CORR-2014.9.30-10Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, DC 20549

___________________________________________

FORM 10-Q

___________________________________________



x	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended September 30, 2014



¨	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to

Commission file number: 001-33292

___________________________________________

CORENERGY INFRASTRUCTURE TRUST, INC.

(Exact name of registrant as specified in its charter)

___________________________________________



Maryland		20-3431375
(State or other jurisdiction of incorporation or organization)		(IRS Employer Identification No.)



1100 Walnut, Ste. 3350 Kansas City, MO		64106
(Address of Principal Executive Offices)		(Zip Code)

(816) 875-3705

(Registrant’s telephone number, including area code)

n/a

(Former name, former address and former fiscal year, if changed since last report)

___________________________________________

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes x No ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes x No ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, 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):



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

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act) Yes ¨ No x

As of October 31, 2014, the registrant had 31,644,877 common shares outstanding.

CorEnergy Infrastructure Trust, Inc.

FORM 10-Q

FOR THE QUARTER ENDED SEPTEMBER 30, 2014

TABLE OF CONTENTS

____________________________________________________________________________________________



PART I.	FINANCIAL INFORMATION
Item 1.	Financial Statements (unaudited)	3
	Consolidated Balance Sheets	3
	Consolidated Statements of Income	4
	Consolidated Statements of Equity	5
	Consolidated Statements of Cash Flows	6
	Notes to Consolidated Financial Statements	7
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	31
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	45
Item 4.	Controls and Procedures	46

PART II.	OTHER INFORMATION
Item 1.	Legal Proceedings	46
Item 1A.	Risk Factors	46
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	46
Item 3.	Defaults Upon Senior Securities	46
Item 4.	Mine Safety Disclosures	46
Item 5.	Other Information	46
Item 6.	Exhibits	47

This report should be read in its entirety. No one section of the report deals with all aspects of the subject matter. It should be read in conjunction with the consolidated financial statements, related notes and with the Management's Discussion & Analysis ("MD&A") included within, as well as provided in the 2013 Annual Report on Form 10-K, as amended.

The consolidated unaudited financial statements have been prepared in accordance with generally accepted accounting principles for interim financial information, the instructions to Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the information and notes required by generally accepted accounting principles for complete financial statements. In the opinion of Management, all adjustments (consisting of normal recurring accruals) considered necessary for a fair presentation have been included. Operating results for the three and nine months ended September 30, 2014 are not necessarily indicative of the results that may be expected for the year ended December 31, 2014. For further information, refer to the consolidated financial statements and footnotes thereto included in the CorEnergy Infrastructure Trust, Inc. Annual Report on Form 10-K, as amended, for the year ended December 31, 2013.

PART I - FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

CorEnergy Infrastructure Trust, Inc.

CONSOLIDATED BALANCE SHEETS



	September 30, 2014		December 31, 2013
Assets	(Unaudited)
Leased property, net of accumulated depreciation of $22,115,766 and $12,754,588	$	268,670,473	$	232,220,618
Other equity securities, at fair value	25,420,877		23,304,321
Financing notes and related accrued interest receivable, net	15,510,956		—
Cash and cash equivalents	5,476,216		17,963,266
Property and equipment, net of accumulated depreciation of $2,243,135 and $2,037,685	3,116,874		3,318,483
Lease receivable	1,421,211		711,229
Accounts receivable	1,086,587		2,068,193
Warrant Investment	508,000		—
Intangible lease asset, net of accumulated amortization of $948,800 and $729,847	145,971		364,924
Deferred debt issuance costs, net of accumulated amortization of $918,811 and $572,830	1,081,881		1,225,524
Deferred lease costs, net of accumulated amortization of $109,299 and $63,272	811,164		857,190
Hedged derivative asset	577,584		680,968
Income tax receivable	—		834,382
Prepaid expenses and other assets	497,391		326,561
Total Assets	$	324,325,185	$	283,875,659
Liabilities and Equity
Current maturities of long-term debt	$	3,528,000	$	2,940,000
Long-term debt (net of current maturities)	64,414,000		67,060,000
Accounts payable and other accrued liabilities	3,329,284		2,920,267
Unearned revenue	1,422,458		—
Deferred tax liability	5,573,233		5,332,087
Income tax payable	75,522		—
Line of credit	—		81,935
Total Liabilities	$	78,342,497	$	78,334,289
Equity
Warrants, no par value; 0 and 945,594 issued and outstanding at September 30, 2014 and December 31, 2013, respectively (5,000,000 authorized)	$	—	$	1,370,700
Capital stock, non-convertible, $0.001 par value; 31,644,877 shares issued and outstanding at September 30, 2014 and 24,156,163 shares issued and outstanding at December 31, 2013 (100,000,000 shares authorized)	31,645		24,156
Additional paid-in capital	217,893,695		173,441,019
Accumulated retained earnings	—		1,580,062
Accumulated other comprehensive income	650,547		777,403
Total CorEnergy Equity	218,575,887		177,193,340
Non-controlling interest	27,406,801		28,348,030
Total Equity	245,982,688		205,541,370
Total Liabilities and Equity	$	324,325,185	$	283,875,659

See accompanying Notes to Consolidated Financial Statements.

CorEnergy Infrastructure Trust, Inc.

CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)



	For the Three Months Ended						For the Nine Months Ended
	September 30, 2014			September 30, 2013			September 30, 2014			September 30, 2013
Revenue
Lease revenue	$	7,191,187		$	5,638,244		$	21,019,272		$	16,914,732
Sales revenue	1,741,209			1,935,868			6,814,346			6,381,213
Financing revenue	413,482			—			578,829			—
Total Revenue	9,345,878			7,574,112			28,412,447			23,295,945
Expenses
Cost of sales (excluding depreciation expense)	1,284,711			1,411,318			5,377,067			4,891,305
Management fees	813,921			647,380			2,359,054			1,937,588
Asset acquisition expenses	102,591			640,302			139,540			725,513
Professional fees	622,864			305,326			1,287,506			1,191,017
Depreciation expense	3,237,261			2,857,412			9,573,809			8,571,860
Amortization expense	15,343			15,342			46,026			45,963
Operating expenses	210,009			204,446			646,283			714,830
Directors’ fees	50,481			74,437			178,791			124,994
Other expenses	251,636			129,748			644,517			403,766
Total Expenses	6,588,817			6,285,711			20,252,593			18,606,836
Operating Income	$	2,757,061		$	1,288,401		$	8,159,854		$	4,689,109
Other Income (Expense)
Net distributions and dividend income	$	1,688,830		$	568,332		$	1,699,874		$	584,157
Net realized and unrealized loss on trading securities	—			(567,276		)	—			(251,213		)
Net realized and unrealized gain (loss) on other equity securities	(865,470		)	1,439,296			2,512,738			3,834,306
Interest expense	(977,635		)	(818,134		)	(2,623,972		)	(2,462,790		)
Total Other Income (Expense)	(154,275		)	622,218			1,588,640			1,704,460
Income before income taxes	2,602,786			1,910,619			9,748,494			6,393,569
Taxes
Current tax expense (benefit)	486,054			(680,281		)	1,340,129			187,367
Deferred tax expense	(161,171		)	1,785,406			241,146			2,180,456
Income tax expense, net	324,883			1,105,125			1,581,275			2,367,823
Net Income	2,277,903			805,494			8,167,219			4,025,746
Less: Net income attributable to non-controlling interest	389,485			366,042			1,167,734			1,103,469
Net Income attributable to CORR Stockholders	$	1,888,418		$	439,452		$	6,999,485		$	2,922,277

Net income	$	2,277,903		$	805,494		$	8,167,219		$	4,025,746
Other comprehensive income (expense):
Changes in fair value of qualifying hedges attributable to CORR Stockholders	214,602			(262,972		)	(126,856		)	658,470
Changes in fair value of qualifying hedges attributable to non-controlling interest	50,175			(61,485		)	(29,660		)	153,954
Net Change in Other Comprehensive Income (Expense)	$	264,777		$	(324,457	)	$	(156,516	)	$	812,424
Total Comprehensive Income	2,542,680			481,037			8,010,703			4,838,170
Less: Comprehensive income attributable to non-controlling interest	439,660			304,557			1,138,074			1,257,423
Comprehensive Income attributable to CORR Stockholders	$	2,103,020		$	176,480		$	6,872,629		$	3,580,747

Earnings Per Common Share:
Basic and Diluted	$	0.06		$	0.02		$	0.23		$	0.12
Weighted Average Shares of Common Stock Outstanding:
Basic and Diluted	31,641,851			24,151,700			31,090,370			24,147,163
Dividends declared per share	$	0.130		$	0.125		$	0.384		$	0.375

See accompanying Notes to Consolidated Financial Statements.

CorEnergy Infrastructure Trust, Inc.

CONSOLIDATED STATEMENTS OF EQUITY



	Capital Stock						Additional Paid-in Capital			Accumulated Other Comprehensive Income			AccumulatedRetained Earnings			Non-Controlling Interest			Total
	Shares	Amount		Warrants			Additional Paid-in Capital			Accumulated Other Comprehensive Income			AccumulatedRetained Earnings			Non-Controlling Interest			Total
Balance at December 31, 2012	24,140,667	$	24,141	$	1,370,700		$	175,256,675		$	—		$	4,209,023		$	29,981,653		$	210,842,192
Net income	—	—		—			—			—			4,502,339			1,466,767			5,969,106
Net change in cash flow hedges	—	—		—			—			777,403			—			181,762			959,165
Total comprehensive income	—	—		—			—			777,403			4,502,339			1,648,529			6,928,271
Dividends	—	—		—			(1,923,760		)	—			(7,131,300		)	—			(9,055,060		)
Distributions to non-controlling interest	—	—		—			—			—			—			(3,282,152		)	(3,282,152		)
Reinvestment of dividends paid to stockholders	15,496	15		—			108,104			—			—			—			108,119
Balance at December 31, 2013	24,156,163	$	24,156	$	1,370,700		$	173,441,019		$	777,403		$	1,580,062		$	28,348,030		$	205,541,370
Net income	—	—		—			—			—			6,999,485			1,167,734			8,167,219
Net change in cash flow hedges	—	—		—			—			(126,856		)	—			(29,660		)	(156,516		)
Total comprehensive income	—	—		—			—			(126,856		)	6,999,485			1,138,074			8,010,703
Net offering proceeds	7,475,000	7,475		—			45,617,088			—			—			—			45,624,563
Dividends	—	—		—			(2,634,179		)	—			(8,579,547		)	—			(11,213,726		)
Distributions to non-controlling interest	—	—		—			—			—			—			(2,079,303		)	(2,079,303		)
Reinvestment of dividends paid to stockholders	13,714	14		—			99,067			—			—			—			99,081
Warrant expiration	—	—		(1,370,700		)	1,370,700			—			—			—			—
Balance at September 30, 2014 (Unaudited)	31,644,877	$	31,645	$	—		$	217,893,695		$	650,547		$	—		$	27,406,801		$	245,982,688

See accompanying Notes to Consolidated Financial Statements.

CorEnergy Infrastructure Trust, Inc.

CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)



	For the Nine Months Ended
	September 30, 2014			September 30, 2013
Operating Activities
Net income	$	8,167,219		$	4,025,746
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Deferred income tax, net	241,146			2,180,456
Depreciation	9,573,809			8,571,860
Amortization	860,960			650,330
Realized and unrealized loss on trading securities	—			251,213
Realized and unrealized gain on other equity securities	(4,199,375		)	(3,834,306		)
Unrealized (gain) loss on derivative contract	(53,132		)	29,239
Distributions received from investment securities	823,499			(567,276		)
Changes in assets and liabilities:
(Increase) decrease in accounts receivable	981,606			(220,004		)
(Increase) in lease receivable	(709,982		)	—
(Increase) decrease in prepaid expenses and other assets	(170,830		)	330,715
Increase (decrease) in accounts payable and other accrued liabilities	(68,421		)	(1,571,999		)
Increase (decrease) in current income tax liability	909,904			(4,626,710		)
Increase (decrease) in unearned revenue	1,422,458			(2,133,685		)
Net cash provided by operating activities	$	17,778,861		$	3,085,579
Investing Activities
Proceeds from sale of long-term investment of trading and other equity securities	—			5,563,865
Deferred lease costs	—			(5,620		)
Acquisition of leased assets	(45,524,755		)	(37,696		)
Purchases of property and equipment	(11,970		)	(42,242		)
Issuance of financing notes receivable	(15,510,956		)	—
Retirement of property and equipment	948			—
Return of capital on distributions received	873,820			1,142,488
Net cash (used in) provided by investing activities	$	(60,172,913	)	$	6,620,795
Financing Activities
Payments on lease obligation	—			(20,698		)
Debt financing costs	(383,678		)	(10,999		)
Net offering proceeds	45,624,563			—
Dividends paid	(11,114,645		)	(5,957,317		)
Distributions to non-controlling interest	(2,079,303		)	(2,479,425		)
Advances on revolving line of credit	2,535,671			139,397
Payments on revolving line of credit	(2,617,606		)	(139,397		)
Principal payment on credit facility	(2,058,000		)	—
Net cash provided by (used in) financing activities	$	29,907,002		$	(8,468,439	)
Net (decrease) increase in cash and cash equivalents	$	(12,487,050	)	$	1,237,935
Cash and cash equivalents at beginning of period	17,963,266			17,680,783
Cash and cash equivalents at end of period	$	5,476,216		$	18,918,718

Supplemental Disclosure of Cash Flow Information:
Interest paid	$	2,104,349		$	1,948,486
Net Income taxes paid (refunds received)	$	430,225		$	4,781,617
Non-Cash Investing Activities
Change in accounts payable and accrued expenses related to acquisition expenditures	$	408,778		$	—
Non-Cash Financing Activities
Reinvestment of distributions by common stockholders in additional common shares	$	99,081		$	78,755
Change in accounts payable and accrued expenses related to debt financing costs	$	(68,660	)	$	—

See accompanying Notes to Consolidated Financial Statements.

CorEnergy Infrastructure Trust, Inc.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

September 30, 2014

1. INTRODUCTION AND BASIS OF PRESENTATION

Introduction

CorEnergy Infrastructure Trust, Inc. ("CorEnergy"), was organized as a Maryland corporation and commenced operations on December 8, 2005. The Company's shares are listed on the New York Stock Exchange under the symbol “CORR.” As used in this report, the terms "we", "us", "our" and the "Company" refer to CorEnergy and its subsidiaries.

We are primarily focused on acquiring and financing midstream and downstream real estate assets within the U.S. energy infrastructure sector and concurrently entering into long-term triple-net participating leases with energy companies. We also may provide other types of capital, including loans secured by energy infrastructure assets. We intend to acquire assets that are accretive to our shareholders and allow us to remain a diversified energy infrastructure real estate investment trust (REIT). Targeted assets include pipelines, storage tanks, transmission lines and gathering systems, among others. These sale-leaseback or real property mortgage transactions provide the energy company with a source of capital that is an alternative to sources such as corporate borrowing, bond offerings, or equity offerings. We expect to receive participation features in the financial performance or value of the underlying infrastructure real property asset. The triple-net lease structure requires that the tenant pay all operating expenses of the business conducted by the tenant, including real estate taxes, insurance, utilities, and expenses of maintaining the asset in good working order.

The Company's consolidated financial statements include the Company's direct and indirect wholly-owned subsidiaries. All significant intercompany balances and transactions have been eliminated in consolidation. The Company's financial statements also present non-controlling interests in the case of entities that are not wholly-owned subsidiaries of the Company.

The Company consolidates certain entities when it is deemed to be the primary beneficiary in a variable interest entity ("VIE"), as defined in Financial Accounting Standards Board ("FASB") Accounting Standards Codification ("ASC") Topic on Consolidation. The Topic on Consolidation requires the consolidation of VIEs in which an enterprise has a controlling financial interest. A controlling financial interest will have both of the following characteristics: (1) the power to direct the activities of a VIE that most significantly impact the VIE's economic performance, and (2) the obligation to absorb losses of the VIE that could potentially be significant to the VIE or the right to receive benefits from the VIE that could potentially be significant to the VIE. This topic requires an ongoing reassessment. The equity method of accounting is applied to entities in which the Company is not the primary beneficiary as defined in the Consolidation Topic of FASB ASC, or does not have effective control, but can exercise influence over the entity with respect to its operations and major decisions.

Taxable REIT subsidiaries hold our securities portfolio, operating business and a financing note receivable. Corridor Public Holdings, Inc. and its wholly-owned subsidiary Corridor Private Holdings, Inc, hold the securities portfolio. The operating company is held by Mowood Corridor, Inc. and its wholly-owned subsidiary, Mowood, LLC ("Mowood"), which is the holding company for Omega Pipeline Company, LLC (“Omega”). Omega owns and operates a natural gas distribution system in Fort Leonard Wood, Missouri. Omega is responsible for purchasing and coordinating delivery of natural gas to Fort Leonard Wood, as well as performing maintenance and expansion of the pipeline. In addition, Omega provides gas-marketing services to local commercial end users. A financing note receivable is held by CorEnergy BBWS ("BBWS").

Basis of Presentation and Use of Estimates

The accompanying consolidated financial statements have been prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) for interim financial information set forth in the Accounting Standards Codification (“ASC”), as published by the Financial Accounting Standards Board (“FASB”), and with the Securities and Exchange Commission (“SEC”) instructions to Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. The accompanying consolidated financial statements reflect all adjustments that are, in the opinion of management, necessary for a fair presentation of the Company's financial position, results of operations and cash flows for the interim period presented. There were no adjustments that, in the opinion of management, were not of a normal and recurring nature. Additionally, certain prior year balances have been reclassified to provide comparability of financial results across reporting periods.

Operating results for the three and nine months ended September 30, 2014 are not necessarily indicative of the results that may be expected for the year ending December 31, 2014. These consolidated financial statements and Management's Discussion and Analysis of the Financial Condition and Results of Operations should be read in conjunction with our Annual Report on Form 10-K, as amended, for the year ended December 31, 2013, filed with the SEC on March 19, 2014.

The financial statements included in this report are based on the selection and application of critical accounting policies, which require management to make significant estimates and assumptions. Critical accounting policies are those that are both important to the presentation of our financial condition and results of operations and require management's most difficult, complex or subjective judgments. Note 2 to the Consolidated Financial Statements, included in this report, further details information related to our significant accounting policies.

2. SIGNIFICANT ACCOUNTING POLICIES

A. Use of Estimates – The preparation of the consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amount of assets and liabilities, recognition of distribution income and disclosure of contingent assets and liabilities at the date of the consolidated financial statements. Actual results could differ from those estimates.

B. Leased Property – The Company includes assets subject to lease arrangements within Leased property, net of accumulated depreciation, in the Consolidated Balance Sheets. Lease payments received are reflected in lease revenue on the Consolidated Statements of Income, net of amortization of any off-market adjustments. Costs in connection with the creation and execution of a lease are capitalized and amortized over the lease term. See Note 4 for further discussion.

C. Cash and Cash Equivalents – The Company maintains cash balances at financial institutions in amounts that regularly exceed FDIC insured limits. The Company’s cash equivalents are comprised of short-term, liquid money market instruments.

D. Long-Lived Assets and Intangibles – Property and equipment are stated at cost less accumulated depreciation. Depreciation is computed using the straight-line method over the estimated useful life of the asset. Expenditures for repairs and maintenance are charged to operations as incurred, and improvements, which extend the useful lives of assets, are capitalized and depreciated over the remaining estimated useful life of the asset.

The Company initially records long-lived assets at their acquisition cost, unless the transaction is accounted for as a business combination. If the transaction is accounted for as a business combination, the Company allocates the purchase price to the acquired tangible and intangible assets and liabilities based on their estimated fair values. The Company determines the fair values of assets and liabilities based on discounted cash flow models using current market assumptions, appraisals, recent transactions involving similar assets or liabilities and other objective evidence, and depreciates the asset values over the estimated remaining useful lives.

The Company may acquire long-lived assets that are subject to an existing lease contract with the seller or other lessee party and the Company may assume outstanding debt of the seller as part of the consideration paid. If, at the time of acquisition, the existing lease or debt contract is not at current market terms, the Company will record an asset or liability at the time of acquisition representing the amount by which the fair value of the lease or debt contract differs from its contractual value. Such amount is then amortized over the remaining contract term as an adjustment to the related lease revenue or interest expense. The Company periodically reviews its long-lived assets, primarily real estate, for impairment whenever events or changes in circumstances indicate that the carrying amount of such assets may not be recoverable. The Company’s review involves comparing current and future operating performance of the assets, the most significant of which is undiscounted operating cash flows, to the carrying value of the assets. Based on this analysis, a provision for possible loss is recognized, if any. No impairment write-downs were recognized during the three and nine months ended September 30, 2014 and September 30, 2013.

Costs in connection with the direct acquisition of a new asset are capitalized as a component of the purchase price and depreciated over the life of the asset. See Note 4 for further discussion.

E. Investment Securities – The Company’s investments in securities are classified as either trading or other equity securities:


•	Trading securities – The Company’s publicly traded equity securities were classified as trading securities and were historically reported at fair value. The Company liquidated its trading securities in order to acquire real asset investments. As of March 31, 2013, all trading securities had been sold.


•	Other equity securities – The Company’s other equity securities represent interests in private companies which the Company has elected to report at fair value under the fair value option.


•	Realized and unrealized gains and losses on trading securities and other equity securities – Changes in the fair values of the Company’s securities during the period reported and the gains or losses realized upon sale of securities during the period are reflected as other income or expense within the accompanying Consolidated Statements of Income.

F. Security Transactions and Fair Value – Security transactions are accounted for on the date the securities are purchased or sold (trade date). Realized gains and losses are reported on an identified cost basis.

For equity securities that are freely tradable and listed on a securities exchange or over-the-counter market, the Company values those securities at their last sale price on that exchange or over-the-counter market on the valuation date. If the security is listed on more than one exchange, the Company will use the price from the exchange that it considers to be the principal, which may not necessarily represent the last sale price. If there has been no sale on such exchange or over-the-counter market on such day, the security will be valued at the mean between the last bid price and last ask price on such day.

The major components of net realized and unrealized gain or loss on trading securities for the three and nine months ended September 30, 2014 and September 30, 2013 are as follows:



Major Components of Net Realized and Unrealized Gain (Loss) on Trading Securities
	For the Three Months Ended					For the Nine Months Ended
	September 30, 2014		September 30, 2013			September 30, 2014		September 30, 2013
Net unrealized gain on trading securities	$	—	$	—		$	—	$	—
Net realized loss on trading securities	—		(567,276		)	—		(251,213		)
Total net realized and unrealized loss on trading securities	$	—	$	(567,276	)	$	—	$	(251,213	)

The Company holds investments in illiquid securities including debt and equity securities of privately-held companies. These investments generally are subject to restrictions on resale, have no established trading market and are valued on a quarterly basis. Because of the inherent uncertainty of valuation, the fair values of such investments, which are determined in accordance with procedures approved by the Company’s Board of Directors, may differ materially from the values that would have been used had a ready market existed for the investments.

The Company determines fair value to be the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. The Company has determined the principal market, or the market in which the Company exits its private portfolio investments with the greatest volume and level of activity, to be the private secondary market. Typically, private companies are bought and sold based on multiples of EBITDA, cash flows, net income, revenues, or in limited cases, book value.

For private company investments, value is often realized through a liquidity event. Therefore, the value of the company as a whole (enterprise value) at the reporting date often provides the best evidence of the value of the investment and is the initial step for valuing the Company’s privately issued securities. For any one company, enterprise value may best be expressed as a range of fair values, from which a single estimate of fair value will be derived. In determining the enterprise value of a portfolio company, an analysis is prepared consisting of traditional valuation methodologies including market and income approaches. The Company considers some or all of the traditional valuation methods based on the individual circumstances of the portfolio company in order to derive its estimate of enterprise value.

The fair value of investments in private portfolio companies is determined based on various factors, including enterprise value, observable market transactions, such as recent offers to purchase a company, recent transactions involving the purchase or sale of the equity securities of the company, or other liquidation events. The determined equity values may be discounted when the Company has a minority position, or is subject to restrictions on resale, has specific concerns about the receptivity of the capital markets to a specific company at a certain time, or other comparable factors exist.

The Company undertakes a multi-step valuation process each quarter in connection with determining the fair value of private investments. We have retained an independent valuation firm to provide third party valuation consulting services based on procedures that the Company has identified and may ask them to perform from time to time on all or a selection of private investments as determined by the Company. The multi-step valuation process is specific to the level of assurance that the Company requests from the independent valuation firm. For positive assurance, the process is as follows:


•	The independent valuation firm prepares the valuations and the supporting analysis.


