UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

ANNUAL REPORT PURSUANT TO SECTION 13 OR 15 (d) OF

THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended September 30, 2013

Commission File Number: 0-12214

DALECO RESOURCES CORPORATION

(Exact name of registrant as specified in its charter)

Nevada	23-2860734
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

17 Wilmont Mews, 5^thFloor West Chester, Pennsylvania 19382 (Address of principal executive offices) (Zip Code)	(610) 429-0181 (Registrant’s telephone number, including are code)

Securities registered under Section 12(b) of the Act: None

Securities registered under Section 12(g) of the Act:

Common Stock, Par Value $.01

(Title of class)

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes ¨ No x

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or 15 (d) of the Act. Yes ¨ No x

Indicate by check mark whether the issuer (1) 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 ¨ Other than this Form 10-K.

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 if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company.

Large accelerated filer ¨

Accelerated filer ¨

Non-accelerated filer ¨

Smaller reporting company x

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

The aggregate market value of the voting and non-voting common equity held by non-affiliates on March 31, 2013, was approximately $7,900,000. This amount is based on the average bid and asked price of the Registrant’s common stock on the Over the Counter Markets ("OTCQB") on that date. Shares of common stock beneficially held by executive officers and directors of the Registrant are not included in the computation. This determination of affiliate status is not necessarily a conclusive determination for other purposes.

72,468,458 shares of common stock, $0.01 par value, were outstanding on December 31, 2013.

DOCUMENTS INCORPORATED BY REFERENCE - None.

DALECO RESOURCES CORPORATION

FORM 10-K

FOR THE YEAR ENDED SEPTEMBER 30, 2013

TABLE OF CONTENTS

PART I
Item 1.	Business	4
Item 1A.	Risk Factors	17
Item 1B.	Unresolved Staff Comments	17
Item 2.	Properties	17
Item 3.	Legal Proceedings	20
Item 4.	Mine Safety Disclosures	20

PART II
Item 5.	Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	20
Item 6.	Selected Financial Data	25
Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	26
Item 7A.	Quantitative and Qualitative Disclosures about Market Risk	38
Item 8.	Financial Statements and Supplementary Data	39
Item 9.	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	79
Item 9A.	Controls and Procedures	79
Item 9B.	Other Information	80

PART III
Item 10.	Directors, Executive Officers and Corporate Governance	80
Item 11.	Executive Compensation	85
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	94
Item 13.	Certain Relationships and Related Transactions and Director Independence	97
Item 14.	Principal Accounting Fees and Services	100

PART IV
Item 15.	Exhibits, Financial Statement Schedules	102

SIGNATURES		111

	2

CAUTIONARY STATEMENTS REGARDING FORWARD-LOOKING STATEMENTS

Some of the information, including all of the estimates and assumptions, in this report contain forward-looking statements within the meaning of Sections 27A of the Securities Act of 1933, as amended, and 21E of the Securities Exchange Act of 1934, as amended. All statements other than statements of historical fact included in this report, including, but not limited to, statements regarding our future financial position, business strategy, budgets, projected costs, savings and plans, objectives of management for future operations, legal strategies, and legal proceedings, are forward-looking statements. Forward-looking statements generally can be identified by the use of forward-looking terminology such as “may”, “will”, “expect”, “intend”, “estimate”, “anticipate”, “believe”, or “continue” or the negative thereof or variations thereon or similar terminology. Except for statements of historical or present facts, all other statements contained in this report are forward-looking statements. The forward-looking statements may appear in a number of places and include statements with respect to, among other things: business objectives and strategic plans; operating strategies; acquisition strategies; drilling wells; oil and gas reserve estimates (including estimates of future net revenues associated with such reserves and the present value of such future net revenues); estimates of future production of oil, natural gas and minerals; expected results or benefits associated with recent acquisitions; marketing of oil, gas and minerals; expected future revenues and earnings, and results of operations; future capital, development and exploration expenditures; expectations regarding cash flow and future borrowings sufficient to fund ongoing operations and debt service, capital expenditures and working capital requirements; nonpayment of dividends; expectations regarding competition; impact of the adoption of new accounting standards and the Company’s financial and accounting systems; and effectiveness of the Company’s control over financial reporting.

These forward-looking statements are subject to numerous assumptions, risks, and uncertainties. Factors that may cause our actual results, performance, or achievements to be materially different from those anticipated in forward-looking statements include, among others, the following:

	·	adverse economic conditions in the United States and globally;
	·	difficult and adverse conditions in the domestic and global capital and credit markets;
	·	domestic and global demand for oil and natural gas and non-metallic minerals;
	·	volatility of the market prices for crude oil and natural gas and non-metallic minerals;
	·	the effects of government regulation, permitting, and other legal requirements;
	·	the geologic quality of our properties with regard to, among other things, the existence of non-metallic minerals and hydrocarbons in economic quantities;
	·	uncertainties about the estimates of our oil and natural gas reserves and our non-metallic mineral resources;
	·	our ability to increase our production and oil and natural gas income and non-metallic mineral sales through exploration and development;
	·	our ability to successfully apply horizontal drilling techniques and tertiary recovery methods;
	·	the number of well locations to be drilled, the cost to drill, and the time frame within which they will be drilled;
	·	the effects of adverse weather on operations;
	·	drilling and operating risks;
	·	the availability of equipment, such as drilling rigs, transportation pipelines and mining equipment;
	·	changes in our oil and gas drilling and minerals development plans and related budgets;
	·	the adequacy of our capital resources and liquidity including, but not limited to, access to additional borrowing capacity;
	·	uncertainties associated with environmental matters and permitting and other regulations affecting our operations and planned activities; and
	·	uncertainties associated with our legal proceedings and their outcome.

Because forward-looking statements are subject to risks and uncertainties, actual results may differ materially from those expressed or implied by such statements. You are cautioned not to place undue reliance on forward-looking statements, which speak only as of the date of the respective document. Other unknown or unpredictable factors may cause actual results to differ materially from those projected by the forward-looking statements. Most of these factors are difficult to anticipate and may be beyond our control. Unless otherwise required by law, we undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events, or otherwise.

All forward-looking statements attributable to us are expressly qualified in their entirety by these cautionary statements.

	3

PART I

Item 1. Business.

General

Daleco Resources Corporation (“DRC”) is a Nevada corporation (organized in Nevada in 2002). DRC’s Articles provide for, among other things, authorized capital stock of 150 million shares of common stock and 20 million shares of preferred stock. By vote of the shareholders at DRC’s annual meeting on June 20, 2013, DRC’s authorized shares of common stock were increased to 150 million shares from 100 million shares. The Company's (as that term is defined below) segments consist of two separate categories: oil and natural gas and non-metallic minerals. DRC is a holding company whose subsidiaries are engaged in: (i) the exploration, development and production of oil and gas; (ii) the exploration for naturally occurring minerals; (iii) the production of such minerals; and (iv) the marketing and sales of such minerals. DRC’s wholly-owned subsidiaries include: Westlands Resources Corporation (“WRC”); Deven Resources, Inc. (“DRI”); DRI Operating Company, Inc. (“DRIOP”); Tri-Coastal Energy, Inc. (“TCEI”); Clean Age Minerals, Inc. (“CAMI”); CA Properties, Inc. (“CAPI”); International Aggregation and Trading Company, LLC (“IATC”); Sustainable Forest Industries, Inc. (“SFI”); and The Natural Resources Exchange, Inc. (“NREX”) (hereinafter, DRC, WRC, DRI, DRIOP, TCEI, CAMI, CAPI, IATC, SFI and NREC are sometimes collectively referred to as the “Company”). IATC, TCEI, SFI and NREX are inactive.

All of the Company’s oil and gas properties are located onshore within the continental United States of America. The Company, through its wholly-owned subsidiaries, WRC, DRIOP and DRI, owns and operates oil and gas properties located in Pennsylvania, Texas and West Virginia. The Company owns overriding royalty interests in (i) two wells in Pennsylvania and (ii) one well in Texas. The Company does not own working interests in the two wells located in Pennsylvania that it operates.

The Company does not refine any crude oil or market, at retail, any oil or petroleum products. The Company does not own any drilling rigs. All of its drilling activities are performed by independent drilling contractors.

DRI is the managing general partner of Deerlick Royalty Partners I, a Pennsylvania general partnership, which owns overriding royalty interests in seventy wells in the Deerlick Coalbed Methane Field located in Tuscaloosa County, Alabama. DRI is also the sole shareholder of DRIOP which operates wells and has oil and gas interests in West Virginia and Pennsylvania.

As of September 30, 2013, the Company owned working interests in 28 wells in Texas and West Virginia. Throughout the twelve month period beginning October 1, 2012 and ending September 30, 2013 (“2013”), the Company has experienced an average increase of 3% in the unit of production weighted average sales price it received for its oil and natural gas products as compared to the twelve month period beginning October 1, 2011 and ending September 30, 2012 (“2012”).

CAMI, through its wholly-owned subsidiary, CAPI (hereinafter CAMI and CAPI are sometimes collectively referred to as “CAM”), owns a fee title interest, leasehold interest and Federal Placer and Lode mining claims containing non-metallic and other minerals in Texas, New Mexico and Utah. CAM is presently engaged in the exploration for such minerals. CAM intends to mine the minerals through the use of contract miners and arrangements with its joint venture partner.

During 2013, the Company filed several provisional patents relating to the use of its CA Series engineered products in various novel systems and processes. Specifically, the provisional patents relate to a system and method for applying a zeolitic material useful for converting a contaminated waste material that is environmentally unacceptable, to a relatively harmless substance which is environmentally acceptable, and, more particularly, applying a material with an effective amount of zeolite for treating waste water. Additional processes include utilizing similar system designs in acid mine drainage, animal feed, agriculture, aquaculture, and other industrial purposes.

	4

FEI/DTE Stock Purchase Agreement

On March 25, 2013, the Company finalized a Stock Purchase Agreement (“SPA”) with Far East Investments, LLC, a California limited liability company (“FEI”) and DTE Investment Ltd., a British Virgin Island company (“DTE”) (hereinafter FEI and DTE are sometimes collectively referred to as the “Investors” and individually as an “Investor”). The Investors paid the Company $1.5 million for 15 million shares of the Company’s common stock, par value $.01 (“Common Stock”) and warrants for the purchase of up to a total of 18 million shares of Common Stock to the Investors (“FEI/DTE Warrants”). The FEI/DTE Warrants have a term of five (5) years (“Term”) and may be exercised at a price of $0.20 per share (“Exercise Price”). In the third through fifth years of the Term, the Exercise Price may be satisfied by exchanging Common Stock at the current market price. The FEI/DTE Warrants may be exercised in whole or in part at any time during the Term. See Note 9.

Under the SPA for so long as the Investors retain 51% or more of the Common Stock issued under the SPA (7,650,000 shares), the Investors are entitled to request that the Company nominate for election, by the shareholders of the Company at the Company’s annual meeting of shareholders, two persons suitable to serve as directors of the Company.

A provision of the Agreement requires that the Company shall not make any public announcement or statement concerning the Agreement other than that which the Company is required to disclose on Form 8-K and other required filings with the Securities and Exchange Commission. See Exhibit 10.27. The Company, consistent with its obligations under the securities laws, is required to seek confidential treatment of the information set forth in the Annex and Exhibits to the SPA.

OIL AND NATURAL GAS

Beginning at page 110 of this report, a glossary of oil and natural gas terms used throughout this report is included. See Item 8 of Part II for additional information relating to the oil and natural gas activities of the Company.

Recent Significant Activity

Texas Railroad Commission Enforcement Action

In September 2013, WRC received an enforcement action from the Texas Railroad Commission (“RRC”). Due to the enforcement action, the renewal of WRC’s operator's permit was suspended until such action is resolved. Certain of WRC’s operated wells continue to pump and oil is stored oil in production tanks. Certain of WRC’s operated wells are not producing as the respective production tanks have reached their capacity limitations. WRC is not permitted to sell oil until its operator’s permit is renewed. As such, the Company's consolidated revenues for the first quarter of 2014 will be significantly lower than the first quarter of 2013. Depending on the timing of the resolution of the renewal of such permit, the Company's consolidated revenues for the second quarter of 2014 may also be higher or lower than the second quarter of 2013. Management of the company anticipates the renewal of the operator’s permit to be completed during the second quarter of 2014; however there can be no assurances as to when the renewal of WRC’s operator’s permit will be approved by the RRC and when the sales of oil from WRC’s operated properties will resume.

Asset Purchase and Sale Agreement

On October 6, 2013, the Company entered into an Asset Purchase and Sale Agreement (“APA”) pursuant to which the Company agreed to sell its interest in certain oil and natural gas leasehold deep rights for certain properties located in Burleson County, Texas (“Properties”), for cash, subject to adjustment as to any title defect that is not cured within the timeframe permitted by such agreement. On November 5, 2013, the closing date was delayed from November 6, 2013, to December 6, 2013, in accordance with the APA to allow the Company to address title issues raised by the buyer on November 1, 2013. A First Amendment to the APA was entered into on December 5, 2013, extending the “Delayed Closing Date” until December 17, 2013. On December 17, 2013, the parties closed on the sale of 280 net acres attributable to the Company’s interest in the Properties covered by this portion of the transaction. The Company received $448,038 at the closing and will recognize gain in the amount of proceeds when received. The oil and natural gas leasehold deep rights that were sold were undeveloped, and as such not income-producing to the Company. On December 16, 2013, a Second Amendment to the APA was entered into by the Company and the Buyer to extend the Delayed Closing Date to January 16, 2014, as to certain Properties to allow the parties to continue to address the Buyer’s concerns about certain issues with the remaining Properties that did not close on December 17, 2013. On January 13, 2014, a Third Amendment to the APA was entered into by the Company and the Buyer to extend the Delayed Closing Date to February 17, 2014.

	5

Property Acquisition and Disposition

During 2013, the Company did not acquire any oil and gas properties or drilling prospects. During 2012, the Company acquired certain working interests in its operated properties in Texas. During 2012, the Company sold certain oil and natural gas leasehold deep rights in Pennsylvania for cash of $898,335. The oil and natural gas leasehold deep rights that were sold were undeveloped, and as such not income-producing to the Company. Within the oil and gas sector, the Company faces competition from entities possessing substantially larger financial resources and staffs. The demand for domestically produced oil and natural gas should remain at the current levels in the foreseeable future especially in light of worldwide demand, the turmoil in the Middle East, decreased production from Central America and political instability in South America. Domestic and increasing world demands, especially in the Pacific Basin, for crude oil and natural gas will continue to increase.

The domestic oil industry is subject to the fluctuations inherent in the global energy industry. Natural gas and crude oil prices have fluctuated on the spot market and each is a commodity traded on the mercantile exchange. However, most of the Company’s products (natural gas and crude oil) are sold under contracts that provide the Company with competitive pricing within its operating areas. While the demand for domestic natural gas remains favorable, the ongoing development of shale gas resources plays has significantly increased the available domestic natural gas supplies. In response, the price received for natural gas has declined within the existing domestic markets. Alternative markets and uses for natural gas are being developed and such should have a favorable impact on the demand for and the stabilization of natural gas prices with the United States.

The Company continues to focus on: (i) identifying niche acquisition and developmental opportunities within the oil and gas sector that can be economically exploited, and (ii) identifying third parties who will, either individually or in conjunction with the Company, develop certain of the Company’s leasehold interests.

Marketing and Production of Oil and Gas, Delivery Commitment

The Company does not refine or engage in retail sales of any petroleum products. All of its production is sold, at the wellhead, to a variety of customers, which include pipelines, oil and natural gas gathering firms and other purchasers, pursuant to written agreements. Sales of oil and natural gas are customarily made at prevailing market prices or tied to a benchmark price under long-term contracts. Typically, oil purchase agreements are of short duration and provide for market sensitive pricing. Natural gas contracts are of a longer duration. The Company is a party to two long-term natural gas sales contracts which contain provisions concerning annual price adjustments and two contracts that renew annually. The Company is not obligated to provide a fixed and determinable quantity of oil and/or natural gas under existing contracts or agreements.

The availability of a market for oil and natural gas produced from the properties of the Company and prices received are dependent upon numerous factors, substantially all of which are beyond the control of the Company. Such factors include the level of domestic production, the availability of imported oil and gas, actions taken by foreign producing nations, the availability of distribution and transportation facilities and capacity thereon, the availability and price of fuels competitive with oil and gas, world and domestic demand for oil and gas and refined products, governmental regulations, environmental restrictions, drilling moratoriums and taxation. Such factors make it impracticable to predict with any degree of certainty future demand for or prices of the oil or gas produced by the Company.

Production of oil and gas is generally not considered to be of a seasonal nature, although severe weather conditions can temporarily curtail or preclude producing activities. Demand for natural gas is fairly constant over the entire year as a result of the increased demand for natural gas to fuel electric power generation and other commercial uses. Gas production from certain wells operated by the Company in West Virginia has been curtailed occasionally by the transporting pipeline. The Company has never experienced any other difficulties in selling any of its oil or gas.

	6

Customers

The following table identifies the Company’s customers who purchased in excess of five percent (5%) of the Company’s oil and natural gas during 2013:

Name and Location of Purchaser		Percentage
GulfMark Energy, Inc.	Houston, Texas	53	%
ETC Texas Pipeline, Ltd.⁽¹⁾	San Antonio, Texas	24	%
Sheridan Production Company LLC	Houston, Texas	13	%
Volunteer Energy Services, Inc.	Pickerington, Ohio	7	%

(1)

The Company’s production of natural gas from its operated wells in the Giddings Field, Texas, is sold to ETC Texas Pipeline, Ltd. pursuant to a long standing contract expiring January 31, 2015, with an annual renewal provision which covers a number of the Company’s Texas leases. Subject to various conditions, ETC has agreed to buy all of the Company’s natural gas produced from the Giddings Field. The Company receives eighty percent (80%) of the weighted average monthly sales price for liquid products extracted from natural gas delivered to ETC and eighty percent (80%) of the resale prices for dry residual gas. Prices received by the Company are subject to deductions for taxes, compression and similar charges.

The Company does not believe that the loss of any one of these customers would have a material adverse effect upon the Company’s revenues since there are numerous purchasers of oil and natural gas in the areas in which the Company operates.

Production

Substantially all the Company’s production of oil and natural gas in Texas is attributable to the Giddings Field located in the Austin Chalk Trend (see Item 2 – Properties) which represented 79% and 72% of total oil and gas production on an MCFE basis for 2013 and 2012, respectively. All the Company’s production of natural gas in West Virginia is attributable to the Oriskany formation of the Appalachian Basin’s Upper Devonian Section which represented 21% and 28% of total oil and natural gas production on an MCFE basis for 2013 and 2012, respectively.

The following table summarizes the Company’s net oil and natural gas production for the fiscal periods indicated, shown in barrels (“Bbls”) and, thousand cubic feet (“Mcf”):

	2013	2012
Texas:
Oil (Bbls)	2,575	2,112
Gas (Mcf)	23,606	21,281
Average Bbls/day	7	6
Average Mcf/day	65	58
Pennsylvania:
Gas (Mcf)	252	192
Average Mcf/day	1	1
West Virginia:
Gas (Mcf)	10,322	12,931
Average Mcf/day	28	36
TOTALS:
Oil (Bbls)	2,575	2,112
Gas (Mcf)	34,180	34,404
Average Bbls/day	7	6
Average Mcf/day	94	96

	7

The following table summarizes the average sales price per barrel of oil, the average sales price per Mcf of natural gas and average sales price and production costs per Mcfe for the fiscal periods indicated. In determining the prices received by the Company, the revenues are attributed to the Company’s net revenue interests. Production costs incurred by the Company include expenses of operation attributable to the Company’s working interests.

	2013		2012
Texas
Average Sales Price Per Bbl	$	95.58	$	95.67
Average Sales Price Per Mcf	$	5.08	$	6.08
Pennsylvania
Average Sales Price Per Mcf	$	3.58	$	3.17
West Virginia
Average Sales Price Per Mcf	$	3.60	$	3.26
Combined Properties
Average Sales Price Per Bbl	$	95.58	$	95.67
Average Sales Price Per Mcf	$	4.63	$	4.98
Average Sales Price Per Mcfe	$	8.14	$	7.93
Average Production Costs per Mcfe	$	4.79	$	3.87

Wells and Acreage

The Company owns no Undeveloped Acreage at September 30, 2013 and 2012. Certain of the Developed Acreage owned by the Company are limited as to depths and/or formations. The following table sets forth certain information that is the same as of September 30, 2013 and 2012:

Well Count	Gross Wells	Net Wells
Texas	26	12.26
West Virginia	2	0.46
Total	28	12.72

Developed Acreage	Gross Acres	Net Acres
Texas	5,069	2,365
Pennsylvania	382	382
West Virginia	1,777	432
Total	7,228	3,179

	8

Drilling Activity

The Company did not participate in the drilling of any exploratory or development wells in 2013 or 2012. Such information should not be considered indicative of future performance or prospects of the Company. There is no necessary correlation between the number of producing wells, whether developmental or exploratory, completed during any period and the aggregate reserves or future net income generated.

Proved Reserves

The Company causes to be prepared an annual estimate of its proved oil and gas reserves. These estimates are prepared by an independent consultant in a manner consistent with generally accepted procedures for such estimates. Proved developed reserves are estimated utilizing available data including but not limited to, the wells’ geologic information, operating performance and the prevailing market conditions.

Proved reserve estimates for the Company’s properties as of September 30, 2013 and 2012 were taken from reserve reports dated December 31, 2013 and January 7, 2013, respectively, prepared by Hall Energy, Inc. of Magnetic Springs, Ohio, with the figures utilizing constant product prices in accordance with reporting requirements. Hall Energy, Inc. is an independent petroleum engineering concern with an emphasis in the Appalachian and Ohio Basins. All of the reserves are located on-shore within the United States.

The following table sets forth the net proved developed reserves of the Company as of September 30, 2013 and 2012:

	September 30
	2013	2012
Net Proved Developed Reserves:
Oil (Bbls)
Texas	21,958	26,736
Gas (Mcf)
Texas	157,955	151,605
Alabama	15,397	105,141
Pennsylvania	1,172	599
West Virginia	122,465	177,036
Total	296,989	434,381
Mcfe
Texas	289,703	312,021
Alabama	15,397	105,141
Pennsylvania	1,172	599
West Virginia	122,465	177,036
Total	428,737	594,797

Substantially all the Company’s proved reserves in Texas are attributable to the Giddings Field located in the Austin Chalk Trend (see Item 2 – Properties) which represented 68% and 52% of total net proved developed reserves on an MCFE basis at September 30, 2013 and 2012, respectively. All the Company’s proved reserves in West Virginia are attributable to the Oriskany formation of the Appalachian Basin’s Upper Devonian Section which represented 28% and 30% of total net proved developed reserves on an MCFE basis at September 30, 2013 and 2012, respectively. All the Company’s proved reserves in Alabama are attributable to the Deerlick Coalbed Methane Field located in Tuscaloosa County, Alabama, which represented 4% and 18% of total net proved developed reserves on an MCFE basis at September 30, 2013 and 2012, respectively.

The Company has identified fifteen (15) potential development and redevelopment opportunities associated with its existing leasehold acreage in the Giddings Field located in the Austin Chalk Trend. The Company believes that the potential for the development of such locations will occur within the next few years as a result of renewed interest in the area of its properties. The prevailing oil price and the development of properties in “resource plays” in the area of the Company’s acreage are major factors contributing to such interest. At September 30, 2013, the Company has assigned probable and possible reserves to the fifteen (15) potential developmental locations.

	9

Estimated Future Net Revenues and Present Worth

Estimated future net revenues of the Company’s proved net oil and gas reserves at the date indicated and the present worth thereof employing a ten percent (10%) discount factor is set forth in the following tabulation:

		September 30
		2013	2012
Future Net Revenues:
Proved Developed Oil and Gas Reserves	$	1,919,319	$	2,669,449
Proved Undeveloped Oil and Gas Reserves		-		-
Total Proved Oil and Gas Reserves	$	1,919,319	$	2,669,449
Present Worth:
Proved Developed Oil and Gas Reserves	$	1,361,002	$	1,792,312
Proved Undeveloped Oil and Gas Reserves		-		-
Total Proved Oil and Gas Reserves	$	1,361,002	$	1,792,312

The present value of estimated future net revenues set forth above is computed using the estimated future net revenues and a discount factor of ten percent (10%) over the projected life of each property.

Petroleum engineering is not an exact science. Information relating to the Company’s oil and gas reserves is based upon engineering estimates. Estimates of economically recoverable oil and gas reserves and of the future net revenues therefrom are based upon a number of variable factors and assumptions, such as historical production from the subject properties compared with production from other producing properties, the assumed effects of regulation by governmental agencies and assumptions concerning future oil and gas prices and future operating costs, severance and excise taxes, development costs, work-over and remedial costs, all of which may in fact vary from actual results. All such estimates are to some degree speculative, and classifications of reserves are only attempts to define the degree of speculation involved. For these reasons, estimates of the economically recoverable reserves of oil and gas attributable to any particular group of properties, classifications of such reserves based on risk of recovery and estimates of the future net revenues expected therefrom, prepared by different engineers or by the same engineers at different times, may vary. The Company emphasizes that the actual production, revenues, severance and excise taxes, development expenditures and operating expenditures with respect to its reserves will likely vary from such estimates, and such variances may be material. Persons should not assume that the estimates of the Company's future reserves are a guaranteed figure.