•	The valuation report is reviewed and approved by senior management.


•	The Audit Committee of the Board of Directors reviews the supporting analysis and accepts the valuations.

G. Financing Notes Receivable – Financing notes receivable are presented at face value plus accrued interest receivable and deferred loan origination fees and net of related direct loan origination costs. The financing notes receivable are discussed more

fully in Note 5. At September 30, 2014 the Company determined that an allowance for financing notes receivable was not deemed necessary.

H. Lease Receivable – Lease receivables are determined according to the terms of the lease agreements entered into by the Company and its lessees, as discussed within Note 4. Lease payments by our tenants, have remained timely and without lapse. At September 30, 2014 and December 31, 2013, the Company determined that an allowance for lease payments receivable was not deemed necessary.

I. Accounts Receivable – Accounts receivable are presented at face value net of an allowance for doubtful accounts. Accounts are considered past due based on the terms of sale with the customers. The Company reviews accounts for collectibility based on an analysis of specific outstanding receivables, current economic conditions and past collection experience. At September 30, 2014 and December 31, 2013, the Company determined that an allowance for doubtful accounts was not deemed necessary.

J. Derivative Instruments and Hedging Activities – FASB ASC 815, Derivatives and Hedging (“ASC 815”), provides the disclosure requirements for derivatives and hedging activities with the intent to provide users of financial statements with an enhanced understanding of: (a) how and why an entity uses derivative instruments, (b) how the entity accounts for derivative instruments and related hedged items, and (c) how derivative instruments and related hedged items affect an entity's financial position, financial performance, and cash flows. Further, qualitative disclosures are required that explain the Company's objectives and strategies for using derivatives, as well as quantitative disclosures about the fair value of and gains and losses on derivative instruments, and disclosures about credit-risk-related contingent features in derivative instruments. Accordingly, the Company's derivative assets and liabilities are presented on a gross basis.

As required by ASC 815, the Company records all derivatives on the balance sheet at fair value. The accounting for changes in the fair value of derivatives depends on the intended use of the derivative, whether the Company has elected to designate a derivative in a hedging relationship and apply hedge accounting and whether the hedging relationship has satisfied the criteria necessary to apply hedge accounting. Derivatives designated and qualifying as a hedge of the exposure to changes in the fair value of an asset, liability, or firm commitment attributable to a particular risk, such as interest rate risk, are considered fair value hedges. Derivatives designated and qualifying as a hedge of the exposure to variability in expected future cash flows, or other types of forecasted transactions, are considered cash flow hedges. Derivatives may also be designated as hedges of the foreign currency exposure of a net investment in a foreign operation. Hedge accounting generally provides for the matching of the timing of gain or loss recognition on the hedging instrument with the recognition of the changes in the fair value of the hedged asset or liability that are attributable to the hedged risk in a fair value hedge or the earnings effect of the hedged forecasted transactions in a cash flow hedge. The Company may enter into derivative contracts that are intended to economically hedge certain of its risks, even though hedge accounting does not apply or the Company elects not to apply hedge accounting.

FASB ASC 820, Fair Value Measurements and Disclosure ("ASC 820"), defines fair value, establishes a framework for measuring fair value, and expands disclosures about fair value measurements. In accordance with ASC 820, the Company made an accounting policy election to measure the credit risk of its derivative financial instruments that are subject to master netting agreements on a net basis by counterparty portfolio.

K. Fair Value Measurements – Various inputs are used in determining the fair value of the Company’s assets and liabilities. These inputs are summarized in the three broad levels listed below:


•	Level 1 – quoted prices in active markets for identical investments


•	Level 2 – other significant observable inputs (including quoted prices for similar investments, market corroborated inputs, etc.)


•	Level 3 – significant unobservable inputs (including the Company’s own assumptions in determining the fair value of investments)

ASC 820 applies to reported balances that are required or permitted to be measured at fair value under existing accounting pronouncements; accordingly, the standard does not require any new fair value measurements of reported balances. ASC 820 emphasizes that fair value is a market-based measurement, not an entity-specific measurement. Therefore, a fair value measurement should be determined based on the assumptions that market participants would use in pricing the asset or liability. As a basis for considering market participant assumptions in fair value measurements, ASC 820 establishes a fair value hierarchy that distinguishes between market participant assumptions based on market data obtained from sources independent of the reporting entity (observable inputs that are classified within Levels 1 and 2 of the hierarchy) and the reporting entity's own assumptions about market participant assumptions (unobservable inputs classified within Level 3 of the hierarchy).

Level 1 inputs utilize quoted prices (unadjusted) in active markets for identical assets or liabilities that the Company has the ability to access. Level 2 inputs are inputs other than quoted prices included in Level 1 that are observable for the asset or liability, either directly or indirectly. Level 2 inputs may include quoted prices for similar assets and liabilities in active markets, as well as inputs that are observable for the asset or liability (other than quoted prices), such as interest rates, foreign exchange rates, and yield curves that are observable at commonly quoted intervals. Level 3 inputs are unobservable inputs for the asset or liability, which are typically based on an entity's own assumptions, as there is little, if any, related market activity. In instances where the determination of the fair value measurement is based on inputs from different levels of the fair value hierarchy, the level in the fair value hierarchy within which the entire fair value measurement falls is based on the lowest level input that is significant to the fair value measurement in its entirety. The Company's assessment of the significance of a particular input to the fair value measurement in its entirety requires judgment, and considers factors specific to the asset or liability.

L. Revenue Recognition – Specific recognition policies for the Company’s revenue items are as follows:

•

Lease Revenue – Income related to the Company’s leased property is recognized on a straight-line basis over the term of the lease when collectibility is reasonably assured. Rental payments received in advance are classified as unearned revenue and included in liabilities within the Consolidated Balance Sheets. Unearned revenue is amortized ratably over the lease period as revenue recognition criteria are met. Rental payments received in arrears are accrued and classified as Lease Receivable and included in assets within the Consolidated Balance Sheets.

•

Sales Revenue – Revenues related to natural gas distribution and performance of management services are recognized in accordance with GAAP upon delivery of natural gas and upon the substantial performance of management and supervision services related to the expansion of the natural gas distribution system. Omega, acting as a principal, provides for transportation services and natural gas supply for its customers. In addition, Omega is paid fees for the operation and maintenance of its natural gas distribution system, including any necessary expansion of the distribution system. Omega is responsible for the coordination, supervision and quality of the expansions while actual construction is generally performed by third party contractors. Revenues from expansion efforts are recognized in accordance with GAAP using either a completed contract or percentage of completion method based on the level and volume of estimates utilized, as well as the certainty or uncertainty of our ability to collect those revenues.

•

Financing Revenue – Our financing notes receivable are considered a core product offering and therefore the related income is presented as a component of operating income in the revenue section. For increasing rate loans, base interest income is recorded ratably over the life of the loan, using the effective interest rate. The net amount of deferred loan origination fees and costs are amortized on a straight-line basis over the life of the loan and reported as an adjustment to yield in financing revenue. Participating financing revenues are recorded when specific performance criteria have been met.

M. Cost of Sales – Included in the Company’s cost of sales are the amounts paid for gas and propane, along with related transportation, which are delivered to customers, as well as the cost of material and labor related to the expansion of the natural gas distribution system.

N. Asset Acquisition Expenses – Costs incurred in connection with the research of real property acquisitions not expected to be accounted for as business combinations are expensed until it is determined that the acquisition of the real property is probable. Upon such determination, costs incurred in connection with the acquisition of the property are capitalized as described in paragraph (D) above. Deferred costs related to an an acquisition that we have determined, based on our judgment, not to pursue are expensed in the period in which such determination is made.

O. Offering Costs – Offering costs related to the issuance of common stock are charged to additional paid-in capital when the stock is issued.

P. Debt Issuance Costs – Costs incurred for the issuance of new debt are capitalized and amortized over the debt term. See Note 13 for further discussion.

Q. Distributions to Stockholders – Distributions to stockholders are determined by the Board of Directors and are recorded on the ex-dividend date.

R. Other Income Recognition – Specific policies for the Company’s other income items are as follows:

•

Securities Transactions and Investment Income Recognition – Securities transactions are accounted for on the date the securities are purchased or sold (trade date). Realized gains and losses are reported on an identified cost basis. Distributions received from our equity investments are generally comprised of ordinary income, capital gains and distributions received from investment securities from the portfolio company. The Company records investment income and return of capital

based on estimates made at the time such distributions are received. Such estimates are based on information available from each portfolio company and other industry sources. These estimates may subsequently be revised based on information received from the portfolio companies after their tax reporting periods are concluded, as the actual character of these distributions are not known until after our fiscal year end.

Subsequent to December 31, 2013, the Company reallocated the amount of 2013 income and return of capital it recognized for the period January 1, 2013 to December 31, 2013 based on the 2013 tax reporting information received from the individual portfolio companies. This reclassification amounted to an increase in net distributions and dividend income on securities of $863 thousand or $0.04 per share; a decrease in net realized and unrealized gains on other equity securities of $863 thousand or $0.04 per share for the year ended December 31, 2013. This reclassification had no impact on net income.

Prior to September 30, 2014, the Company reallocated the amount of 2014 income and return of capital it recognized for the period January 1, 2014 to September 30, 2014 based on estimated 2014 tax reporting information received from the individual portfolio companies. This reclassification amounted to an increase in net distributions and dividend income on securities of $823 thousand or $0.03 per share; an increase in net realized and unrealized loss on other equity securities of $823 thousand or $0.03 per share for the nine months ended September 30, 2014. This reclassification had no impact on net income.

•

Dividends and distributions from investments – Dividends and distributions from investments are recorded on their ex-dates and are reflected as other income within the accompanying Consolidated Statements of Income. Distributions received from the Company’s investments are generally characterized as ordinary income, capital gains and distributions received from investment securities. The portion characterized as return of capital is paid by our investees from their cash flow from operations. The Company records investment income, capital gains and distributions received from investment securities based on estimates made at the time such distributions are received. Such estimates are based on information available from each company and other industry sources. These estimates may subsequently be revised based on information received from the entities after their tax reporting periods are concluded, as the actual character of these distributions is not known until after the fiscal year end of the Company.

S. Federal and State Income Taxation – In 2013 we qualified, and in January 2014 elected (effective as of January 1, 2013), to be treated as a REIT for federal income tax purposes (which we refer to as the “REIT Election"). Because certain of our assets may not produce REIT-qualifying income or be treated as interests in real property, those assets are held in wholly-owned Taxable REIT Subsidiaries ("TRSs") in order to limit the potential that such assets and income could prevent us from qualifying as a REIT.

As a REIT, our distributions from earnings and profits will be treated as ordinary income and a return of capital, and generally will not qualify as qualified dividend income ("QDI"). To the extent that the REIT had accumulated C corporation earnings and profits from the periods prior to 2013, we have distributed such earnings and profits in 2013. A portion of our normal distribution was characterized for federal income tax purposes as a distribution of those earnings and profits from non-REIT years and have been treated as QDI.

As a REIT, the Company holds and operates certain of our assets through one or more wholly-owned TRSs. A TRS is a subsidiary of a REIT that is subject to applicable corporate income tax. Our use of TRSs enables us to continue to engage in certain businesses while complying with REIT qualification requirements and also allows us to retain income generated by these businesses for reinvestment without the requirement of distributing those earnings. In the future, we may elect to reorganize and transfer certain assets or operations from our TRSs to the Company or other subsidiaries, including qualified REIT subsidiaries.

The Company's trading securities and other equity securities are limited partnerships or limited liability companies which are treated as partnerships for federal and state income tax purposes. As a limited partner, the Company reports its allocable share of taxable income in computing its own taxable income. The Company's tax expense or benefit is included in the Consolidated Statements of Income based on the component of income or gains and losses to which such expense or benefit relates. Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. A valuation allowance is recognized if, based on the weight of available evidence, it is more likely than not that some portion or all of the deferred income tax asset will not be realized. Due to our decision to structure ourselves as a REIT in December 2012, it is expected that for the year ended December 31, 2013 and future periods, any deferred tax liability or asset will be related entirely to the assets and activities of the Company's TRSs.