The present values shown above should not be construed as the current market value of the estimated oil and gas reserves attributable to the Company’s properties. In accordance with applicable requirements of the Securities and Exchange Commission, the estimated discounted future net revenues from proved reserves are based, generally, on prices and costs as of the date of the estimate, whereas actual future prices and costs may be materially higher or lower. Actual future net revenues also will be affected by factors such as actual production, supply and demand for oil and gas, curtailments or increases in consumption by gas purchasers, changes in governmental regulations or taxation, the impact of inflation on operating costs, general and administrative costs and interest expense. Estimated future production is priced at the average price received for 2013 for the amounts at September 30, 2013 and the average price received for 2012 for amounts at September 30, 2012. The method of calculating the estimated product prices is in accordance with the reserve estimation and disclosure requirements of ASC Topic 932, Extractive Industries – Oil and Gas which the Company adopted on September 30, 2010. The timing of actual future net revenues from proved reserves, and thus their actual present value, will be affected by the timing of the incurrence of expenses in connection with development of oil and gas properties. In addition, the ten percent (10%) discount factor, which is required by the Commission to be used to calculate discounted future net revenues for reporting purposes, is not necessarily the most appropriate discount factor based on interest rates in effect from time to time and risks associated with the oil and gas industry. Discounted future net revenues, no matter what discount rate is used, are materially affected by assumptions as to the timing of future production and future expenses which may and often do prove to be inaccurate.

Reserves Reported To Other Agencies

No estimates of total, proved net oil and gas reserves have been filed with or included in reports to any Federal authority or agency, other than estimates filed with the Securities and Exchange Commission during 2013 and 2012.

	10

NON-METALLIC MINERALS

Beginning at page 113 of this report, a glossary of minerals and mining terms used throughout this report is included. See Item 8 of Part II for additional information relating to the minerals activities of the Company.

Recent Significant Activity

During September 2013, the company produced saleable minerals from its zeolite mineral deposit in Texas (“Texas Zeolite”). The Company shipped 105 tons of zeolite from its Texas property to a processing and fulfillment facility in Pennsylvania. A portion of such material required additional processing and such processing was completed in October 2013. Backlog orders approximated $2,000 as of September 30, 2013. Sales of the processed and unprocessed product to identified customers commenced in October 2013. On December 16, 2013, the Company entered into an agreement for the purchase of extraction and crushing equipment of its contract operator of the property for $300,000. On January 16, 2014, the Company borrowed $250,000 from an unrelated party to fund the major portion of the purchase price and closed on the purchase of such equipment. The Company believes the capacity of such equipment is appropriate for anticipated extraction and crushing activities for the next three years. Depending on the level of sales activity, the Company may need to acquire or lease additional equipment. The Company has engaged a contract operator of such equipment and anticipates the commencement of larger-scale extraction activities to commence. The Company has also contracted certain micro-processing capabilities to prepare certain samples and test material.

General

The mining and marketing of non-metallic industrial minerals is highly competitive; however, the Company believes that the locations and quality of its mineral deposits will benefit its future development and sales efforts. By definition, the Company is in the Development Stage in respect to its Texas Zeolite and is in the Exploration Stage in respect to its Sierra Kaolin mineral holdings in New Mexico (“Sierra Kaolin”) and its zeolite mineral holdings in Utah (“Utah Zeolite”). During 2012 and 2013, sales of non-metallic minerals did not account for 15 percent or more of the consolidated revenue of the Company. The business of this segment has not been, and it is not anticipated that it will be, seasonal.

In 2005, the Company contracted Denali Enterprises to review available technical data associated with the quantification of the mineral deposits in connection with the Company’s exploration efforts. Such review reaffirmed the existence of sufficient mineral deposits to continue with such efforts. The Company’s ability to explore and develop its mineral deposits is dependent on its success in bringing in strategic partners with experience in or a demand for specific minerals and raising capital through third parties. In June 2007, the Company and Tecumseh Professional Associates, Inc. (“TPA”) entered into a Restated Development and Operating Agreement in respect to the Sierra Kaolin. Under the Restated Development and Operating Agreement the Company and TPA continued the evaluation of the Sierra Kaolin (See “Kaolin” below). The Company has continued its independent evaluation of its zeolite properties. The Company continues to sell raw zeolite to third parties as animal feed supplement and for other uses, and market its zeolite based products such as its ReNuGen™, a product utilized in wastewater treatment applications. At September 30, 2013, the Company was and continues to be involved in discussions with one or more potential joint venture partners for the development and testing of additional zeolite based products and to provide capital for market introduction.

Mineral Extraction

The Company has not established large-scale production of any of its mineral deposits at September 30, 2013. See the “Recent Significant Activity” discussed above. The Texas Zeolite extraction is conducted by an independent contractor engaged by CAM. The contemplated Sierra Kaolin extraction activities are the responsibility of TPA pursuant to the Restated Development and Operating Agreement between TPA and the Company. No extraction activities have occurred as regards the Utah Zeolite. The Company does not conduct any direct extraction activities of its own. As such, the Company is subject to costs of independent contractors for the extraction, crushing or preparation of its minerals. Any independent contractor is required to comply with all Federal, state and local laws, regulations and ordinances for the conduct of operations, environmental protection and safety of operations.

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Mineralized Materials

Set forth below are the total acres, acres evaluated and estimated quantities of Mineralized Materials associated with the gross acres evaluated for the Company’s kaolin claims in Sierra County, New Mexico, zeolite lease and fee acreage in Presidio County, Texas, and zeolite claims in Beaver County, Utah. These Mineralized Materials were evaluated and estimated by a Competent Person.

State	Mineral	Total Gross Acres	Gross Acres Evaluated	Gross Mineralized Materials (millions of tons)	Total Net Acres	Net Mineralized Materials (millions of tons)
New Mexico	Kaolin ⁽¹⁾	2,720	264	38.0	952	13.3
Texas	Zeolite	5,200	438	54.8	5,200	54.8
Utah	Zeolite	220	-	-	220	-

(1)

Pursuant to the Restated Development and Operating Agreement with TPA, (i) TPA shall earn 65 % of the net cash flow from the Sierra Kaolin operations in the event TPA develops the property, including the construction and funding of an appropriate processing facility and (ii) TPA shall be entitled to 50% of the sale proceeds in the event of a divestiture of the Sierra Kaolin property prior to its development by TPA.

Zeolite

Texas - Through September 30, 2013, the Company mined approximately 1,400 tons of material for the preparation of samples and test products and material for various environmental testing and waste purification projects; 105 tons have been sold or distributed as the Company’s trademarked ReNuGen™, a zeolite based, wastewater treatment product; and 200 tons were sold for use in certain agricultural oriented products. The Company currently has approximately 115 tons available for product processing.

During fiscal 2006, the Company initiated a confirmation geologic field mapping project and commenced a resource definition program, as well as a core hole drilling and sampling program to delineate Mineralized Materials in sufficient quantities to support large scale mining operations. These efforts targeted 438 acres of the 5,200 acres held by the Company which are most likely to be subjected to initial development. During fiscal 2007, Krumrey Industrial Minerals, LLC, formerly known as KT Minerals, Inc. (“KIM”), completed the evaluation of the target area. KIM has identified 54.8 million tons of Mineralized Materials associated with the target area. At September 30, 2013, the Company is also exploring alternatives for the development and marketing of additional zeolite based products for introduction into the industrial and environmental markets. See “Recent Significant Activities” above.

Utah – As of September 30, 2013, the Company is not conducting any exploration activities on the Three Creek zeolite deposit.

Kaolin

The Company has 17 Federal Placer mining claims covering approximately 2,720 acres and 8 Lode claims covering approximately 160 acres covering a portion of its existing holdings. The Company has maintained all of its claims during fiscal 2013. Through September 30, 2013, the Company has not produced commercial quantities of its Sierra Kaolin. Sierra Kaolin was mined in previous years for testing by prospective customers.

Pursuant to the Restated Development and Operating Agreement with TPA, the pre-development evaluation program of the Company’s Sierra Kaolin claims was completed during fiscal 2010. This program focused on evaluating in detail approximately 173 acres (+/-7%) of the Company’s 2,720 acre mineral claim block which is most likely to be subjected to initial development. During fiscal 2008, KT Minerals, Inc. identified 38.0 million gross tons of Mineralized Materials based on a total of 53 verifiable drill holes representing 6,310 feet of subsurface material.

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In 1965, twenty core holes were drilled which produced 3,087 feet of core samples. In 1976, 17 core holes were drilled which produced 1,784 feet of core samples. During fiscal 2005, 16 core holes were drilled on a 32 acre area from which 1,442 feet of subsurface material was recovered. During fiscal year 2006, this subsurface material was broken down into over 600 samples which were subjected to detailed testing at three different laboratories. The testing phase of the project included roughly 20,000 tests which now comprise an extensive Sierra Kaolin data base. This data base was then utilized by the consulting firm of Pincock, Allen & Holt to develop detailed geologic models of the Sierra Kaolin deposit test area. Based on this work, it was determined that this 32 acre core tested area contained approximately 1.4 million tons of gross Mineralized Materials.

KIM conducted a re-evaluation of the potential Kaolin Mineralized Materials associated with the project. The KIM re-evaluation considered the geologic and compositional data available from prior studies and incorporated the results of the mineral processing study completed by Ginn Mineral Technology, Inc. (“GMT”). Based on the GMT study, a greater percentage of the project’s in situ minerals may be processed into marketable material as compared to prior indications. In addition, KIM evaluated and expanded the study area outside of the 32 acres encompassed by the TPA coring program to include acreage penetrated by an additional 53 historical core holes from which verifiable data could be obtained. As a result, KIM evaluated approximately 264 acres of the project and identified approximately 38.0 million tons of gross Mineralized Materials.

TPA has proceeded with the next phases of the project which included: (i) further work to quantify Mineralized Materials; (ii) product identification and development; (iii) preparation of detail process flow sheets; and (iv) the establishment of equipment specifications, as well as marketing and capital requirements. In December 2009, the Sierra Kaolin Open Pit Clay Mine project cleared the regulatory review and the project’s definitive USDA Forest Service Plan of Operations was approved. This will facilitate the project moving to the next phase. These activities will continue in fiscal 2014.

Marketing of Minerals and Marketing Agreements

In December 2004, the Company entered into a Memorandum of Understanding for development of Sierra Kaolin Deposit (“MOU”) with TPA for the management, development, exploration and marketing of the Company’s Sierra Kaolin claims, located in Sierra County, New Mexico (see Exhibit 10.9).

Under the Company’s March 11, 2005 and June 7, 2007 agreements with TPA (see Exhibits 10.12 and 10.17, respectively), TPA has assumed the duties to mine, test, exploit, and market the Company’s Sierra Kaolin deposit.

On July 3, 2012, CAMI entered into an operating agreement for ZeoSure LLC (“ZLLC”) as one of ZLLC’s two managing members. ZLLC was formed for the purpose of developing human consumption products including but not limited to detoxification and digestive supplements and human consumable products utilizing CAPI’S Clinoptilolite zeolite mineral focusing on markets throughout the world with a primary emphasis on markets in the United States and Asia. CAMI and SafeHatch LLC, an entity controlled by an individual previously affiliated with the Musser Group, are the managing members and each owns 47.5% of ZLLC. The remaining 5% of ZLLC is owned by the Musser Group. The members of ZLLC intend to seek initial capital of $1 million from third parties and enter into product marketing and distribution agreements with participants active within the dietary supplements market. The operating agreement has not been ratified by the Audit Committee of the Board of Directors of the Company. ZLLC is seeking initial capital and attempting to identify viable product marketing and distribution partners. The Company has contracted certain micro-processing capabilities to prepare certain samples and clinical trial test material for ZLLC.

On March 25, 2013, in connection with the SPA with FEI and DTE, the Company entered into an Exclusive Sales Agency and Marketing Agreement with FEI (the “FEI Marketing Agreement”). The FEI Marketing Agreement grants to FEI the right to act as the Company’s exclusive marketing and sales agent for natural resources products produced, mined and/or sold by the Company, excluding certain human consumption products, in Asia excluding the nation of India. The Company is required to pay a monthly fee of $10,000 to an affiliate of FEI for 18 months. Through September 30, 2013, no sales have occurred relating to the FEI Marketing Agreement.

During April 2013, the Company hired a Vice President of Sales. Management of the Company directs the activities pertaining to the Company’s zeolite minerals and participates in the decisions regarding the agreement with TPA in respect to the marketing of the Sierra Kaolin.