If we cease to qualify as a REIT, the Company, as a C corporation, would be obligated to pay federal and state income tax on its taxable income. Currently, the highest regular marginal federal income tax rate for a corporation is 35 percent. The Company may

be subject to a 20 percent federal alternative minimum tax on its federal alternative minimum taxable income to the extent that its alternative minimum tax exceeds its regular federal income tax.

T. Recent Accounting Pronouncements – In August 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2014-15, Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern (“ASU No. 2014-15”) that will require management to evaluate whether there are conditions and events that raise substantial doubt about the Company’s ability to continue as a going concern within one year after the financial statements are issued on both an interim and annual basis. Management will be required to provide certain footnote disclosures if it concludes that substantial doubt exists or when its plans alleviate substantial doubt about the Company’s ability to continue as a going concern. ASU No. 2014-15 becomes effective for annual periods beginning in 2016 and for interim reporting periods starting in the first quarter of 2017. The Company does not expect the adoption of this amendment to have a material impact on its consolidated financial statements.

In May 2014, the FASB issued ASU No. 2014-09 "Revenue from Contracts with Customers." ASU No. 2014-09 adds to the FASB ASC by detailing new guidance in order to make a more clarified set of principles for recognizing revenue from customer contracts. ASU No. 2014-09 is effective for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period. Management has evaluated this amendment and does not expect adoption to have a material impact on the Company's consolidated financial statements.

In April 2014, the FASB issued ASU 2014-08 "Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity". Under this guidance, only disposals representing a strategic shift in operations would be presented as discontinued operations. This guidance requires expanded disclosure that provides information about the assets, liabilities, income and expenses of discontinued operations. Additionally, the guidance requires additional disclosure for a disposal of a significant part of an entity that does not qualify for discontinued operations reporting. This guidance will be effective for reporting periods beginning on or after December 15, 2014 with early adoption permitted for disposals or classifications of assets as held-for-sale that have not been reported in financial statements previously issued or available for issuance. The Company has not elected early adoption, however we anticipate the effects of applying the revised guidance will vary based upon the nature and size of future disposal transactions. It is expected that fewer disposal transactions will meet the new criteria to be reported as discontinued operations.

In July 2013, the FASB issued ASU No. 2013-11 "Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists." ASU No. 2013-11 amends FASB ASC Topic 740 Income taxes, to include explicit guidance on the financial statement presentation of an unrecognized tax benefit when a net operating loss carryforward, a similar tax loss, or a tax credit carryforward exists. ASU No. 2013-11 is effective for fiscal years, and interim periods within those years, beginning after December 15, 2013. Management has adopted this amendment and it did not have a material impact on the Company's consolidated financial statements.

3. LEASED PROPERTIES

Pinedale LGS

Our subsidiary, Pinedale Corridor, LP ("Pinedale LP"), owns a system of gathering, storage, and pipeline facilities (the "Liquids Gathering System" or "Pinedale LGS"), with associated real property rights in the Pinedale Anticline in Wyoming.

Physical Assets

The Pinedale LGS consists of more than 150 miles of pipelines with 107 receipt points and four above-ground central gathering facilities. The system is leased to and used by Ultra Petroleum Corp. ("Ultra Petroleum") as a method of separating water, condensate and associated flash gas from a unified stream and subsequently selling or treating and disposing of the separated products. Prior to entering the Pinedale LGS, a commingled hydrocarbon stream is separated into wellhead natural gas and a liquids stream. The wellhead natural gas is transported to market by a third party. The remaining liquids, primarily water, are transported by the Pinedale LGS to one of its four central gathering facilities where they pass through a three-phase separator which separates condensate, water and associated natural gas. Condensate is a valuable hydrocarbon commodity that is sold by Ultra Petroleum; water is transported to disposal wells or a treatment facility for re-use; and the natural gas is sold or otherwise used by Ultra Petroleum for fueling on-site operational equipment. To date, no major operational issues have been reported with respect to the Pinedale LGS.

The asset is depreciated for book purposes over an estimated useful life of 26 years. The amount of depreciation recognized for the leased property for each of the three-month periods ended September 30, 2014 and 2013 was $2.2 million, and for each of the nine-month periods ended September 30, 2014 and 2013 was $6.7 million.

See Note 4 for further information regarding the Pinedale Lease Agreement (as defined therein).

Non-Controlling Interest Partner

Prudential Financial, Inc. ("Prudential") funded a portion of the Pinedale LGS acquisition and, as a limited partner, holds 18.95 percent of the economic interest in Pinedale LP. The general partner, Pinedale GP, holds the remaining 81.05 percent of the economic interest.

Debt

Pinedale LP borrowed $70 million pursuant to a secured term credit facility with KeyBank National Association ("KeyBank") serving as a lender and the administrative agent on behalf of other lenders participating in the credit facility. The credit facility will remain in effect through December 2015, with an option to extend through December 2016. The credit facility is secured by the LGS. See Note 13 for further information regarding the credit facility.

Portland Terminal Facility

On January 21, 2014, we completed a follow-on equity offering of 7,475,000 shares of common stock, raising approximately $49 million in gross proceeds at $6.50 per share (net proceeds of approximately $46 million after underwriters’ discount). Concurrently, our subsidiary, LCP Oregon, used the net proceeds from the offering to close on a Purchase and Sale Agreement to acquire a petroleum products terminal facility and certain associated real property rights located in Portland, Oregon ("Portland Terminal Facility") for $40 million in cash. LCP Oregon also entered into a long-term triple-net Lease Agreement relating to the use of the Portland Terminal Facility (the “Portland Lease Agreement”) with Arc Terminals Holdings LLC ("Arc Terminals"), an indirect wholly-owned subsidiary of Arc Logistics Partners LP ("Arc Logistics").

The Portland Terminal Facility is a rail and marine facility adjacent to the Willamette River in Portland, Oregon. The 39-acre site has 84 tanks with a total storage capacity of approximately 1,500,000 barrels. The Portland Terminal Facility is capable of receiving, storing and delivering crude oil and refined petroleum products. Products are received and delivered via railroad or marine (up to Panamax size vessels). The marine facilities are accessed through a neighboring terminal facility via an owned pipeline. The Portland Terminal Facility offers heating systems, emulsions and an on-site product testing laboratory as ancillary services.

We anticipate funding an additional $10 million of terminal-related improvement projects in support of Arc Terminals’ commercial strategy to optimize the Portland Terminal Facility and generate stable cash flows, including: i) upgrade a portion of the existing storage assets; ii) enhance existing terminal infrastructure; and iii) develop, design, engineer and construct throughput expansion opportunities. As of September 30, 2014, additional spending on terminal-related projects totaled approximately $4.4 million.

The asset is depreciated for book purposes over an estimated useful life of 30 years. The amount of depreciation recognized for the leased property for each of the three months ended September 30, 2014 and 2013 was $374 thousand and $0, respectively. The amount of depreciation recognized for the leased property for each of the nine months ended September 30, 2014 and 2013, was $1.0 million and $0, respectively.

See Note 4 for further information regarding the Portland Lease Agreement related to the Portland Terminal Facility assets.

Eastern Interconnect Project (EIP)

Physical Assets

The EIP transmission assets are utilized by the lessee to move electricity across New Mexico between Albuquerque and Clovis. The physical assets include 216 miles of 345 kilovolt transmission lines, towers, easement rights, converters and other grid support components. Originally, the assets were depreciated for book purposes over an estimated useful life of 20 years. Pursuant to the Purchase Agreement discussed in Note 4, the Company reevaluated the residual value used to calculate its depreciation of the EIP, and determined that a change in estimate was necessary. The change in estimate resulted in higher depreciation expenses beginning in November of 2012 through the expiration of the lease in April 2015.

The amount of depreciation expense related to the EIP leased property for each of the three-month periods ended September 30, 2014 and 2013 was $570 thousand. The amount of depreciation expense related to the EIP leased property for each of the nine-month periods ended September 30, 2014 and 2013 was $1.7 million.

See Note 4 for further information regarding the PNM Lease Agreement related to the EIP transmission assets.

4. LEASES

As of September 30, 2014 the Company had three significant leases. The table below displays the impact of each lease on total leased properties and total lease revenues for the periods presented.



	As a Percentage of
	Leased Properties		Lease Revenues
	As of September 30, 2014	As of December 31, 2013	For the Three Months Ended		For the Nine Months Ended
	As of September 30, 2014	As of December 31, 2013	September 30, 2014	September 30, 2013	September 30, 2014	September 30, 2013
Pinedale LGS	79.95%	94.23%	70.59%	88.68%	72.45%	88.68%
Portland Terminal Facility	16.77%	—	20.53%	—	18.44%	—
Public Service of New Mexico	3.28%	5.77%	8.88%	11.32%	9.11%	11.32%

Pinedale LGS

Pinedale LP entered into a long-term triple-net Lease Agreement on December 20, 2012, relating to the use of the Pinedale LGS (the “Pinedale Lease Agreement”) with Ultra Wyoming LGS, LLC ("Ultra Wyoming"), an indirect wholly-owned subsidiary of Ultra Petroleum. Ultra Wyoming utilizes the Pinedale LGS to gather and transport a commingled stream of oil, natural gas and water, then further utilizes the Pinedale LGS to separate this stream into its separate components. Ultra Wyoming's obligations under the Pinedale Lease Agreement are guaranteed by Ultra Petroleum and Ultra Petroleum's operating subsidiary, Ultra Resources, Inc. (“Ultra Resources”), pursuant to the terms of a Parent Guaranty. Annual rent for the initial term under the Pinedale Lease Agreement is a minimum of $20 million (as adjusted annually for changes based on the Consumer Price Index (“CPI”), subject to annual maximum adjustments of 2 percent), with the exact rental amount determined by the actual volume of the components handled by the Pinedale LGS, subject to Pinedale LP not being in default under the Pinedale Lease Agreement. For 2014, the increase in quarterly rent is $76 thousand, based on the CPI adjustment as specified in the lease terms. Total annual rent may not exceed $27.5 million.

As of September 30, 2014 and December 31, 2013, approximately $811 thousand and $857 thousand, respectively, of net deferred lease costs are included in the accompanying Consolidated Balance Sheets. The deferred costs are amortized over the 15 year life of the Pinedale LGS lease. For each of the three months ended September 30, 2014 and 2013, $15 thousand is included in amortization expense within the Consolidated Statements of Income. For each of the nine months ended September 30, 2014 and 2013, $46 thousand, is included in amortization expense within the Consolidated Statements of Income. Approximately $2.6 million in gross asset acquisition costs related to the Pinedale LGS acquisition is included in Leased Property within the Consolidated Balance Sheets. The asset acquisition costs are being depreciated over the anticipated 26 year life of the asset and are included in depreciation expense within the Consolidated Statements of Income.

The assets, which comprise the Pinedale LGS, include real property and land rights to which the purchase consideration was allocated based on relative fair values and equaled $122.3 million and $105.7 million, respectively, at the time of acquisition. The land rights are being depreciated over the 26 year life of the related land lease with associated depreciation expense expected to be approximately $4.1 million for each of the next five years.

In view of the fact that Ultra Petroleum leases a substantial portion of the Company's net leased property, which is a significant source of revenues and operating income, its financial condition and ability and willingness to satisfy its obligations under its lease with the Company are expected to have a considerable impact on the results of operation going forward.

Ultra Petroleum is currently subject to the reporting requirements of the Securities Exchange Act of 1934, as amended (the "Exchange Act") and is required to file with the SEC annual reports containing audited financial statements and quarterly reports containing unaudited financial statements. The audited financial statements and unaudited financial statements of Ultra Petroleum can be found on the SEC's website at www.sec.gov. The Company makes no representation as to the accuracy or completeness of the audited and unaudited financial statements of Ultra Petroleum, but has no reason to doubt the accuracy or completeness of such information. In addition, Ultra Petroleum has no duty, contractual or otherwise, to advise the Company of any events that might have occurred subsequent to the date of such financial statements which could affect the significance or accuracy of such information. Summary Consolidated Balance Sheets and Consolidated Statements of Operations for Ultra Petroleum are provided below.



Ultra Petroleum Corp. Summary Consolidated Balance Sheets (in thousands)
	September 30, 2014		December 31, 2013
	(Unaudited)
Current assets	$	136,877	$	128,631
Non-current assets	3,867,050		2,656,688
Total Assets	$	4,003,927	$	2,785,319

Current liabilities	374,457		407,476
Non-current liabilities	3,624,272		2,709,333
Total Liabilities	$	3,998,729	$	3,116,809

Shareholder's equity (deficit)	5,198		(331,490		)
Total Liabilities and Shareholder's Equity	$	4,003,927	$	2,785,319



Ultra Petroleum Corp. Summary Consolidated Statements of Operations (Unaudited) (in thousands)
	For the Three Months Ended September 30						For the Nine Months Ended September 30
	2014			2013			2014			2013
Revenues	$	288,608		$	221,205		$	910,970		$	708,207
Expenses	169,669			136,389			475,347			419,387
Operating Income	118,939			84,816			435,623			288,820
Other Income (Expense), net	5,035			(20,525		)	(104,422		)	(88,863		)
Income before income tax provision (benefit)	123,974			64,291			331,201			199,957
Income tax provision (benefit)	(1,383		)	381			(1,924		)	3,240
Net Income	$	125,357		$	63,910		$	333,125		$	196,717

Portland Terminal Facility

LCP Oregon entered into the Portland Lease Agreement on January 21, 2014. Arc Logistics has guaranteed the obligations of Arc Terminals under the Portland Lease Agreement. The Portland Lease Agreement grants Arc Terminals substantially all authority to operate the Portland Terminal Facility. During the initial term, Arc Terminals will make base monthly rental payments and variable rent payments based on the volume of liquid hydrocarbons that flowed through the Portland Terminal Facility in the prior month. The base rent in the initial year of the Portland Lease Agreement increased to approximately $418 thousand per month starting with August 2014 and each month thereafter. The base rent is also expected to increase during the initial year of the Portland Lease Agreement based on a percentage of specified construction costs at the Portland Terminal Facility incurred by LCP Oregon, estimated at $10 million. Variable rent is capped at 30 percent of total rent, which would be the equivalent of the Portland Terminal Facility’s expected throughput capacity.

Arc Logistics is a fee-based, growth-oriented Delaware limited partnership formed by Lightfoot to own, operate, develop and acquire a diversified portfolio of complementary energy logistics assets. In November 2013, Arc Logistics completed its initial public offering ("IPO"). Arc Logistics’ public disclosures filed with the SEC indicate that Arc Logistics is principally engaged in the terminaling, storage, throughput and transloading of crude oil and petroleum products with energy logistics assets strategically located in the East Coast, Gulf Coast and Midwest regions of the U.S. It is focused on growing its business through the optimization, organic development and acquisition of terminaling, storage, rail, pipeline and other energy logistics assets that generate stable cash flows and offer customers multiple supply and delivery modes via pipelines, rail, marine and truck. Arc Logistics indicated in its 2013 Form 10-K that it had approximately 5 million barrels of crude oil and petroleum product storage capacity. Arc Terminals is a wholly-owned subsidiary of Arc Logistics.

Arc Logistics is currently subject to the reporting requirements of the Exchange Act and is required to file with the SEC annual reports containing audited financial statements and quarterly reports containing unaudited financial statements. The audited financial statements and unaudited financial statements of Arc Logistics can be found on the SEC's web site at www.sec.gov. The Company makes no representation as to the accuracy or completeness of the audited and unaudited financial statements of Arc

Logistics but has no reason to doubt the accuracy or completeness of such information. In addition, Arc Logistics has no duty, contractual or otherwise, to advise the Company of any events that might have occurred subsequent to the date of such financial statements which could affect the significance or accuracy of such information. None of the information in the public reports of Arc Logistics that are filed with the SEC is incorporated by reference into, or in any way form, a part of this filing.

Public Service Company of New Mexico ("PNM")

EIP is leased on a triple-net basis through April 1, 2015 (the "PNM Lease Agreement") to PNM, an independent electric utility company serving approximately 500 thousand customers in New Mexico. PNM is a subsidiary of PNM Resources Inc. (NYSE: PNM) ("PNM Resources"). Per the PNM Lease Agreement, at the time of expiration of the PNM Lease Agreement, the Company could choose to renew the PNM Lease Agreement with the lessee, the lessee could offer to repurchase the EIP, or the PNM Lease Agreement could be allowed to expire and the Company could find another lessee.

At the time of acquisition, the rate of the PNM Lease Agreement was determined to be above market rates for similar leased assets and the Company recorded an intangible asset of $1.1 million for this premium which is being amortized as a reduction to lease revenue over the remaining lease term. See Note 12 below for further information as to the intangible asset.

On November 1, 2012 the Company entered into a definitive Purchase Agreement with PNM to sell the Company’s 40 percent undivided interest in the EIP upon termination of the PNM Lease Agreement on April 1, 2015 for $7.7 million. Upon execution of the Agreement, the schedule of the lease payments under the PNM Lease Agreement was changed so that the last scheduled semi-annual lease payment was received by the Company on October 1, 2012. Additionally, PNM's remaining basic lease payments due to the Company were accelerated. The semi-annual payments of approximately $1.4 million that were originally scheduled to be paid on April 1, and October 1, 2013, were received by the Company on November 1, 2012. The three remaining lease payments due April 1, 2014, October 1, 2014 and April 1, 2015 were paid in full on January 2, 2014, a portion of which is reported as an unearned revenue liability within the Consolidated Balance Sheets. The amount of revenue included in lease revenue on the consolidated statements of income is $638 thousand for the three month periods ended September 30, 2014 and 2013. For the nine month periods ended September 30, 2014 and 2013, revenue of $1.9 million was included lease revenue on the income statement.

PNM Resources is currently subject to the reporting requirements of the Exchange Act and is required to file with the SEC annual reports containing audited financial statements and quarterly reports containing unaudited financial statements. The audited financial statements and unaudited financial statements of PNM Resources can be found on the SEC's web site at www.sec.gov. The Company makes no representation as to the accuracy or completeness of the audited and unaudited financial statements of PNM Resources but has no reason to doubt the accuracy or completeness of such information. In addition, PNM Resources has no duty, contractual or otherwise, to advise the Company of any events that might have occurred subsequent to the date of such financial statements which could affect the significance or accuracy of such information. None of the information in the public reports of PNM Resources that are filed with the SEC is incorporated by reference into, or in any way form, a part of this filing.

The future contracted minimum rental receipts for all net leases as of September 30, 2014 are as follows:



Future Minimum Lease Receipts
Years Ending December 31,	Amount
2014	$	6,463,288
2015	25,547,516
2016	25,547,516
2017	25,547,516
2018	25,547,516
Thereafter	242,411,842
Total	$	351,065,194

5. FINANCING NOTES RECEIVABLE

On March 13, 2014, our wholly-owned subsidiary, Corridor Bison, LLC ("Corridor Bison") entered into a Loan Agreement with Black Bison Water Services, LLC ("Black Bison WS"). Black Bison WSs initial Loan draw in the amount of $4.3 million was used to acquire real property in Wyoming and to pay Loan transaction expenses. Corridor Bison agreed to loan Black Bison WS up to $11.5 million (the "Black Bison Loan") to finance the acquisition and development of real property that will provide water sourcing, water disposal, or water treating and recycling services for the oil and natural gas industry.

On July 23, 2014, the Company increased its secured financing to Black Bison WS from $11.5 million to $15.3 million. The Company executed an amendment to the Loan Agreement to increase the loan to $12 million, and entered into an additional loan for $3.3 million from a taxable REIT subsidiary of the Company, CorEnergy BBWS, Inc. ("CorEnergy BBWS"), on substantially the same terms (the "TRS Loan" and, together with the Black Bison Loan, as amended, the "Loans"). The purpose of the increase in the secured financing was to fund the acquisition and development of real property and related equipment that will provide water sourcing, water disposal, or water treating and recycling services for the oil and natural gas industry. There were no other material changes to the terms of the Loan Agreement. In connection with the Amendment and the TRS Loan, the Company fully funded the remainder of the $15.3 million capacity of the combined Loans.

Interest will initially accrue on the outstanding principal amount of both Loans at an annual base rate of 12 percent, which base rate will increase by 2 percent of the current base rate per year. In addition, starting in April 2015 and continuing for each month thereafter, the outstanding principal of the Loans will bear variable interest calculated as a function of the increase in volume of water treated by Black Bison WS during the particular month. The base interest plus variable interest, paid monthly, is capped at 19 percent per annum. The Loans mature on March 31, 2024 and are to be amortized by quarterly payments beginning March 31, 2015 and annual prepayments based upon free cash flows of the Borrower and its affiliates commencing in April 2015. The Loans are secured by the real property and equipment held by Black Bison WS and the outstanding equity in Black Bison WS and its affiliates. The Loans are also guarantied by all affiliates of Black Bison WS. The Company believes the notes receivable are fully collectible as of September 30, 2014.

As a condition to the Black Bison Loan, Corridor Bison acquired a Warrant to purchase a number of equity units, which as of March 13, 2014 represented 15 percent of the outstanding equity of Black Bison Intermediate Holdings, LLC ("Intermediate Holdings"). Corridor Bison paid $34 thousand for the Warrant, which amount was determined to represent the fair value of the Warrant as of the date of purchase. The exercise price of the Warrant, $3.16 per unit, was determined based on the value of 15 percent of the contributed capital of Intermediate Holdings as of the date of purchase. The exercise price increases at a rate of 12 percent per annum. The Warrant grants to the holder certain rights with respect to the management of Intermediate Holdings and Black Bison WS.

In anticipation of the July 2014 modifications to the Black Bison agreements described above, Corridor Bison assigned to CorEnergy BBWS its rights and obligations in the Warrant dated March 13, 2014. As a condition of the TRS Loan, the parties entered into an Amended and Restated Warrant, pursuant to which the amount available to purchase thereunder was increased to a number of equity units, which as of July 23, 2014 represented 18.72 percent of the outstanding equity of Intermediate Holdings. CorEnergy BBWS paid an additional $51 thousand for this increase in the amount that could be purchased pursuant to the Amended and Restated Warrant. The amount paid was determined to be the current value of the incremental amount that could be purchased under the Amended and Restated Warrant.

6. VARIABLE INTEREST ENTITIES

The Company's variable interest in Variable Interest Entities ("VIE" or "VIEs") currently are in the form of equity ownership and loans provided by the Company to a VIE. The Company examines specific criteria and uses its judgment when determining if the Company is the primary beneficiary of a VIE and is therefore required to consolidate the investments. Factors considered in determining whether the Company is the primary beneficiary include risk- and reward-sharing, experience and financial condition of the other partner(s), voting rights, involvement in day-to-day capital and operating decisions, representation on a VIE's executive committee or Board of Directors, whether or not the Company has the power to direct the activities of the VIE that most significantly impact the VIE's economic performance, existence of unilateral kick-out rights or voting rights, and level of economic disproportionality between the Company and the other partner(s).

Consolidated VIEs

As of September 30, 2014, the Company does not have any investments in VIEs that qualify for consolidation.

Unconsolidated VIE

At September 30, 2014, the Company's recorded investment in Black Bison WS and Intermediate Holdings, collectively a VIE that is unconsolidated, was $16.0 million. The Company's maximum exposure to loss associated with the investment is limited to the Company's outstanding note receivable, related accrued interest receivable and the purchase price paid for the Warrant, discussed in Note 5, totaling $16.0 million. While this entity is a VIE, the Company has determined that the power to direct the activities of the VIE that most significantly impact the VIE's economic performance is not held by the Company, therefore the VIE is not consolidated.

7. INCOME TAXES

Deferred income taxes reflect the net tax effect of temporary differences between the carrying amount of assets and liabilities for financial reporting and tax purposes. Components of the Company’s deferred tax assets and liabilities as of September 30, 2014 and December 31, 2013 are as follows:



Deferred Tax Assets and Liabilities
	September 30, 2014			December 31, 2013
Deferred Tax Assets:
Net operating loss carryforwards	$	(137,793	)	$	(65,248	)
Cost recovery of leased and fixed assets	(896,700		)	(966,914		)
Sub-total	$	(1,034,493	)	$	(1,032,162	)
Deferred Tax Liabilities:
Basis reduction of investment in partnerships	$	5,633,662		$	6,335,805
Net unrealized gain on investment securities	974,064			28,444
Sub-total	6,607,726			6,364,249
Total net deferred tax liability	$	5,573,233		$	5,332,087

For the period ended September 30, 2014, the total deferred tax liability presented above relates to assets held in the Company's TRSs. The Company recognizes the tax benefits of uncertain tax positions only when the position is “more likely than not” to be sustained upon examination by the tax authorities based on the technical merits of the tax position. The Company’s policy is to record interest and penalties on uncertain tax positions as part of tax expense. As of September 30, 2014, the Company had no uncertain tax positions and no penalties and interest were accrued. Tax years subsequent to the year ending November 30, 2006 remain open to examination by federal and state tax authorities.