In October 2013, the Company entered into a distribution agreement with an independent party in respect to such party’s distribution of the Company’s zeolite material for industrial absorption applications in the states of Arizona, California, Oregon and Washington.

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Government Regulations

Oil and Natural Gas

There are statutory and/or regulatory provisions regulating the Company’s oil and natural gas operations. These statutes allow administrative agencies to promulgate regulations in connection with the development, production and sale of oil and natural gas, and to establish allowable rates of production.

The Company’s activities are subject to laws and regulations relating to environmental quality and pollution control. Although the cost of compliance with such legislation and regulations has not been material to date, such laws and regulations could substantially increase the cost of carrying on these activities and could prevent or delay the commencement or continuance of a given operation. The Company believes that existing legislation and regulations have had no material adverse effect on its present method of operations. In the future, Federal, state and local environmental controls may require the Company to make significant expenditures, but neither the probability nor the magnitude of the expenditures, if any, can be predicted.

The discharge of oil, natural gas or the by-products of drilling, reworking and producing oil and natural gas into the air, soil or water may give rise to potential liabilities for the restoration of the environment and to third parties. A variety of Federal and state laws and regulations govern the environmental aspects of the production, transportation and processing of hydrocarbons and may, in addition to other laws and regulations, impose liability in the event of a discharge or seepage (whether or not accidental). Compliance with such laws and regulations could increase the cost of the exploration, production and development of oil and natural gas reserves. The Company does not currently anticipate that compliance will have a material adverse effect on the ability of the Company to continue in the exploration, development or production of its existing reserves and the development and/or acquisition of new reserves.

The Company does not believe that its environmental risks are materially different from those of comparable companies in the oil and gas industry. The Company believes that it is in substantial compliance with all existing rules and regulations. No assurance can be given, however, that environmental laws will not, in the future, result in more onerous regulations causing a marked increase in the cost of production, development and exploration or otherwise adversely affect the Company’s operations or financial ability to maintain its existing reserves. Although the Company maintains insurance coverage for certain liabilities, to include insurance to cover specific environmental risks, such as seepage or discharge, other environmental risks may not be fully insurable.

Mineral Interests

The Company’s activities are subject to Federal and state laws and regulations relating to environmental quality and pollution control, safety rules as prescribed by Occupational Safety and Health Administration, and the provisions of the 1872 Mining Law and the 1976 Federal Land Policy Management Act. At present, the Company does not intend to engage in mining activities on its own. The Company intends to retain, and has to date retained, the services of outside contractors to carry out such activities. The Company believes that such practices may result in substantial savings in the future. The Company’s Sierra Kaolin and Utah Zeolite are on Federal lands. As such, the Company must also comply with the rules and regulations imposed for the development of Federal mining claims. The Texas Zeolite is on fee and leased acreage and is subject to Federal and state laws and regulations governing open pit extraction.

Transportation

Oil and Gas

All of the Company’s oil is shipped via the tank trucks of the respective purchasers. Currently the majority of the Company’s natural gas is sold to interstate carriers. The Company moves its gas to the interstate carriers over a gathering system owned by the Company or joint venture partners in the Company's wells. The Company has experienced no difficulty in moving or selling its gas. The Company is not a regulated interstate/intrastate carrier of natural gas and as such it is not a regulated pipeline under the National Gas Policy Act of 1983, the National Gas Act of 1938 or as a common carrier by applicable state agencies.

Mineral Interests

All of the Company’s mineral deposits are serviced by all-weather paved or unpaved roads. The Texas Zeolite property is adjacent to a railroad line that can be utilized to transport minerals to market. The Utah Zeolite and Sierra Kaolin deposits also have access to rail lines but will require over-land transport prior to rail transport.

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Partnerships

DRI sponsored Deerlick Royalty Partners I (“DRP”) which was formed in April 1993. As the managing general partner, DRI is subject to full liability for the obligations of DRP although it is entitled to indemnification to the extent of the assets of DRP. As “partnership programs” constitute a “security” under the Securities Act of 1933, DRI is also subject to potential liability for failure to comply with applicable Federal and state securities laws and regulations. DRP owns overriding royalty interests covering 2,043 gross acres in the Deerlick Creek Coalbed Methane field located in Tuscaloosa County, Alabama.

Acquisitions/Mergers

Oil and Gas Segment

During the past two fiscal years, the Company has not participated in any mergers. During 2013, the Company did not incur any property acquisition, exploration or development costs. During 2012, the Company (1) incurred $47,078 of acquisition costs of proved developed producing properties and (2) did not incur any exploration or development costs.

Minerals Segment

During the past two fiscal years, the Company has not participated in any mergers. During 2013 and 2012, the Company did not incur any property acquisition, exploration or development costs.

Patent and License Agreement

Patent

As part of the acquisition of Clean Age Minerals, Inc., the Company also acquired U.S. Patent No. 5,387,738. This patent, owned by Clean Age Minerals, Inc. (previously owned by Matrix-Loc, Inc., which was acquired by Clean Age Minerals, Inc., as a result of Matrix-Loc’s merger with Clean Age Minerals, Inc., as of March 18, 2002), deals with a reagent and process for the remediation of water and contaminated soils. Such patent was based upon an engineered product which utilizes all naturally occurring non-hazardous minerals for the remediation of sites contaminated with hazardous and/or toxic materials. Such patent expired on February 7, 2012. Typically, the remediation of these sites is necessary in order to meet quality control regulation for air, land and water enforced by the Environmental Protection Agency and various other state and Federal environmental regulatory agencies. Such engineered products are marketed by CAMI as CA Series Engineered products. Each of these engineered environmental products is designed for specific project site requirements based on the nature of the on-site contaminant, the size of the project and specific treatment requirements.

The CA Series engineered products have been proven effective, through the use of a catalytically enhanced chemical exchange process, in permanently changing many hazardous metals to a non-hazardous state and, through molecular sieve and/or absorption processes, in removing many hazardous hydrocarbon and nitrate contaminants in connection with site remediation projects.

The processing of contaminated materials using the CA Series technology is designed as an on-site operation. Internal studies have shown that because the CA Series engineered products are designed to be used at the remediation project site, substantial cost savings can be generated as compared to other remediation methods requiring extraction, removal and incineration. The on-site use of CA Series engineered products can provide a complete and permanent environmental cleanup of the hazardous materials in that the treated materials are converted into non-hazardous permanently non-leachable substances that can remain in place. Through laboratory and field tests, the CA Series Engineered products have been proven to be effective in the remediation of contamination caused by hydrocarbons and petroleum products, chemicals and toxic metallic compounds in rendering the toxic and hazardous materials to a permanently non-toxic and non-hazardous stage.

During 2013, the Company filed several provisional patents relating to the use of their CA Series engineered products in various novel systems and processes. Specifically, the provisional patents relate to a system and method for applying a zeolitic material useful for converting a contaminated waste material that is environmentally unacceptable, to a relatively harmless substance which is environmentally acceptable, and, more particularly, applying a material with an effective amount of zeolite for treating waste water. Additional processes include utilizing similar system designs in acid mine drainage, animal feed, agriculture, aquaculture, and other industrial purposes.

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License Agreement

In February 2010, the Company entered into a License Agreement concerning two US method patents for the treatment of sanitary wastewaters. Such patents utilize the Company’s zeolite. The license applies to the US and covers the use of the patented technology in water, wastewater and waste treatment in animal feed operations, agriculture, and aquaculture. In addition, the license applies to the treatment of sanitary wastewater on Federal facilities, military bases and lands administered by the US Bureau of Indian Affairs. The initial period of the agreement was for three years; thereafter, the agreement shall automatically renew for additional consecutive terms of five years unless the Company gives the other parties not less than ninety (90) days written notice prior to the end of the existing term of its election not to renew the agreement for an additional term. The Company is required to pay a royalty to the licensor based on the license fees received from sub-licensees of the Company that employ the licensed process or processes. The Company has made the minimum annual payment of $12,000 to maintain the License Agreement.

Trademarks

The Company has a trademark for the Company’s “ReNuGen™”, a product used to enhance the efficacy of conventional waste water treatment plants. During 2013, the Company applied for a trademark for its two additional engineered, zeolite-based products, Cite-Clean^TM and ZoilTech^TM. Cite-Clean^TM is an all-natural mineral based non-hazardous absorbent. The Cite-Clean^TM product has been tested and proven effective in various industrial, commercial and do-it-yourself residential settings for the absorption and retention of fluids. ZoilTech^TM is a natural mineral based environmentally friendly soil treatment. The ZoilTech^TM product has been tested and shown to be effective in enhancing moisture retention, balancing nutrient levels and controlling odors in commercial and residential applications.

Employees and Contract Services

At September 30, 2013, the Company has four employees and engages the services of its Chief Accounting Officer pursuant to his employment agreement, as amended.

On February 25, 2011, the Company entered into a Consulting Services Agreement with the Musser Group, LLC (“Musser Group”) to perform consulting services for the Company and such agreement has been extended through February 2014. The Company engaged the Musser Group, an independent contractor, to provide advisory and consulting services to the Company. The Musser Group is engaged to provide (i) managed services; (ii) strategic business planning and implementation; and (iii) assistance in directing and executing the implementation of any strategies approved by the Board of Directors of the Company. The Musser Group’s primary focus is the analysis and validation of market opportunities for the commercialization of products within the Company’s mineral segment.

In March 2013, the Company engaged an investor relations firm to assist management in such activities for one year. The Company issued 600,000 shares (valued at $0.11 per share) of Common Stock to the IR Firm and such contract requires monthly payments of cash of $5,000 during the term of the agreement.

On April 1, 2013, pursuant to the SPA, the Company entered into an agreement with a law firm for an attorney to perform legal services for and representation of the Company for a flat fee of $5,000 per month. Such attorney represented FEI and DTE in connection with the SPA.

The Company employs the services of consulting scientists, geologists and engineers, as well as those of nonaffiliated operating companies that conduct oil and gas field operations and mineral extraction/processing. The Company operates oil and natural gas wells in Pennsylvania, Texas and West Virginia from its Pennsylvania office utilizing contract pumpers to perform the field operations. The Company’s non-operated wells are monitored from the Company’s Pennsylvania office.

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The Company’s mineral lease, fee interest and mining claims are operated by contract mining entities and are monitored from its Pennsylvania office and by TPA under its agreement pertaining to covering the Company’s Sierra Kaolin deposit. The Company considers its relations with its consultants to be satisfactory.

Item 1A. Risk Factors.

Not required as the registrant is a smaller reporting company.

Item 1B. Unresolved Staff Comments.

Not required as the registrant is a smaller reporting company.

Item 2. Properties.

OIL AND NATURAL GAS INTERESTS

Texas

Substantially all of the Texas properties are located in the Austin Chalk Trend in Burleson, Brazos and Lee Counties, Texas. The Austin Chalk Trend consists of the Austin Chalk, Buda, Georgetown and Edwards formations, extends for approximately 300 miles in length and 50 miles across, and is encountered at depths of 5,500 to 18,000 feet. These reservoirs are generally of low permeability. Historically, these formations were considered to be economically marginal except in areas where the reservoir rocks are highly fractured. In later years, stimulation by mechanical fracturing of the rock resulted in increasing hydrocarbon recoveries and extensive development of the Trend. Ongoing technical developments using horizontal drilling techniques allow the well bore to intersect, if present, series of vertical fracture systems instead of a single one, thus resulting in higher rates of production and recoverable reserves, at the cost of a more expensive drilling effort. Whether an individual well will be economic, even if horizontally drilled, depends largely upon intersecting fractured portions of the formation, which cannot be predicted. Certain locales appear to contain more fracturing than others. It is not unusual for an individual well to produce as much as forty percent (40%) of the primary recoverable reserves during the first two years of production and the remainder over a period of ten to fifteen years. The Company is presently evaluating joint venturing with third parties to develop its Texas Properties. The Company operates twenty-five (25) wells and owns a working interest in a well that it does not operate in Texas.

West Virginia and Pennsylvania

The Company’s hydrocarbon production in West Virginia is in the producing zone of the Oriskany formation of the Appalachian Basin’s Upper Devonian Section. The Company has working interests in two wells in West Virginia for which it acts as operator. The Company operates two wells in which it owns no working interest and owns overriding royalty interests in two other wells which it does not operate that produce from the Balltown Formation in Pennsylvania.

Alabama

DRIOP acts as the managing general partner of DRP. DRP owns an overriding royalty interest in 70 wells located in the Deerlick Creek Coalbed Methane Field in Tuscaloosa County, Alabama, in the Black Warrior Basin.