Total income tax expense differs from the amount computed by applying the federal statutory income tax rate of 35 percent for the three and nine months ended September 30, 2014 and September 30, 2013 to income or loss from operations and other income and expense for the years presented, as follows:



Income Tax Expense (Benefit)
	For the Three Months Ended					For the Nine Months Ended
	September 30, 2014			September 30, 2013		September 30, 2014			September 30, 2013
Application of statutory income tax rate	$	775,982		$	540,602	$	3,004,593		$	1,851,535
State income taxes, net of federal tax benefit	15,321			120,139		118,090			191,978
Federal Tax Attributable to Income of Real Estate Investment Trust	(466,420		)	444,384		(1,541,408		)	324,310
Total income tax expense	$	324,883		$	1,105,125	$	1,581,275		$	2,367,823

Total income taxes are computed by applying the federal statutory rate of 35 percent plus a blended state income tax rate, which was approximately 3.11 percent for the three and nine months ended September 30, 2014 and 2.26 percent for the three and nine months ended September 30, 2013. CorEnergy BBWS does pay any state taxes because it operates only in Wyoming, which does not have state income tax. Because Mowood operates only in the state of Missouri, a blended state income tax rate of 5 percent was used for the operations of our Mowood TRS for the three and nine months ended September 30, 2014 and 2013. The restructuring done in December 2012 causes us to hold and operate certain of our assets through one or more TRSs. A TRS is a subsidiary of a REIT that is subject to applicable corporate income tax. For the three and nine months ended September 30, 2014, all of the income tax expense presented above relates to the assets and activities held in the Company's TRSs.The components of income tax expense include the following for the periods presented:



Components of Income Tax Expense (Benefit)
	For the Three Months Ended						For the Nine Months Ended
	September 30, 2014			September 30, 2013			September 30, 2014		September 30, 2013
Current tax expense (benefit)
Federal	$	446,391		$	(665,471	)	$	1,230,768	$	149,550
State (net of federal tax benefit)	39,663			(14,810		)	109,361		37,817
Total current tax expense (benefit)	486,054			(680,281		)	1,340,129		187,367
Deferred tax expense (benefit)
Federal	(136,829		)	1,650,457			232,417		2,026,295
State (net of federal tax benefit)	(24,342		)	134,949			8,729		154,161
Total deferred tax expense (benefit)	(161,171		)	1,785,406			241,146		2,180,456
Total income tax expense, net	$	324,883		$	1,105,125		$	1,581,275	$	2,367,823

As of December 31, 2013, the TRSs had a net operating loss for federal income tax purposes of approximately $160 thousand. The net operating loss may be carried forward for 20 years. If not utilized, this net operating loss will expire in the year ending December 31, 2033. A total Net Operating Loss of approximately $182 thousand has been incurred by the TRSs for the nine months ended September 30, 2014.

The aggregate cost of securities for federal income tax purposes and securities with unrealized appreciation and depreciation, were as follows:



Aggregate Cost of Securities for Income Tax Purposes
	September 30, 2014		December 31, 2013
Aggregate cost for federal income tax purposes	$	8,436,355	$	6,604,635
Gross unrealized appreciation	16,984,522		16,699,686
Net unrealized appreciation	$	16,984,522	$	16,699,686

8. PROPERTY AND EQUIPMENT

Property and equipment consists of the following:



Property and Equipment
	September 30, 2014			December 31, 2013
Natural gas pipeline	$	5,215,424		$	5,215,424
Vehicles and trailers	128,958			125,117
Computers	15,627			15,627
Gross property and equipment	5,360,009			5,356,168
Less: accumulated depreciation	(2,243,135		)	(2,037,685		)
Net property and equipment	$	3,116,874		$	3,318,483

The amounts of depreciation of property and equipment recognized for each of the three-month periods ended September 30, 2014 and 2013 was $71 thousand. The amount of depreciation of the property and equipment recognized for the nine-month periods ending September 30, 2014 and 2013 was $213 thousand and $212 thousand, respectively.

9. CONCENTRATIONS

Prior to 2013, the Company had historically invested in securities of privately-held and publicly-traded companies in the midstream and downstream segments of the U.S. energy infrastructure sector. As of September 30, 2014, investments in securities of energy infrastructure companies represented approximately 8 percent of the Company’s total assets. Subsequent to September 30, 2014, the Company liquidated its investment in VantaCore Partners LP as a result of the acquisition of VantaCore by Natural Resource Partners L.P., thereby reducing its remaining investments in securities of energy infrastructure companies. See Note 17 to the Consolidated Financial Statements included in this report for additional information. The Company is now focused on identifying and acquiring real property assets in the U.S. energy infrastructure sector that are REIT-qualified.

Mowood, a wholly-owned TRS of the Company, has a ten-year contract, expiring on January 31, 2015, with the Department of Defense (“DOD”) to provide natural gas and gas distribution services to Fort Leonard Wood. On October 21, 2014, the DOD formally solicited qualifications and proposals from other parties that may be interested in providing the services Omega currently provides. In this solicitation, the DOD states that Omega is the owner of the distribution system, and that any interested party must have a feasible plan to either procure the existing system from Omega, partner with Omega, install a new natural gas distribution system or create another alternative to natural gas. It also states that if no acceptable alternatives come forward, it is the DOD’s intent to award a new 10 year contract to Omega. Based on theses statements from the DOD and its knowledge of the local market, Mowood currently expects that an additional ten-year term will be agreed to by the DOD in second quarter 2015. The DOD expects that the solicitation and contract negotiation process it has undertaken will go beyond January 31, 2015. Accordingly, the DOD and Omega expect to agree to a 90 day bridge extension of the current agreement for Omega to continue providing natural gas and gas distribution services until a new agreement is reached.

Revenue related to the DOD contract accounted for 85 percent and 88 percent of our sales revenue for the three and nine months ended September 30, 2014, respectively, as compared to 64 percent and 79 percent for the three and nine months ended September 30, 2013, respectively. Mowood, through its wholly-owned subsidiary Omega, performs management and supervision services related to the expansion of the natural gas distribution system used by the DOD. The amount due from the DOD accounts for 83 percent and 91 percent of the consolidated accounts receivable balances at September 30, 2014 and December 31, 2013, respectively.

Mowood’s contracts for its supply of natural gas are concentrated among select providers. Purchases from its largest supplier of natural gas accounted for 40 percent and 63 percent of our cost of sales for the three and nine months ended September 30, 2014. This compares to 34 percent and 32 percent for the three and nine months ended September 30, 2013.

10. MANAGEMENT AND ADVISORY AGREEMENTS

On December 1, 2011, the Company executed a Management Agreement with Corridor InfraTrust Management, LLC (“Corridor”). Under the Management Agreement, Corridor (i) presents the Company with suitable acquisition opportunities consistent with the investment policies and objectives of the Company, (ii) is responsible for the day-to-day operations of the Company, and (iii) performs such services and activities relating to the assets and operations of the Company as may be appropriate. A new Management Agreement between the Company and Corridor was approved by the Board of Directors and became effective July1, 2013. The new agreement does not change in any respect the terms for determination or payment of compensation for the Manager, does not have a specific term, and will remain in place unless terminated by the Company or the Manager in the manner permitted pursuant to the agreement. The new management agreement was amended as of January 1, 2014 to change the methodology for calculating the quarterly management fee. The new method is not expected to have a material impact on the compensation payable to the manager.

The terms of the Management Agreement include a quarterly management fee equal to 0.25 percent (1.00 percent annualized) of the value of the Company’s Managed Assets as of the end of each quarter. For purposes of the Management Agreement, “Managed Assets” means the total assets of the Company (including any securities receivables, other personal property or real property purchased with or attributable to any borrowed funds) minus (A) the initial invested value of all non-controlling interests, (B) the value of any hedged derivative assets, (C) any prepaid expenses, and (D) all of the accrued liabilities other than (1) deferred taxes and (2) debt entered into for the purpose of leverage. For purposes of the definition of Managed Assets, the Company’s securities portfolio will be valued at then current market value. For purposes of the definition of Managed Assets, other personal property and real property assets will include real and other personal property owned and the assets of the Company invested, directly or indirectly, in equity interests in or loans secured by real estate or personal property (including acquisition related costs and acquisition costs that may be allocated to intangibles or are unallocated), valued at the aggregate historical cost, before reserves for depreciation, amortization, impairment charges or bad debts or other similar noncash reserves.

The Management Agreement includes a quarterly incentive fee of 10 percent of the increase in distributions paid over a threshold distribution equal to $0.125 per share per quarter. The Management Agreement also requires at least half of any incentive fees to be reinvested in the Company’s common stock.

The Company pays Corridor, as the Company's Administrator pursuant to an Administrative Agreement, a fee equal to an annual rate of 0.04 percent of managed assets, with a minimum annual fee of $30 thousand.

Tortoise Capital Advisors, L.L.C. (“TCA”) is compensated by Corridor to provide investment services related to the monitoring and disposition of our current securities portfolio.

U.S. Bancorp Fund Services, LLC serves as the Company’s fund accounting services provider. The Company pays the provider a monthly fee computed at an annual rate of $24 thousand on the first $50 million of the Company’s Net Assets, 0.0125 percent on the next $200 million of Net Assets, 0.0075 percent on the next $250 million of Net Assets and 0.0025 percent on the balance of the Company’s Net Assets.

11. FAIR VALUE OF OTHER SECURITIES

The inputs or methodology used for valuing securities and financial instruments are not necessarily an indication of the risk associated with investing in those securities or financial instruments. The following tables provide the fair value measurements of applicable Company assets and liabilities by level within the fair value hierarchy as of September 30, 2014, and December 31, 2013. These assets and liabilities are measured on a recurring basis.



September 30, 2014
	September 30, 2014		Fair Value
	September 30, 2014		Level 1		Level 2		Level 3
Assets:
Other equity securities	$	25,420,877	$	—	$	—	$	25,420,877
Warrant Investment	508,000		—		—		508,000
Total Assets	$	25,928,877	$	—	$	—	$	25,928,877



December 31, 2013
	December 31, 2013		Fair Value
	December 31, 2013		Level 1		Level 2		Level 3
Assets:
Other equity securities	$	23,304,321	$	—	$	—	$	23,304,321
Total Assets	$	23,304,321	$	—	$	—	$	23,304,321

The changes for all Level 3 securities measured at fair value on a recurring basis using significant unobservable inputs for the nine months ended September 30, 2014 and September 30, 2013 are as follows:



Level 3 Rollforward
For the Nine Months Ended 9/30/14	Fair Value Beginning Balance		Acquisitions⁽²⁾		Total Realized and Unrealized Gains Included in Net Income		Return of Capital Adjustments Impacting Cost Basis of Securities			Fair Value Ending Balance		Changes in Unrealized Gains, Included In Net Income, Relating to Securities Still Held ⁽¹⁾
Other equity securities	$	23,304,321	$	—	$	2,990,376	$	(873,820	)	$	25,420,877	$	2,990,376
Warrant investment	—		122,500		385,500		—			508,000		385,500
Total	$	23,304,321	$	122,500	$	3,375,876	$	(873,820	)	$	25,928,877	$	3,375,876
For the Nine Months Ended 9/30/13
Other equity securities	$	19,707,126	$	—	$	3,509,432	$	(1,048,290	)	$	22,168,268	$	3,509,432
Warrant investment	—		—		—		—			—		—
Total	$	19,707,126	$	—	$	3,509,432	$	(1,048,290	)	$	22,168,268	$	3,509,432

(1) Located in Net realized and unrealized gain on other equity securities in the Consolidated Statements of Income

(2) Includes capitalized costs in addition to the purchase price

The Company utilizes the beginning of reporting period method for determining transfers between levels. There were no transfers between levels 1, 2 or 3 for the three- and nine-month periods ended September 30, 2014 and September 30, 2013.

Valuation Techniques and Unobservable Inputs

An equity security of a publicly traded company acquired in a private placement transaction without registration under the Securities Act of 1933, as amended (the “1933 Act”), is subject to restrictions on resale that can affect the security’s liquidity (and hence its fair value). If the security has a common share counterpart trading in a public market, the Company generally determines an appropriate percentage discount for the security in light of the restrictions that apply to its resale (taking into account, for example, whether the resale restrictions of Rule 144 under the 1933 Act apply). This pricing methodology applies if the Company has Level 2 trading securities.