Operating Hazards and Uninsured Risks

The Company’s oil and gas operations are subject to all of the risks normally incident to the exploration for and production of oil and gas, including mechanical failures, blow-outs, cratering, pollution and fires, each of which could result in damage to or destruction of oil and gas wells or production facilities or damage to persons and property. While the Company maintains $3,000,000 of all risks liability policies in amounts that it believes are adequate, the insurance may not cover all potential operational risks. The occurrence of a significant event not fully insured against could have a material adverse effect on the Company’s financial position. In the coming year, the Company plans to seek participation in certain types of exploratory or developmental drilling prospects. In these instances, the Company has historically expanded its insurance coverage to cover the specific risk associated with those types of operations. The Company will continue to conduct its normal day-to-day activities as operator of its wells.

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Title to Oil and Gas Properties

The Company’s interests in producing and non-producing acreage are in the form of direct or indirect interests in leases. Each of its properties is subject to customary royalty interests in amounts prevailing in the area in which the oil and gas lease was taken, overriding royalty interests, liens incident to operating agreements, liens for current taxes and other burdens and mineral encumbrances and restrictions. The Company believes that none of these burdens materially interferes with the use of such properties, in the operation of the Company’s business or the profitability of the Company’s investment therein.

As is customary in the oil and gas industry, only a preliminary investigation of title may be made at the time of acquisition of undeveloped properties. Detailed investigations are generally made, including, in most cases, receiving a title opinion of local counsel, prior to the commencement of drilling operations. A thorough examination of title was performed with respect to substantially all of the Company’s producing properties. Also, prior to the acquisition of properties, the Company has received an opinion of title, satisfactory to counsel to the Company, on a majority (in value) of the assets acquired. The Company believes that it has defensible title to substantially all of its properties.

MINERAL INTERESTS

Minerals Holdings

CAPI owns fee title interest, leasehold interests and Federal mining claims containing non-metallic minerals in the States of Texas, New Mexico and Utah. Title to and rights in the properties are held by CAPI, a wholly-owned subsidiary of CAMI.

Texas

Marfa Zeolite

CAPI is the lessee under a 5,200 acre lease containing high grade zeolite, located 32 miles south of Marfa in Presidio County, Texas. The lease terms call for royalty payments of $3.00 per ton of zeolite removed from the property with a minimum royalty of $30,000 per year which is due annually through November 2014. The lease can be extended for eight successive periods of ten years each. CAPI has the option to terminate the annual royalty payments by paying a lump sum of $400,000. CAPI owns, in fee, approximately 188 acres of land encompassed by and contained within the bounds of the 5,200 acre zeolite leasehold. During each of 2013 and 2012, the Company paid the minimum royalty of $30,000.

Location

The Company's zeolite deposit is located 32 miles south of Marfa, Texas, on State Highway 169, then 2 miles west on an all-weather dirt road. A railroad is immediately adjacent to the Company's leasehold and fee mineral interests. The Company's leasehold and fee mineral holdings are on private property. For a map of the location of the Company’s zeolite deposit, see Exhibit 99.1.

Geologic Setting

The zeolite bearing formation is an altered tuffaceous material that is exposed in several road cuts in the area. The zeolite present is the mineral Clinoptilolite.

New Mexico

Sierra Kaolin

CAPI owns 17 placer mining claims on 2,720 acres and 8 Lode claims covering 160 acres, all located in Sierra County, New Mexico, encompassing its Sierra Kaolin deposit. The Federal mining claims are burdened by a royalty interest of 7% of net proceeds derived from mining operations. TPA paid $20,160 to the Bureau of Land Management (“BLM”) in 2013 and 2012 to maintain CAPI’s Federal mineral claims. Such payment by TPA was in accordance with the provisions of the Restated Development and Operating Agreement (See Exhibit 10.17) with the Company.

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Location

The Sierra Kaolin claims are located on a paved road (State Highway 59) near Winston, NM, some 40 miles west of Truth or Consequences, NM. The claims are located on Federal lands administered by the Bureau of Land Management. For a map of the location of the Company’s Kaolin claims, see Exhibit 99.1.

Geologic Setting

The Sierra Kaolin project lies near the eastern margin of the Datil-Mogollon volcanic field, a region dominated by Tertiary caldera-related volcanic rocks.

The Sierra Kaolin is considered to be a primary hydrothermal deposit that was formed in situ. The Sierra Kaolin is part of an advanced argillic alteration assemblage that includes kaolinite (AI₄(Si₄O₁₀)(OH)₈) and related mineral species, possibly including dickite and halloysite, alunite (KAI₃(OH)₈(SO₄)₂) and chalcedonic and/or opaline quartz (hydrous amorphous silica).

Utah

Beaver Zeolite

CAPI owns 11 placer mining claims (Three Creek) covering approximately 220 acres of zeolite located in Beaver County, Utah. The Company considers the zeolite in this deposit to be of a high grade. During 2013 and 2012, the Company paid $6,160 to the Bureau of Land Management to maintain its federal mining claims.

Location

The Beaver zeolite claims are located on a paved road (State Highway 153) 18 miles east of Beaver, Utah. The claims are on Federal Lands administered by the Bureau of Land Management. For a map of the location of the Company’s Utah zeolite claims, see Exhibit 99.1.

Geologic Setting

The deposit is geologically located in an altered tuffaceous formation associated with widespread volcanic activity of the area.

Mining

The Company has periodically extracted zeolite from its deposit in Texas through the use of contract miners. The mining of all of the Company’s mineral deposits is exclusively conducted through surface mining. The quantities of extracted volumes were commensurate with demands for the minerals and to comply with the Company's lease obligations. The Company, under its agreements with Tecumseh Professional Associates, Inc. (“TPA”) (see Exhibits 10.12 and 10.17) extracted sufficient quantities of Sierra Kaolin for qualitative and quantitative analysis of the mineral’s commercial properties. All of the extraction of the Company's current mineral holdings is expected to be done by surface mining. At each of the locations, the areas disturbed by extractive operations have been limited to initial ten acre permit sites in New Mexico and under 100 acres in Texas in accordance with applicable state regulations.

The Company's Texas zeolite deposit will be mined on a periodic basis to meet existing obligations and to support development of new and emerging markets. Initial production of the Company’s Sierra Kaolin has been conducted by TPA for testing. Commercial development and marketing will be conducted in accordance with the Sierra Kaolin Restated Development and Operating Agreement (See Exhibit 10.17). In December 2009, the Sierra Kaolin Open Pit Clay Mine project cleared the regulatory review. The project’s definitive USDA Forest Service Plan of Operations has been approved.

At the present time, as a result of its limited activities on its mineral properties, the Company believes that its share of the reclamation costs currently associated with its activities is approximately $10,000.

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Operating Hazards and Uninsured Risks

The Company’s minerals operations are subject to all of the risks normally incident to the exploration for and production of non-metallic industrial minerals, including mechanical failures, pollution and fires, each of which could result in damage to or destruction of production facilities or damage to persons and property. While the Company maintains $3,000,000 of all risks liability policies in amounts that it believes are adequate, the insurance may not cover all potential operational risks. The occurrence of a significant event not fully insured against could have a material adverse effect on the Company’s financial position. The Company has historically expanded its insurance coverage to cover the specific risk associated with its operations.

Item 3. Legal Proceedings.

During October 2009, a working interest owner commenced an action against a subsidiary of the Company (“WRC”) in the District Court of Burleson County, Texas, for an accounting of expenses and revenues for six wells. WRC, through its Texas counsel, had filed a general denial of the claim. In November 2009, WRC provided the plaintiff with a complete accounting for all wells in question. The plaintiff sought additional discovery and WRC provided additional information. During July 2012, WRC and certain owners of overriding royalty and working interests in oil and gas wells operated by WRC agreed to the general terms of a settlement agreement. Pursuant to the settlement agreement (effective September 1, 2012), WRC paid $120,000 in cash for (i) settlement of all amounts due from WRC to such certain owners and (ii) the acquisition of the working interest ownership position of the respective entities. The parties entered into mutual releases and the litigation was terminated with prejudice.

The Company is a party to certain pending legal proceedings in Burleson County, Texas, each seeking to terminate WRC’s leasehold interest for failure to further develop the respective leases, for an accounting and for failure to properly pay royalties. WRC has filed a denial of all claims. The royalties in question were held in suspense due to the death of the royalty owner and the failure of the heirs to give WRC timely notice of their inheritance. Additionally, under Texas law, since the leases were properly being held by production from commercial wells, WRC was not obligated to undertake additional drilling on the leases to develop other productive reservoirs. WRC, through its Texas litigation counsel, are seeking to amicably resolve these suits. Should these two suits be timely resolved, the leases affected by these suits will be part of the sale of the deep rights on February 17, 2014 (see Recent Significant Activity - Asset Purchase and Sale Agreement included in Item 1).

Management of the Company believes such proceedings to be ordinary routine litigation incidental to the business as discussed in Notes to the Consolidated Financial Statements included in Item 8.

Item 4. Mine Safety Disclosures.

None.

PART II

Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities.

Description of Securities

Pursuant to the Company’s Articles of Incorporation, the Company is authorized to issue 150 million shares of common stock, par value $0.01 per share, and 20 million shares of preferred stock, par value of $0.01 per share. During June 2013, DRC’s authorized shares of common stock were increased to 150 million shares from 100 million shares. Below is a description of the Company’s outstanding securities, including common stock, preferred stock, options, warrants and convertible debt.

Common Stock

Each holder of the Company’s common stock is entitled to one vote for each share held of record. Holders of common stock have no preemptive, subscription, conversion, or redemption rights. Upon liquidation, dissolution or winding-up, the holders of common stock are entitled to receive the Company’s net assets pro rata. Each holder of common stock is entitled to receive ratably any dividends declared by the board of directors out of funds legally available for the payment of dividends. The Company has not paid any dividends on its common stock and does not contemplate doing so in the foreseeable future. The Company anticipates that any earnings generated from operations will be used to finance its growth. As of September 30, 2013, there were 72,468,458 shares of common stock issued and outstanding.

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Preferred Stock

The Company is authorized to issue 20,000,000 shares of preferred stock, par value $0.01 per share, with no voting power. As of September 30, 2013, there were: no shares of Series A preferred stock issued and outstanding; 135,000 shares of Series B 8% Cumulative Convertible Preferred Stock (“Series B Preferred Stock”) issued and outstanding. The Series B Preferred Stock (stated value of $10.00 per share) was issued in the acquisition of Clean Age Minerals, Inc. in September 2000. The Series B Preferred Stock can be converted to common stock at 85% of the average closing price of the 5 days before the date of conversion with a minimum amount of $1.25 per share. Thus, at September 30, 2013, the 135,000 shares of Series B Preferred Stock were convertible into 1,080,000 shares of Common Stock.

Further, the shares of Series B Preferred Stock (i) earn dividends at the rate of 8% per annum computed on the basis of a 365 day year, and (ii) have priority in liquidation to the extent of the stated value of $10.00 per share plus any unpaid dividends over any other preferred stock, common stock or any other stock issued after September 19, 2000. At September 30, 2013, the liquidation preference totals $3,392,239 (stated value of $1,350,000 plus arrearages in cumulative dividends of $2,042,239).

Market Information

The Company's Common Stock trades on the Over the Counter Markets ("OTCQB"). The symbol for the Company's shares is DLOV. The following table shows the high and low closing bid prices as quoted on the OTCBB for the fiscal quarters indicated and the quotations reflect inter-dealer prices, without retail mark-up, mark-down or commission and may not represent actual transactions. The Company’s fiscal year ends September 30.

2013	High		Low
First Quarter	$	0.09	$	0.05
Second Quarter	$	0.11	$	0.05
Third Quarter	$	0.18	$	0.09
Fourth Quarter	$	0.16	$	0.08

2012	High		Low
First Quarter	$	0.24	$	0.09
Second Quarter	$	0.25	$	0.13
Third Quarter	$	0.20	$	0.11
Fourth Quarter	$	0.16	$	0.09

Holders

Common Equity

As of September 30, 2013, the current outstanding amount of shares of common stock was 72,468,458 with approximately 2,000 holders of record (inclusive of brokerage house "street accounts").

Preferred Equity

As of September 30, 2013, there were no shares of Series A Preferred Stock issued and outstanding and there were 16 holders of the 135,000 shares of Series B Preferred Stock issued and outstanding.

Dividends

Common Stock - The Company has never paid a dividend on its common stock. The Company has no plans to pay any dividends on its common stock in the near future. The Company intends to retain all earnings, if any, for the foreseeable future for use in its business operations.

Series A Preferred Stock - No shares of Series A Preferred Stock were issued during 2013 and 2012. No shares were outstanding at September 30, 2013, 2012 and 2011.

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Series B 8% Cumulative Convertible Preferred Stock - No shares of Series B Preferred Stock, par value of $0.01 per share, were issued during 2013 and 2012. During 2012, 10,000 shares of Series B Preferred Stock were converted into 80,000 shares of Common Stock as discussed in Note 7 of the Notes to Consolidated Financial Statements. During fiscal years 2013 and 2012, there were no cash dividend payments in respect to the Series B Preferred Stock.