The Company’s other equity securities, which represent securities issued by private companies, are classified as Level 3 assets. Valuation of these investments is determined by weighting various valuation metrics for each security. Significant judgment is required in selecting the assumptions used to determine the fair values of these investments. See Note 2, Significant Accounting Policies, for additional discussion.

For the year ended December 31, 2013, the Company’s investments in private companies were valued using one or a combination of the following valuation techniques: (i) analysis of valuations for publicly traded companies in a similar line of business (“public company analysis”), (ii) analysis of valuations for comparable M&A transactions (“M&A analysis”) and (iii) discounted cash flow analysis.

The public company analysis utilizes valuation multiples for publicly traded companies in a similar line of business as the portfolio company to estimate the fair value of such investment. Typically, the Company’s analysis focuses on the ratio of enterprise value to earnings before interest expense, income tax expense, depreciation and amortization (“EBITDA”) which is commonly referred to as an EV/EBITDA multiple. The Company selects a range of multiples given the trading multiples of similar publicly traded companies and applies such multiples to the portfolio company’s EBITDA to estimate the portfolio company’s trailing, proforma, projected or average (as appropriate) EBITDA to estimate the portfolio company’s enterprise value and equity value. The Company also selects a range of trading market yields of similar public companies and applies such yields to the portfolio company’s estimated distributable cash flow. When calculating these values, the Company applies a discount, when applicable, to the portfolio company’s estimated equity value for the size of the company and the lack of liquidity in the portfolio company’s securities.The M&A analysis utilizes valuation multiples for historical M&A transactions for companies or assets in a similar line of business as the portfolio company to estimate the fair value of such investment. Typically, the Company’s analysis focuses on EV/EBITDA multiples. The Company selects a range of multiples based on EV/EBITDA multiples for similar M&A transactions or similar companies and applies such ranges to the portfolio company’s analytical EBITDA to estimate the portfolio company’s enterprise value.

The discounted cash flow ("DCF") analysis is used to estimate the equity value for the portfolio company based on estimated DCF of such portfolio company. Such cash flows include an estimate of terminal value for the portfolio company. A present value of these cash flows is determined by using estimated discount rates (based on the Company’s estimate for weighted average cost of capital for such portfolio company).

Under all of these valuation techniques, the Company estimated operating results of its portfolio companies (including EBITDA). These estimates utilize unobservable inputs such as historical operating results, which may be unaudited, and projected operating results, which were based on expected operating assumptions for such portfolio company. The Company also consulted with management of the portfolio companies to develop these financial projections. These estimates were sensitive to changes in assumptions specific to such portfolio company as well as general assumptions for the industry. Other unobservable inputs utilized in the valuation techniques outlined above include: possible discounts for lack of marketability, selection of publicly-traded companies, selection of similar M&A transactions, selected ranges for valuation multiples, selected range of yields and expected required rates of return and weighted average cost of capital. The various inputs were weighted as appropriate, and other factors may have been weighted into the valuation, including recent capital transactions of the Company.

Changes in EBITDA multiples, or discount rates may change the fair value of the Company’s portfolio investments. Generally, a decrease in EBITDA multiples or DCF multiples, or an increase in discount rates, when applicable, may result in a decrease in the fair value of the Company’s portfolio investments.

For the nine months ended September 30, 2014, the Company’s investments in private companies were valued using one or a combination of the following valuation techniques: (i) public share price of private companies investments, discounted for a lack of marketability, (ii) recent sales price of private companies, discounted for any lack of marketability or liquidity due to an earn out or escrow agreement and (iii) discounted cash flow analysis. Due to the inherent uncertainty of determining the fair value of investments that do not have a readily available market value, the fair value of the Company’s investments may fluctuate from period to period. Additionally, the fair value of the Company’s investments may differ from the values that would have been used

had a ready market existed for such investments and may differ materially from the values that the Company may ultimately realize.

As of both September 30, 2014 and December 31, 2013, the Company held a 6.7 percent equity interest in Lightfoot Capital Partners LP ("Lightfoot") and an 11.1 percent equity interest in VantaCore Partners LP ("VantaCore"). Please see Note 17 to these Consolidated Financial Statements and the Asset Portfolio and Related Developments section of Management's Discussion and Analysis for more detail relating to the sale of VantaCore on October 1, 2014.

Certain condensed combined financial information of the unconsolidated affiliates, Lightfoot and VantaCore, is presented in the following tables.



Assets	September 30, 2014		December 31, 2013
Current assets	$	60,451,310	$	50,545,378
Noncurrent assets	550,676,592		554,029,979
Total Assets	$	611,127,902	$	604,575,357
Liabilities
Current liabilities	$	33,630,413	$	29,159,353
Noncurrent liabilities	193,522,187		185,653,304
Total Liabilities	$	227,152,600	$	214,812,657

Partner's equity	383,975,302		389,762,700
Total liabilities and partner's equity	$	611,127,902	$	604,575,357



	For the Three Months Ending					For the Nine Months Ending
	September 30, 2014		September 30, 2013			September 30, 2014		September 30, 2013
Revenues	$	48,289,666	$	40,481,062		$	124,727,402	$	106,112,586
Operating expenses	42,443,219		34,175,660			112,883,618		91,022,483
Other income (expenses)	673,479		(1,124,731		)	4,868,653		7,995,030
Net income	$	6,519,926	$	5,180,671		$	16,712,437	$	23,085,133

EBITDA	$	14,005,447	$	12,943,273		$	41,113,399	$	45,701,881

For the nine months ended September 30, 2014, the Company’s Warrant Investment was valued using the Black-Scholes model. The Black-Scholes model incorporates the fair value of the business, the time value of money, the option's strike price, volatility of business and the time to the option's expiry. Due to the inherent uncertainty of determining the fair value of Warrant investments that do not have a readily available market value, the fair value of the Company’s warrant investments may fluctuate from period to period. Additionally, the fair value of the Company’s warrant investments may differ from the values that would have been used had a ready market existed for such investments and may differ materially from the values that the Company may ultimately realize.

The following section describes the valuation methodologies used by the Company for estimating fair value for financial instruments not recorded at fair value, but fair value is included for disclosure purposes only, as required under disclosure guidance related to the fair value of financial instruments.

Cash and Cash Equivalents — The carrying value of cash, amounts due from banks, federal funds sold and securities purchased under resale agreements approximates fair value.

Financing Notes Receivable — Based on the interest rates for similar financial instruments, the carrying value of the financing notes receivable are considered to approximate fair value.

Long-term Debt — The fair value of the Company’s long-term debt is calculated, for disclosure purposes, by discounting future cash flows by a rate equal to the Company’s current expected rate for an equivalent transaction.

Line of Credit — The carrying value of the line of credit approximates the fair value due to its short-term nature.



Carrying and Fair Value Amounts
	Level within fair value hierarchy	September 30, 2014				December 31, 2013
	Level within fair value hierarchy	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Financial Assets:
Cash and cash equivalents	Level 1	$	5,476,216	$	5,476,216	$	17,963,266	$	17,963,266
Financing notes receivable	Level 2	$	15,510,956	$	15,510,956	$	—	$	—
Financial Liabilities:
Long-term debt	Level 2	$	67,942,000	$	67,942,000	$	70,000,000	$	70,000,000
Line of credit	Level 1	$	—	$	—	$	81,935	$	81,935

12. INTANGIBLES

The Company has recorded an intangible lease asset, related to the PNM Lease Agreement, for the fair value of the amount by which the remaining contractual lease payments exceeded market lease rates at the time of acquisition. The intangible lease asset is being amortized on a straight-line basis over the life of the lease term, which expires on April 1, 2015. Quarterly amortization of the intangible lease asset, totaling $73 thousand for each of the three months ended September 30, 2014 and September 30, 2013, and $219 thousand for each of the nine months ended September 30, 2014 and September 30, 2013, is reflected in the accompanying Consolidated Statements of Income as a reduction to lease revenue. This amount is included in amortization expense in the accompanying Consolidated Statements of Cash Flows. Refer to Note 4 for further discussion around the PNM Purchase Agreement.



Intangible Lease Asset
	September 30, 2014			December 31, 2013
Intangible lease asset	$	1,094,771		$	1,094,771
Accumulated amortization	(948,800		)	(729,847		)
Net intangible lease asset	$	145,971		$	364,924



Remaining Estimated Amortization On Intangibles
Year ending December 31,	Amount
2014	$	72,986
2015	72,985
Total	$	145,971

13. CREDIT FACILITIES

On December 20, 2012, Pinedale LP closed on a $70 million secured term credit facility with KeyBank serving as a lender and as administrative agent on behalf of other lenders participating in the credit facility. Funding of the credit facility was conditioned on our contribution to Pinedale LP of the proceeds of a related stock issuance financing a portion of the acquisition cost of the Pinedale LGS and the receipt by Pinedale LP of the related $30 million co-investment funds from Prudential. Outstanding balances under the credit facility will generally accrue interest at a variable annual rate equal to LIBOR plus 3.25 percent (3.40 percent as of September 30, 2014). The credit facility will remain in effect through December 2015, with an option to extend through December 2016. Principal payments totaling $2.9 million and $3.5 million are required during the years 2014 and 2015, respectively. The credit facility is secured by the Pinedale LGS. Pinedale LP is obligated to pay all accrued interest monthly and is further obligated to make monthly principal payments, which began March 7, 2014, in the amount of $294 thousand or 0.42 percent of the principal balance as of March 1, 2014. The credit agreement contains, among other restrictions, specific financial covenants including the maintenance of certain financial coverage ratios and a minimum net worth requirement. Additionally, the registrant has provided to KeyBank a guarantee against certain inappropriate conduct by or on behalf of Pinedale LP or us. Pinedale LP is required to maintain a restricted collateral account into which Ultra Wyoming makes all lease payments under the Pinedale Lease Agreement. Payments of principal and interest pursuant to the credit facility are drawn by KeyBank directly from the restricted collateral account prior to transferring the remaining cash to the Pinedale LP operating account. The balance in the restricted collateral account at September 30, 2014 was $0. As of September 30, 2014, Pinedale LP was in compliance with all of the financial covenants of the secured term credit facility.

Pinedale LP's credit facility with KeyBank limits distributions by Pinedale LP to the Company. Now that the Company has qualified as a REIT under the Code, distributions by Pinedale LP to the Company are permitted to the extent required for the Company to

maintain its REIT qualification, so long as Pinedale LP's obligations to KeyBank have not been accelerated following an Event of Default (as defined in the credit facility). The KeyBank credit facility also requires that Pinedale LP maintain minimum net worth levels and certain leverage ratios, which along with other provisions of the credit facility limit cash dividends and loans to the Company.

As of September 30, 2014 and December 31, 2013 approximately $630 thousand and $1.0 million, respectively, in net deferred debt issuance costs related to the KeyBank credit facility are included in the accompanying Consolidated Balance Sheets. The deferred costs will be amortized over the anticipated three-year term of the KeyBank credit facility. For the three months ended September 30, 2014 and 2013, $129 thousand is included in interest expense within the accompanying Consolidated Statements of Income. For the nine months ended September 30, 2014 and 2013, $387 thousand and $385 thousand, respectively, are included in interest expense within the accompanying Consolidated Statements of Income.

We have executed interest rate swap derivatives to add stability to our interest expense and to manage our exposure to interest rate movements on our LIBOR based borrowings. Interest rate swaps involve the receipt of variable-rate amounts from a counterparty in exchange for us making fixed-rate payments over the life of the agreements without exchange of the underlying notional amount. See Note 14 for further information regarding interest rate swap derivatives.

On May 8, 2013, the Company entered into a $20 million revolving line of credit with KeyBank. The primary term of the facility was three years with the option for a one-year extension. Outstanding balances under the revolving credit facility (the "KeyBank Revolver") accrued interest at a variable annual rate equal to LIBOR plus 4.0 percent or the Prime Rate plus 2.75 percent. The facility was for the purpose of funding general working capital needs and if necessary, to provide short-term financing for the acquisition of additional real property assets. The amount available to be drawn under this facility was subject to a borrowing base limitation. As of September 30, 2014 , there had been no borrowings against the KeyBank Revolver. The agreement was terminated on September 26, 2014.

As of September 30, 2014 and December 31, 2013, approximately $0 and $208 thousand, respectively, in net deferred debt issuance costs, related to the KeyBank Revolver, are included in the accompanying Consolidated Balance Sheets. The deferred costs were initially amortized over the anticipated four-year term of the KeyBank Revolver facility. For the three months ended September 30, 2014 and 2013, approximately $16 thousand and $0, respectively, is included in interest expense within the accompanying Consolidated Statements of Income. For the nine months ended September 30, 2014 and 2013, approximately $47 thousand and $0, respectively, is included in interest expense within the accompanying Consolidated Statements of Income. Upon termination, the remaining unamortized deferred debt issuance costs totaling approximately $161 thousand were expensed in full.

On September 26, 2014 the company entered into a $30 million revolving credit facility (the "Regions Revolver") with Regions Bank. The credit facility has a maturity of September 26, 2018. For the first six months the facility will bear interest on the outstanding balance at a rate of LIBOR plus 4.00 percent. On March 26, 2015 the interest rate will be determined by a grid anticipated to be LIBOR plus 3.25 percent to 4.00 percent. As of September 30, 2014 and December 31, 2013 approximately, $452 thousand and $0, respectively, in net deferred debt issuance costs related to the Regions Bank credit facility are included in the accompanying Consolidated Balance Sheets. For the three and nine months ended September 30, 2014 and 2013, approximately $0, is included in interest expense within the accompanying Consolidated Statements of Income. As of September 30, 2014, there had been no borrowings against the Regions Revolver.

On October 29, 2010, Mowood entered into a Revolving Note Payable Agreement (“2010 Note Payable Agreement”) with a financial institution with a maximum borrowing base of $1.3 million. Borrowings on the 2010 Note Payable Agreement, as amended and restated, were secured by all of Mowood’s assets. Interest accrued at LIBOR, plus 4 percent, was payable monthly, with all outstanding principal and accrued interest payable on the termination date of October 29, 2013.

On October 15, 2013, Mowood entered into a Revolving Note Payable Agreement (“2013 Note Payable Agreement”) with a financial institution with a maximum borrowing base of $1.5 million. Borrowings on the 2013 Note Payable Agreement are secured by Mowood’s assets. Interest accrues at Prime Lending Rate as published in the Wall Street Journal, plus 0.5 percent (3.75 percent as of September 30, 2014), is payable monthly, with all outstanding principal and accrued interest payable on the termination date of October 15, 2014. As of September 30, 2014 there was $0 in outstanding borrowings under this 2013 Note Payable Agreement. The 2013 Note Payable Agreement contains various restrictive covenants, with the most significant relating to minimum consolidated fixed charge ratio, the incidence of additional indebtedness, member distributions, extension of guaranties, future investments in other subsidiaries and change in ownership. Mowood was in compliance with the various covenants of the 2013 Note Payable Agreement as of September 30, 2014. For additional information, see Note 17 of the Notes to the Consolidated Financial Statements.

14. INTEREST RATE HEDGE SWAPS

Derivative financial instruments

Currently, the Company uses interest rate swaps to manage its interest rate risk. The valuation of these instruments is determined using widely accepted valuation techniques including discounted cash flow analysis on the expected cash flows of each derivative. This analysis reflects the contractual terms of the derivatives, including the period to maturity, and uses observable market-based inputs, including forward interest rate curves. The fair values of interest rate swaps are determined using the market standard methodology of netting the discounted future fixed cash payments and the discounted expected variable cash receipts. The variable cash receipts are based on an expectation of future interest rates (forward curves) derived from observable market interest rate forward curves.

To comply with the provisions of ASC 820, the Company incorporates credit valuation adjustments to appropriately reflect both its own nonperformance risk and the respective counterparty's nonperformance risk in the fair value measurements. In adjusting the fair value of its derivative contracts for the effect of nonperformance risk, the Company has considered the impact of netting and any applicable credit enhancements, such as collateral postings, thresholds, mutual puts, and guarantees. In conjunction with the FASB's fair value measurement guidance in ASC 820, the Company made an accounting policy election to measure the credit risk of its derivative financial instruments that are subject to master netting agreements on a net basis by counterparty portfolio.

Although the Company has determined that the majority of the inputs used to value its derivatives fall within Level 2 of the fair value hierarchy, the credit valuation adjustments associated with its derivatives utilize Level 3 inputs, such as estimates of current credit spreads to evaluate the likelihood of default by itself and its counterparties. However, as of September 30, 2014, the Company has assessed the significance of the impact of the credit valuation adjustments on the overall valuation of its derivative positions and has determined that the credit valuation adjustments are not significant to the overall valuation of its derivatives. As a result, the Company has determined that its derivative valuations in their entirety are classified in Level 2 of the fair value hierarchy.

The table below presents the Company's assets and liabilities measured at fair value on a recurring basis as well as their classification on the Consolidated Balance Sheets as of September 30, 2014 and December 31, 2013, aggregated by the level in the fair value hierarchy within which those measurements fall. Hedges that are valued as receivable by the Company are considered Asset Derivatives and those that are valued as payable by the Company are considered Liability Derivatives.



Derivative Financial Instruments Measured At Fair Value on a Recurring Basis
	Balance Sheet Classification	Fair Value Hierarchy
Balance Sheet Line Item	Balance Sheet Classification	Level 1		Level 2		Level 3
		September 30, 2014
Hedged derivative asset	Assets	$	—	$	577,584	$	—

		December 31, 2013
Hedged derivative asset	Assets	$	—	$	680,968	$	—

Level 1 – quoted prices in active markets for identical investments
Level 2 – other significant observable inputs (including quoted prices for similar investments, market corroborated inputs, etc.)
Level 3 – significant unobservable inputs (including the Company’s own assumptions in determining the fair value of investments)

Risk Management Objective of Using Derivatives

The Company is exposed to certain risk arising from both its business operations and economic conditions. The Company principally manages its exposures to a wide variety of business and operational risks through management of its core business activities. The Company manages economic risks, including interest rate, liquidity, and credit risk primarily by managing the amount, sources, and duration of its debt funding and the use of derivative financial instruments. Specifically, the Company enters into derivative financial instruments to manage exposures that arise from business activities that result in the receipt or payment of future known and uncertain cash amounts, the value of which are determined by interest rates. The Company's derivative financial instruments are used to manage differences in the amount, timing, and duration of the Company's known or expected cash receipts and its known or expected cash payments principally related to the Company's investments and borrowings.

Cash Flow Hedges of Interest Rate Risk

The Company's objectives in using interest rate derivatives are to add stability to interest expense and to manage its exposure to interest rate movements. To accomplish this objective, the Company primarily uses interest rate swaps and caps as part of its interest rate risk management strategy. Interest rate swaps designated as cash flow hedges involve the receipt of variable amounts from a counterparty in exchange for the Company making fixed-rate payments over the life of the agreements without exchange of the underlying notional amount. Interest rate caps designated as cash flow hedges involve the receipt of variable amounts from a counterparty if interest rates rise above the strike rate on the contract in exchange for an upfront premium.

The effective portion of changes in the fair value of derivatives designated and that qualify as cash flow hedges is recorded in Accumulated Other Comprehensive Income (“AOCI”) and is subsequently reclassified into earnings in the period that the hedged forecasted transaction affects earnings. The Company elected to designate its interest rate swaps as cash flow hedges in April 2013. During the three and nine months ended September 30, 2014, such derivatives were used to hedge the variable cash flows associated with existing variable-rate debt. The ineffective portion of the change in fair value of the derivatives is recognized directly in earnings. During the three and nine months ended September 30, 2014 there was a gain due to ineffectiveness of approximately $148 and there was a loss due to ineffectiveness of approximately $434, respectively, recorded in earnings resulting from interest rate swaps that did not have a fair value of zero at inception of the hedging relationship. During the three and nine-months ended September 30, 2013 there was a loss due to ineffectiveness of approximately $1 thousand and a gain of $6 thousand due to ineffectiveness, respectively, recorded in earnings resulting from interest rate swaps that did not have a fair value of zero at inception of the hedging relationship.

Amounts reported in AOCI related to derivatives will be reclassified to interest expense as interest payments are made on the Company's variable-rate debt. Over the next 12 months, the Company estimates that an additional $247 thousand will be reclassified as an increase to interest expense.

As of September 30, 2014, the Company had the following outstanding interest rate derivatives that were designated as cash flow hedges of interest rate risk:

Outstanding Derivatives Designated as Cash Flow Hedges of Interest Rate Risk

Interest Rate Derivative

Number of Instruments

Notional Amount Outstanding

Floating Rate Received

Fixed Rate Paid

Effective Date

Termination Date

Interest Rate Swap

$52,500,000

February 5, 2013

December 5, 2017

1-month US Dollar LIBOR

0.865%

Non-Designated Hedges

Derivatives not designated as hedges are not speculative and are used to manage the Company's exposure to interest rate movements and other identified risks. Changes in the fair value of derivatives not designated in hedging relationships are recorded directly in earnings and were equal to a net loss of approximately $0 and $75 thousand for the three and nine months ended September 30, 2013, respectively. As the Company elected to designate its interest rate swaps in cash flow hedging relationships in April 2013 (see Cash Flow Hedges of Interest Rate Risk above), the Company did not have any non-designated hedges as of September 30, 2014.

Tabular Disclosure of the Effect of Derivative Instruments on the Income Statement

The tables below present the effect of the Company's derivative financial instruments on the Income Statement for the three and nine months ended September 30, 2014 and September 30, 2013.



Effect of Derivative Financial Instruments on Income Statement
Derivatives in Cash Flow Hedging Relationships	Amount of Gain (Loss) Recognized in AOCI on Derivative (Effective Portion)						Location of Gain (Loss) Reclassified from AOCI into Net Income (Effective Portion)		Amount of Gain (Loss) Reclassified from AOCI on Derivatives (Effective Portion) Recognized in Net Income *						Location of Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)			Amount of Gain (Loss) Recognized in Income on Derivative (Ineffective Portion, Amounts Excluded from Effectiveness Testing)
Derivatives in Cash Flow Hedging Relationships
For the three months ended:	September 30, 2014			September 30, 2013					September 30, 2014			September 30, 2013						September 30, 2014			September 30, 2013
Interest Rate Products	$	187,642		$	(397,214	)	Interest Expense		$	(77,135	)	$	(72,757	)	Interest Expense			$	148		$	(1,062	)
For the nine months ended:	September 30, 2014			September 30, 2013					September 30, 2014			September 30, 2013						September 30, 2014			September 30, 2013
Interest Rate Products	$	(385,232	)	$	669,674		Interest Expense		$	(228,716	)	$	(142,750	)	Interest Expense			$	(434	)	$	6,098

Derivatives Not Designated as Hedging Instruments	Location of Gain (Loss) Recognized in Income on Derivative						Amount of Gain (Loss) Recognized in Income on Derivative *
							For the Three Months Ended					For the Nine Months Ended
							September 30, 2014		September 30, 2013			September 30, 2014			September 30, 2013
Interest rate contracts	Interest Expense						$	—	$	—		$	—		$	(75,200	)
* The gain or (loss) recognized in income on derivatives includes changes in fair value of the derivatives as well as the periodic cash settlements and interest accruals for derivatives not designated as hedging instruments

Tabular Disclosure of Offsetting Derivatives

The table below presents a gross presentation, the effects of offsetting, and a net presentation of the Company's derivatives as of September 30, 2014 and December 31, 2013. The net amounts of derivative assets or liabilities can be reconciled to the tabular disclosure of fair value. The tabular disclosure of fair value provides the location that derivative assets and liabilities are presented on the Balance Sheet.



Offsetting Derivatives
	Gross Amounts of Recognized Assets		Gross Amounts Offset in the Statement of Financial Position		Net Amounts of Assets presented in the Statement of Financial Position		Gross Amounts Not Offset in the Statement of Financial Position

							Financial Instruments		Cash Collateral Received		Net Amount
Offsetting Derivative Assets as of September 30, 2014	$	577,584	$	—	$	577,584	$	—	$	—	$	577,584

Offsetting Derivative Liabilities as of September 30, 2014	$	—	$	—	$	—	$	—	$	—	$	—

Offsetting Derivative Assets as of December 31, 2013	$	680,968	$	—	$	680,968	$	—	$	—	$	680,968

Offsetting Derivative Liabilities as of December 31, 2013	$	—	$	—