The only dividends paid prior to fiscal 2012 on the Company's Series B Preferred Stock were in shares of Common Stock at the time of conversion of the respective shares of such Preferred Stock into Common Stock.

At September 30, 2011, dividends payable on shares of Series B Preferred Stock totaled $1,914,558. At September 30, 2010, dividends payable totaled $1,857,895 - Series A of $59,338 and Series B of $1,798,557. As of October 1, 2011, the beginning of 2012, the Company no longer accrues dividends on the shares of Series B Preferred Stock due to the very low probability that the holders of the Series B Preferred Stock will elect to convert such shares into shares of Common Stock. Also, the Company is not required to pay dividends by issuing shares of its Common Stock. The Company intends to pay dividends on the shares of Series B Preferred Stock when its financial condition makes any such payment appropriate.

During the third quarter of 2012, Carl Haessler, a Director at that time, accepted 73,854 shares of Common Stock as satisfaction for any and all dividends due him ($92,318 of which $88,319 were accrued) in respect to his direct holdings of 30,000 shares of Series B Preferred Stock through the date of the conversion of 10,000 of such shares. See Note 7 of the Notes to Consolidated Financial Statements.

At September 30, 2013, the arrearages in cumulative dividends on the Series B Preferred Stock totals $2,042,239, of which $1,826,239 has been accrued (see Note 9 of the Notes to Consolidated Financial Statements).

Recent Sales of Unregistered Securities

Non-qualified Independent Director Stock Option Plan

On December 27, 2012, David A Grady, a Director of the Company at that date, was granted an option to purchase 200,000 shares of Common Stock at an exercise price of $0.06 per share under the Company’s Non-qualified Independent Director Stock Option Plan. The option was exercisable through December 2017. The option was scheduled to vest 50% in December 2013 and 25% in each of December 2014 and 2015. At the Company’s Annual Meeting of Shareholders in June 2013, Mr. Grady was not re-elected to serve as a Director; accordingly, the option expired unexercised in accordance with its terms.

On November 21, 2013, Michael Carter, Stanley Porfido and Raymond Sobieski, Directors of the Company as of August 21, 2013, were each granted an option to purchase 200,000 shares of Common Stock at an exercise price of $0.14 per share under the Company’s Non-qualified Independent Director Stock Option Plan. The options are exercisable through November 2018. The option vests 50% in November 2014 and 25% in each of November 2015 and 2016. On February 10, 2014, Mr. Porfido resigned from the Board and, accordingly, the option granted to him expired effective with his resignation.

CAMI Debt

Under the terms of the agreement dated March 25, 2013, with Alice Haessler, Mrs. Haessler received $20,000 in cash and 50,000 shares of Common Stock in full settlement of the obligation owed to Alice Haessler.

2013 Private Placement

Commencing in January 2013, the Company offered a private placement under the provisions of Regulation D promulgated under the Securities Act of 1933, as amended. The 2013 Private Placement consists of up to five hundred thousand dollars ($500,000) for the issuance of up to 5 million shares of Common Stock at $0.10 per share and warrants to purchase up to 2 million shares of Common Stock at an exercise price of $0.50 per share. The warrants expire on January 16, 2018. As of September 30, 2013, the Company has received cash totaling $411,000 for the sale of 4,110,000 shares of Common Stock and warrants to purchase 1,644,000 shares of Common Stock. The fair value of the warrants was determined to be $120,983 using the Black-Scholes valuation model.

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FEI/DTE Stock Purchase Agreement

On March 25, 2013, the Company sold 15 million shares of Common Stock and issued warrants to purchase up to a total of 18 million shares of Common Stock to the Investors (“FEI/DTE Warrants”) for $1,500,000. The FEI/DTE Warrants have a term of five (5) years (“Term”) and may be exercised at a price of $0.20 per share (“Exercise Price”). In the third through fifth years of the Term, the Exercise Price may be satisfied by exchanging Common Stock at the current market price. The FEI/DTE Warrants may be exercised in whole or in part at any time during the Term. The fair value of the warrants was determined to be $806,838 using the Black-Scholes valuation model.

Option and Grant to Chief Executive Officer (“CEO”)

Effective March 25, 2013, the Company granted (i) 600,000 shares of Common Stock and (ii) and an option for the purchase of 1.2 million shares of Common Stock to Michael Parrish, Chief Executive Officer of the Company. The 600,000 shares are issuable at the rate of 100,000 shares at the end of each of the six months commencing April 30, 2013, and as such the average issuance price was $0.10 per share. Also, effective March 25, 2013, the Company granted an option for the purchase of 1.2 million shares of Common Stock to Mr. Parrish at an exercise price of $0.14 per share. The option is exercisable through May 21, 2015 and vests 50% on each of May 21, 2013 and 2014. The fair value of the option was determined to be $119,737 using the Black-Scholes valuation model.

Forbearance and Certain Other Agreements

As a condition precedent to entering into the FEI/DTE Stock Purchase Agreement, the Company was required to enter into (i) forbearance agreements with certain of its major creditors and debtors (“Certain Creditors”) (“Forbearance Agreements”), (ii) the Second Amendment to Employment Agreement with Mr. Blackstone, Vice President and Chief Accounting Officer (“Blackstone Agreement”) and (iii) the First Amendment to Employment Agreement with Mr. Novinskie, President and Chief Financial Officer (“Novinskie Agreement”).). The Forbearance Agreements provide for the Certain Creditors to agree to forbear from making a demand on the Company for payment of their debt for a period of two years from the date of the SPA. The Certain Creditors, Blackstone and/or Novinskie are entitled to receive accelerated payment of their debt should the Company, among other things, (i) have net income, (ii) sell equity securities or (iii) sell assets in excess of stated amounts (see notes 1, 6, 7 and 11 of the notes to Consolidated Financial Statements for discussions regarding the Forbearance Agreements, the Blackstone Agreement and the Novinskie Agreement).

Convertible Note Payable to Dov Amir

Option and Grant to Vice President of Sales

Effective May 8, 2013, the Company granted an option for the purchase of 50,000 shares of common stock to Joseph Sverapa, Vice President of Sales, at an exercise price of $0.20 per share. The option is exercisable through May 2018. The option vests 50% in May 2014 and 25% in each of May 2015 and 2016. The fair value of the option was determined to be $8,878 using the Black-Scholes valuation model.

On August 28, 2013, the Company entered into a Securities Exchange and Settlement Agreement (the “SESA”) with Mr. Benediktson. Pursuant to the SESA, the parties have agreed to settle all obligations between them. The Company (i) issued 2,169,400 shares of the Company’s common stock and (ii) released from escrow the 1 million shares of the Company’s common stock which were collateral for a note receivable from Mr. Benediktson. Such settlement resulted in reductions of $915,887 of accrued bonus expense due to Mr. Benediktson, $37,448 of accounts receivable due from Mr. Benediktson and the principal balance of and interest due pursuant to a certain note receivable from Mr. Benediktson ($444,559).

Note Payable – Equipment Purchase

As additional consideration in connection with the borrowing of $250,000 on January 16, 2014, the Company (i) issued a warrant, exercisable through January 15, 2017, to an unrelated party for the purchase of 300,000 shares of Common Stock at an exercise price of $0.15 per share and (ii) extended the expiration date to December 31, 2016, of previously issued warrants for the purchase of 500,000 shares of Common Stock at an exercise price of $0.15 per share.

Securities Authorized for Issuance Under Equity Compensation Plans

At the Annual Meeting of Shareholders in June 2013, the Shareholders approved the increase in the authorized number of shares of Common Stock to be allocated to the Non-Qualified Independent Director Stock Option Plan from 800,000 shares to 1.6 million shares and to extend the term of such plan so that awards may be made through the Company’s Annual Meeting in 2016.

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The following table contains information as of September 30, 2013, regarding securities authorized for issuance under equity compensation plans including the Non-Qualified Independent Director Stock Option Plan and individual compensation arrangements (see “Recent Sales of Unregistered Securities – Option and Warrants” below):

	Number of securities to be issued upon exercise of outstanding options, warrants and rights		Weighted- average exercise price of outstanding options, warrants and rights	Number of securities remaining available for future issuance under equity compensation plans (excluding securities reflected in column (a))
Plan Category	(a)		(b)	(c)
Equity compensation plans approved by security holders ^{(1) (2)}	400,000	$	0.22	1,200,000
Equity compensation plans not approved by security holders	3.000,000	$	0.18	-
Total	3,400,000	$	0.19	1,200,000

	(1)	On June 2, 2013, Lord Gilbert, a Director, passed away. On December 1, 2013, an option, previously granted to Lord Gilbert for the purchase of 200,000 shares of Common Stock under the Company’s Non-qualified Independent Director Stock Option Plan, expired unexercised.
	(2)	On November 13, 2013, Michael Carter, Stanley Porfido and Raymond Sobieski, Directors of the Company as of August 21, 2013, were each granted an option to purchase 200,000 shares of Common Stock at an exercise price of $0.14 per share under the Company’s Non-qualified Independent Director Stock Option Plan. The options are exercisable through November 2018. The options vest 50% in November 2014 and 25% in each of November 2015 and 2016. On February 10, 2014, Mr. Porfido resigned from the Board and, accordingly, the option granted to him expired effective with his resignation.

Options and Warrants

Options ⁽¹⁾to Purchase Shares of Common Stock:

	2013			2012
Outstanding at beginning of fiscal year		2,150,000			2,550,000
Granted		1,450,000	^(2)(3)(4)		-
Cancelled		-			-
Expired		(200,000)	⁽⁴⁾		(400,000)	⁽⁵⁾⁽⁶⁾
Exercised		-			-
Outstanding at end of fiscal year⁽⁷⁾		3,400,000			2,150,000

	(1)	The Company accounts for all stock-based compensation (options) in accordance with the Financial Accounting Standard Board, or FASB, Accounting Standard Codification, or ASC, Topic 718. Under ASC 718, the fair value of stock options and compensation costs are measured as of the grant date.
	(2)	Effective March 25, 2013, the Company granted an option for the purchase of 1.2 million shares of Common Stock to Michael Parrish, Chief Executive Officer of the Company, at an exercise price of $0.14 per share. The option is exercisable through May 21, 2015 and vests 50% on each of May 21, 2013 and 2014. The fair value of the option was determined to be $119,737 using the Black-Scholes valuation model.
	(3)	Effective May 8, 2013, the Company granted an option for the purchase of 50,000 shares of Common Stock to Joseph Sverapa, Vice President of Sales, at an exercise price of $0.20 per share. The option is exercisable through May 2018. The option vests 50% in May 2014 and 25% in each of May 2015 and 2016. The fair value of the option was determined to be $8,878 using the Black-Scholes valuation model.
	(4)	Effective December 27, 2012, David A. Grady was granted an option to purchase 200,000 shares of Common Stock at an exercise price of $0.06 per share under the Company’s Non-qualified Independent Director Stock Option Plan. At the Company’s Annual Meeting of Shareholders in June 2013, Mr. Grady was not re-elected to serve as a Director; accordingly, the option expired unexercised in accordance with its terms.
	(5)	During fiscal 2007, the Company granted an option for the purchase of 200,000 shares of Common Stock to Richard W. Blackstone, an officer of the Company. The option was exercisable through October 2011, at an exercise price of $0.67 per share. The option expired unexercised during fiscal 2012.
	(6)	During fiscal 2007, David A Grady, was granted an option to purchase 200,000 shares of Common Stock at an exercise price of $0.28 per share under the Company’s Non-qualified Independent Director Stock Option Plan. The option expired during fiscal 2012.
	(7)	Options for the purchase of 2,900,000 shares of Common Stock outstanding as of September 30, 2013 are held by current officers, directors and employees of the Company (“Insiders”). The exercise prices for the options held by Insiders range from $0.14 per share to $0.22 per share (average exercise price of $0.18 per share).

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Warrants to Purchase Shares of Common Stock

At September 30, 2013, warrants for the purchase of 22,744,000 shares of Common Stock at an average exercise price of $0.22 per share are outstanding.

On January 12, 2011, the Revocable Trust Created by Ian B. Jacobs under Agreement dated November 25, 1999 (“RTCIBJ”), loaned $60,000 to the Company pursuant to a promissory note of same date. The Company issued warrants for the purchase of 500,000 shares of Common Stock at an exercise price of $0.15 per share. The warrants were to expire on December 31, 2015; however, as additional consideration in connection with the borrowing of $250,000 from Standard Energy Company (“SECO”) on January 16, 2014, the Company extended the expiration date to December 31, 2016. The trustee of RTCIBJ is affiliated with SECO.

On February 25, 2011, the Company entered into a Consulting Services Agreement with the Musser Group (see Item 7 - Management’s Discussion and Analysis of Financial Condition and Results of Operations – CONSULTING SERVICES AGREEMENT). In addition to certain registered securities, the Company issued to individuals associated with the Musser Group warrants for the purchase of 2,500,000 shares of Common Stock at an exercise price of $0.15 per share. The warrants may not be exercised unless and until the average bid and asking closing price of the Company’s Common Stock exceeds $1.00 per share for a period of thirty consecutive trading days. The warrants are exercisable through February 24, 2016.

On April 26, 2011, the Company granted a warrant for the purchase of 100,000 shares of Common Stock to an engineering consultant to the Company. The warrant is exercisable through April 25, 2016, at an exercise price of $0.22 per share.

On March 25, 2013, in connection with the FEI/DTE Stock Purchase Agreement, the Company issued warrants for the purchase of up to 18 million shares of Common Stock. The FEI/DTE Warrants have a term of five (5) years and may be exercised at a price of $0.20 per share. In the third through fifth years of such term, the exercise price may be satisfied by exchanging Common Stock at the current market price. The FEI/DTE Warrants may be exercised in whole or in part at any time during such term.

In connection with the 2013 Private Placement through September 30, 2013, the Company has issued warrants for the purchase of 1,644,000 million shares of Common Stock at an exercise price of $0.50 per share. The warrants expire on January 16, 2018.

Issuer Purchases of Equity Securities

The Company does not have a stock purchase program for its equity securities.

Item 6. Selected Financial Data.

Not required as the registrant is a smaller reporting company.

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Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.

Forward Looking Statements

The forward-looking statements in this section and other parts of this report involve risks and uncertainties including statements regarding our plans, objectives, goals, strategies, and financial performance. Our actual results could differ materially from the results anticipated in these forward-looking statements as a result of various factors. See the “CAUTIONARY STATEMENTS REGARDING FORWARD-LOOKING STATEMENTS” contained on page 3 of this Annual Report on Form 10-K.

All forward-looking statements speak only as of the date made. All subsequent forward-looking statements are expressly qualified in their entirety by the cautionary statements above. Except as may be required by law, the Company undertakes no obligation to update any forward-looking statement or reflect events or circumstances after the date on which the forward-looking statement is made, or to reflect the occurrence (or non-occurrence) of anticipated (or unanticipated) events or circumstances.

Overview

This Management's Discussion and Analysis of Financial Condition and Results of Operations ("MD&A") describes the matters that we consider important in understanding the results of our operations for the fiscal year ended September 30, 2013 and our financial condition as of September 30, 2013. Our fiscal year begins on October 1 and ends on September 30. Unless otherwise noted, references to "year" pertain to our fiscal year; for example, 2013 refers to fiscal 2013, which is the period from October 1, 2012 to September 30, 2013. In the discussion that follows, we analyze the results of our operations for fiscal 2013, including the trends in our overall business, followed by a discussion of our financial condition. The following discussion should be read in conjunction with our consolidated financial statements and the notes thereto, all included elsewhere in this report.

Results of Operations - Selected information for 2013 and 2012:

	2013		2012
Oil and gas sales	$	404,225	$	373,443
Well management revenues	$	262,813	$	287,446
Total operating revenues	$	679,489	$	670,047
Impairment of prepaid mineral royalties	$	(539,237)	$	-
Gain on sale of oil and gas properties	$	-	$	898,335
Gain on debt forgiveness	$	112,330	$	43,655
Impairment of interest receivable on subscriptions receivable	$	-	$	(207,025)
Net Loss	$	(2,024,509)	$	(772,759)
Oil and Gas Production and Cost Information:
Production:
Oil (Bbl)		2,575		2,112
Gas (Mcf)		34,180		34,404
MCFE		49,630		47,076
Average price:
Oil (per barrel)	$	95.58	$	95.67
Gas (per Mcf)	$	4.63	$	4.98
Per Mcfe	$	8.14	$	7.93
Lease Operating Expenses and Production and Severance Taxes per Mcfe	$	5.23	$	4.31

	Bbl = Barrels of oil
	Mcf = One Thousand cubic feet of gas
	Mcfe = One Thousand cubic feet of gas equivalent

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FEI/DTE STOCK PURCHASE AGREEMENT

A provision of the Agreement requires that the Company shall not make any public announcement or statement concerning the Agreement other than that which the Company is required to disclose on Form 8-K and other required filings with the Securities and Exchange Commission. The Company, consistent with its obligations under the securities laws, is required to seek confidential treatment of the information set forth in the Annex and Exhibits to the SPA.

OIL AND NATURAL GAS OPERATIONS

See Notes 3, 13 and 14 of Notes to Consolidated Financial Statements.

Oil and Gas Sales

Oil and gas sales increased to $404,225 for 2013 from $373,443 for 2012. See the table above in respect to production, average prices and lease operating expenses and production and severance taxes per Mcfe. The average price per Mcfe of sales of oil and gas production increased 3% and oil and gas production (on a Mcfe basis) increased 5%. The increase in total production experienced during 2013 is primarily a result of wells being brought back “on-line” (certain wells had been “off-line” during 2012 and a portion of 2013 for repair) which offset the anticipated decline in production from the wells and the Company purchasing working interests in certain wells during the fourth quarter of 2012. At September 30, 2013, two wells in Texas were off-line awaiting repairs to certain mechanical items such as tubing, rods, down-hole pumps and/or pumping units. Generally, a well is off-line for less than two months; however, rig availability from third party contractors impacts the timing of the well work.

Gain on Sale of Oil and Gas Properties

On January 20, 2012, the Company entered into a purchase and sale agreement pursuant to which the Company agreed to sell certain oil and natural gas leasehold deep rights for cash of $898,335, subject to adjustment as to any title defect that is not cured within the timeframe permitted by the purchase and sale agreement. The sale closed on March 28, 2012. The Company received $898,335 at the closing and recognized gain in the amount of proceeds received. The oil and natural gas leasehold deep rights that were sold were undeveloped, and as such not income-producing to the Company.

Well Management Revenue

Well management revenue decreased 9% to $262,813 for 2013 from $287,446 for 2012. The decrease is primarily the result of the Company purchasing working interests in certain wells during the fourth quarter of 2012. The amounts which may be charged by the Company for well management are set forth in the joint operating agreements governing the wells operated by the Company.

Lease Operating Expenses and Production and Severance Taxes

Lease Operating Expenses and Production and Severance Taxes for 2013 increased 28% from 2012. Lease Operating Expenses and Production and Severance Tax totaled $259,683 for 2013 and $202,905 for 2012. Expenses incurred to restore production from certain wells as discussed above totaled $50,330 and $41,919 for 2013 and 2012, respectively. The balance of the increase experienced during 2013 is primarily a result of the Company purchasing working interests in certain wells during the fourth quarter of 2012.

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Depreciation, Depletion and Amortization - Oil and Gas

Depreciation, depletion and amortization (“DD&A”) – Oil and Gas totaled $48,000 for 2013 and $60,000 for 2012. This 20% decrease is primarily the result of the upward revision of proved developed reserves at the end of 2012 resulting primarily from the increase in estimated future production from certain wells being brought back “on-line” during 2012.

MINERALS OPERATIONS

See Note 4 of Notes to Consolidated Financial Statements.

The Company is in the Development Stage in respect to its Texas Zeolite and is in the Exploration Stage in respect to its Sierra Kaolin mineral holdings in New Mexico and its zeolite mineral holdings in Utah.

Minerals Sales

Minerals sales (zeolite) increased 36% to $7,652 for 2013 from $5,626 for 2012. This increase in mineral sales primarily resulted from initial shipments of product generated by the increased sales efforts of the Company (see “COMMERCIALIZATION OF EXISTING ASSETS” below).

Minerals Exploration Expenses

The Company did not incur minerals exploration expenses during 2013 and 2012. Minerals exploration expenses are primarily for costs associated with the exploration of the mineral deposits and quantification of Mineralized Materials. These expenses are primarily for costs associated with the exploration and quantification of mineral resources and mineral reserves. Such expenses related to the Sierra Kaolin property were the responsibility of the operator of the property, Tecumseh Professional Associates, Inc.

Minerals Operating Expenses and Other Costs

Minerals operating expenses and other costs increased 57% to $30,083 for 2013 from $19,121 for 2012. The increase primarily resulted from research and development expenditures of $7,956 in 2013 as compared to no such expenditures in 2012. During each of 2013 and 2012, the Company paid $6,160 to the Bureau of Land Management (“BLM”) to maintain its federal mining claims in Utah. Tecumseh Professional Associates, Inc. (“TPA”) paid $20,160 to the BLM in each of 2013 and 2012 to maintain CAPI’s Federal mineral claims in New Mexico. Such payment by TPA was in accordance with the provisions of the Restated Development and Operating Agreement with the Company.

DD&A - Minerals

DD&A - minerals totaled $4,556 for 2013 and $253,612 for 2012. Such amounts represent amortization of Patent Rights and Patent License Rights. The Company’s patent expired in February 2012.

Once the Company produces commercial quantities of any of its mineral deposits, the Company will use the unit-of-production method in calculating cost depletion.

Impairment of Prepaid Mineral Royalties

As part of our annual impairment test as of September 30, 2013, and in connection with the Company entering the production phase of its Texas Zeolite minerals in the fourth quarter of 2013, we assessed the estimated future benefit of the royalty advances paid. This assessment was based on the expected production from the mineral properties. Although we are optimistic about the future cash flow of our mineral properties, the future results from our sales efforts and market growth cannot be assured. Based upon this information, we have determined that we are uncertain when we will be able to realize the prepaid mineral royalties and that these assets may not be recoverable through future operations; therefore, we recognized an impairment expense of $539,237 in 2013.

GENERAL AND ADMINISTRATIVE EXPENSES

These expenses increased 27% to $1,672,371 for 2013 as compared to $1,318,177 for 2012.

The Company incurred compensation expense of $284,500 and $87,500 during 2013 and 2012, respectively, in connection with the employment of a new CEO in May 2012. On April 22, 2013, the Company employed its Vice President of Sales. During 2013, the Company incurred expenses, including salary, of $76,270 in connection with its increased marketing activities relating to its zeolite.

The Company recorded stock-based compensation expense of $148,109 and $97,326 for 2013 and 2012, respectively.

In connection with the SPA, the Company entered into an Exclusive Sales Agency and Marketing Agreement with FEI (“FEI Marketing Agreement”). The FEI Marketing Agreement grants to FEI the right to act as the Company’s exclusive marketing and sales agent for natural resources products produced, mined and/or sold by the Company, excluding the Company’s ZeoSure products, in Asia excluding the nation of India. From April through September 2013, in connection with the FEI Marketing Agreement, the Company paid $60,000 to Far East Investments (USA) LLC, an affiliate of FEI. Through September 30, 2013, no sales transactions relating to the Marketing Agreement had occurred.

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The Company recorded amortization expense of $151,237 and $366,575 in 2013 and 2012, respectively, related to the consulting services agreement fees paid to individuals associated with the Musser Group in 2011. The Company recorded amortization expense of $35,441 and consulting fee expense of $30,000 in 2013 related to the investor relations firm consulting services agreement. The Company incurred additional legal expense of $30,000 in 2013 related to a legal services agreement with the Secretary of the Company. See “CONSULTING SERVICES AGREEMENTS” below.

Provision for Doubtful Accounts – Proceeds Receivable from Prior Sale of Oil and Gas Properties

As of September 30, 2013 and 2012, management of the Company believes that the collection of a portion of a $50,000 receivable relating to the sale of certain oil and gas properties during 2008 is in doubt. Accordingly, the Company recognized a provision for doubtful accounts of $25,000 during 2012.

INTEREST EXPENSE

Interest expense decreased 16% to $262,630 for 2013 as compared to $313,371 for 2012. The decrease of $50,741 is primarily attributable to (1) a decrease in amortization expense and (2) a decrease in interest expense as a result of payments of certain debt obligations in 2012 and 2013. During 2013 and 2012, the Company recognized $6,648 and $31,605, respectively, as interest expense regarding the amortization of discounts on debt issuances.

IMPAIRMENT OF SUBSCRIPTIONS RECEIVABLE AND INTEREST RECEIVABLE

As of September 30, 2013, management of the Company believes that the collection of the principal balance of and interest due pursuant to a certain note receivable is in doubt (see Note 11 of the Notes to Consolidated Financial Statements). As of September 30, 2012, the Company changed to the recovery method in accounting for the certain notes receivable and interest thereon. Accordingly, the principal and interest will be recorded when, and if, collected. This change to the recovery method resulted in the recognition of $207,025 as an impairment of the interest receivable at September 30, 2012.

Gain on debt forgiveness

During 2013 and 2012, the Company recognized gain on debt forgiveness of $112,330 and $43,655, respectively, as discussed in Note 6 of the Notes to Consolidated Financial Statements.

CONSULTING SERVICES AGREEMENTS

Musser Group, LLC

On February 25, 2011, the Company entered into a Consulting Services Agreement with the Musser Group, LLC (“Musser Group”) to perform consulting services for the Company through February 2013. During February 2013, the agreement was extended through February 2014 at no cost to the Company. The Company has engaged the Musser Group, an independent contractor, to provide advisory and consulting services to the Company. The Musser Group is engaged to provide (i) managed services; (ii) strategic business planning and implementation; and (iii) assistance in directing and executing the implementation of any strategies approved by the Board of Directors of the Company. The Musser Group’s primary focus is the analysis and validation of market opportunities for the commercialization of products within the Company’s mineral segment. See “COMMERCIALIZATION OF EXISTING ASSETS” below.

The Company issued 2,400,000 shares of Common Stock to individuals associated with the Musser Group in connection with the initial Consulting Services Agreement with the Musser Group. Also, the Company issued to individuals associated with the Musser Group warrants for the purchase of 2,500,000 shares of Common Stock at an exercise price of $0.15 per share. The warrants may not be exercised unless and until the average bid and asking closing price of the Company’s Common Stock exceeds $1.00 per share for a period of thirty consecutive trading days. The warrants are exercisable through February 24, 2016. The Company filed a registration statement under the Securities Act of 1933 on Form S-8 for the shares of Common Stock issued to individuals associated with the Musser Group. The Company determined the fair value of the shares of Common Stock and the warrants issued to individuals associated with the Musser Group to be $735,153 and recorded such amount as prepaid consulting fees. The prepaid consulting fees were amortized over the life of the respective agreement.

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Investor Relations Firm

In March 2013, the Company engaged an investor relations firm (“IR Firm”) to assist management in such activities for one year. The Company issued 600,000 shares (valued at $0.11 per share) of Common Stock to the IR Firm and such contract requires monthly payments of cash of $5,000 during the term of the agreement. The Company is amortizing the prepaid consulting fees of $66,000 over the term of the contract with the IR Firm and unamortized consulting fees total $30,559 at September 30, 2013.

Legal Services

On April 1, 2013, in accordance with the requirements of Section 6.1 of the SPA, the Company entered into an agreement with an attorney to perform corporate governance and securities law services for and representation of the Company for a flat fee of $5,000 per month. The attorney represented FEI and DTE in connection with the SPA. Such attorney became the Secretary of the Company on September 18, 2013.

Liquidity and Capital Resources

The Company’s cash flow used in operating activities was $1,126,060 for 2013. Such use of cash flow reflects the use of $335,000 in payments required by the Forbearance Agreements, Novinskie Agreement and Blackstone Agreement as discussed below in the FEI/DTE Stock Purchase Agreement section.

The Company’s net cash (unrestricted) at September 30, 2013 totaled $140,607. Restricted cash deposits – equity issuances are discussed below in the SPA Additional Provisions section.

To obtain capital in the past, the Company’s capital obtainment methods have included selling its interest in certain oil and gas properties, and borrowing funds from and issuing Common Stock to related and unrelated parties, as well as utilizing joint venture structures. If the Company is not successful in increasing its operating cash flows and the preceding financing methods are not available, the Company may not be able to sustain its operations and may need to seek alternative actions to preserve shareholder value.

Liquidity is a measure of a Company’s ability to access cash. The Company has historically addressed its long-term liquidity requirements through the issuance of equity securities and borrowings or debt financing for certain activities. The Company estimates its capital needs to approximate $1 million for fiscal 2014 and approximate $4 million for fiscal 2015 to satisfy debt payments, pay current operating costs and expenses, and to fund the Company’s growth initiatives.

At present, the Company does not have in place a credit facility or other line of credit upon which it may draw. As operating activities increase, the Company will evaluate the need for such a credit facility. For desired acquisitions or project enhancements, the Company must seek project specific financing. See Note 4 of the Notes to Consolidated Financial Statements regarding ZeoSure LLC. None of the Company’s properties are encumbered.

The prices the Company receives for its oil and gas and the level of production have a significant impact on the Company’s cash flows. The Company is unable to predict, with any degree of certainty the prices the Company will receive for its future oil and gas production and the success of the Company’s exploration, exploitation and production activities. Increases in the sales of the Company’s minerals, which to date have not been mined in substantial commercial quantities, will also affect cash flow.

In an effort to address the liquidity shortfall, the Company sold certain of its oil and gas properties in 2012, is selling certain oil and gas properties in 2014 and is evaluating the sale of certain additional oil and gas properties. It may take months and possibly longer to sell these properties at a suitable price. The market is affected by many factors, such as general economic conditions, availability of financing, interest rates and other factors, including supply and demand that are beyond our control. We cannot predict whether we will be able to sell a property for the price or on terms acceptable to us or whether any price or other terms offered by a prospective purchaser would be acceptable to us. We cannot predict the length of time needed to find a willing purchaser and to close the sale of any property.

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During April 2012, the Company paid $50,000 in cash and issued of 158,290 shares of Common Stock in full satisfaction of a note due an affiliate of Carl A. Haessler, a Director at that time, as discussed in Note 6 of the Notes to Consolidated Financial Statements.

During May 2012, Carl Haessler, a Director at that time, elected to convert 10,000 shares of Series B 8% Cumulative Convertible Preferred Stock into 80,000 shares of Common Stock at the conversion rate of $1.25 per share of Common Stock. Also, Mr. Haessler accepted 73,854 shares of Common Stock as satisfaction for any and all dividends due him ($92,318 of which $88,319 were accrued) in respect to his direct holdings of 30,000 shares of Series B 8% Cumulative Convertible Preferred Stock through the date of the conversion of 10,000 of such shares. See Note 7 of the Notes to Condensed Consolidated Financial Statements.

On August 23, 2012, the Company, entered into an agreement with Michael D. Parrish to become the Chief Executive Officer and a director of the Board of Directors of the Company. The initial term of Mr. Parrish’s employment was effective as of May 18, 2012. In November 2012, the employment contract with Mr. Parrish was renewed. Such contract was orally amended in December 2012 to reflect a change in base salary. Effective March 25, 2013, the Company granted (i) 600,000 shares of common stock and (ii) and an option for the purchase of 1.2 million shares of common stock to Mr. Parrish (see Note 8). Pursuant to Section 4.8 of the SPA, Mr. Parrish’s employment has been extended through December 31, 2013. Mr. Parrish and the Compensation Committee of the Board of the Company are in discussions regarding the contract.

The Company shall use the proceeds from the transaction with FEI and DTE (discussed below) in an effort to establish additional profitable revenue generating activities. The Company is implementing its plan and creating sales, marketing, and distribution programs. The Company has employed a Vice President of Sales and intends to use internal and external resources to focus on mineral sales. In anticipation of increased sales, the Company’s plans include handling, storage and transportation modifications for the mineral properties. Also, the Company plans to continue its workover operations and other activities in certain of its Texas and West Virginia oil and gas properties to enhance its existing revenue stream and profitability.

SPA Additional Provisions

In connection with the SPA the Company entered into an Exclusive Sales Agency and Marketing Agreement with FEI (“FEI Marketing Agreement”). The FEI Marketing Agreement grants to FEI the right to act as the Company’s exclusive marketing and sales agent for natural resources products produced, mined and/or sold by the Company, excluding the Company’s ZeoSure products (see Note 4), in Asia excluding the nation of India. As of September 30, 2013, the Company and FEI are actively seeking to aggregate certain petroleum products and coal supplies owned by others for export to identified buyers in Asia. The completion of these identified transactions is contingent on the finalization of financial and supply arrangements.

As a condition precedent to entering into the FEI/DTE Stock Purchase Agreement, the Company was required to enter into (i) forbearance agreements with certain of its major creditors and debtors (“Certain Creditors”) (“Forbearance Agreements”), (ii) the Second Amendment to Employment Agreement with Mr. Blackstone, Vice President and Chief Accounting Officer (“Blackstone Agreement”) and (iii) the First Amendment to Employment Agreement with Mr. Novinskie, President and Chief Financial Officer (“Novinskie Agreement”). The Forbearance Agreements provide for the Certain Creditors to agree to forbear from making a demand on the Company for payment of their debt for a period of two years from the date of the SPA. The Certain Creditors, Blackstone and/or Novinskie are entitled to receive accelerated payment of their debt should the Company, among other things, (i) have net income, (ii) sell equity securities, (iii) sell assets in excess of stated amounts and/or (iv) if the Company permits an Event of Default (as defined in the respective agreements) (“Accelerated Payments”). See notes 1, 6, 7 and 11 of the notes to Consolidated Financial Statements for discussions regarding the Forbearance Agreements, the Blackstone Agreement and the Novinskie Agreements. At September 30, 2013, the Company is not required to make Accelerated Payments to the Certain Creditors, Blackstone or Novinskie.

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The SPA contains provisions that restrict the use of the $1.5 million received by the Company as follows:

	Initial		Restricted cash at
	Restriction		September 30,
	per the SPA		2013
Forbearance Agreements, Novinskie Agreement and Blackstone Agreement	$	350,000	$	15,000
Marketing Agreement payments to FEI		120,000		60,000
Other marketing and sales activities		360,000		283,730
Transaction closing costs and related		80,000		3,383
Oil and gas properties activities		75,000		23,000
Mineral properties activities		50,000		35,000
Future general and administrative expenses		345,000		225,650
Other costs and expenses		120,000		48,045
Total	$	1,500,000	$	693,808

2013 Private Placement

Commencing in January 2013, the Company offered a private placement under the provisions of Regulation D promulgated under the Securities Act of 1933, as amended (the “2013 Private Placement”). The 2013 Private Placement consists of up to five hundred thousand dollars ($500,000) for the issuance of up to 5 million shares of Common Stock at $0.10 per share and warrants to purchase up to 2 million shares of Common Stock at an exercise price of $0.50 per share. The warrants expire on January 16, 2018. The Company will utilize the proceeds of this private placement for general working capital purposes. At September 30, 2013, the Company had received cash totaling $411,000 for the sale of 4,110,000 shares of Common Stock and warrants to purchase 1,644,000 shares of Common Stock.

Convertible Note Payable to Dov Amir

On May 3, 2013, the Company paid cash of $70,000 and issued 498,000 shares of Common Stock in full satisfaction of all amounts due Amir pursuant to the note. The Company determined the value of the cash and shares of Common Stock (at $0.17 per share) to be $154,660. The if-converted value of the Convertible Note Payable on such date was $183,051. Accordingly, the Company recognized $95,802 as gain on debt forgiveness as a result of such full satisfaction of the note.

Securities Exchange and Settlement Agreement

On August 28, 2013, the Company entered into a Securities Exchange and Settlement Agreement (the “SESA”) with Stephan V. Benediktson, a former officer of the Company. Pursuant to the SESA, the parties have agreed to settle all obligations between them. The Company (i) issued 2,169,400 shares of the Company’s common stock and (ii) released from escrow the 1 million shares of the Company’s common stock which were collateral for a note receivable from Mr. Benediktson. Such settlement resulted in reductions of $915,887 of accrued bonus expense due to Mr. Benediktson, $37,448 of accounts receivable due from Mr. Benediktson and the principal balance of and interest due pursuant to a certain note receivable from Mr. Benediktson ($444,559). The principal balance and interest thereon was impaired as discussed in Note 11 of the Notes to Consolidated Financial Statements. Accordingly, the Company did not recognize any gain or loss as a result of the settlement of all obligations between the parties.

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Certain Debt and Other Obligations

As of September 30, 2013, the Company and certain of its subsidiaries were in default of various obligations and certain debt obligations classified as current liabilities in the accompanying balance sheet as set forth in the following table:

Such defaulted obligations at September 30, 2013 include the following:

Amounts included in accounts payable:
Consulting services and interest due a licensor	$	19,009
EV&T – fees, expenses and accrued interest (subject to forbearance agreement)		213,040
CAMI notes payable and accrued interest:
Subject to forbearance agreements		830,534
Not subject to forbearance agreements		32,171
EV&T note and interest (subject to forbearance agreement)		1,202,318
Note payable to related party and interest thereon (subject to forbearance agreement)		69,587
7.25% Convertible Debentures and interest due a related party (subject to forbearance agreement)		46,689
Note payable to former related party and interest thereon (subject to forbearance agreement)		19,949
Amounts included in accrued compensation expense:
Subject to forbearance agreements		597,009
Not subject to forbearance agreements		94,791
Total	$	3,125,097

See Note 9 of the Notes to Consolidated Financial Statements regarding the cumulative dividends in arrears of $2,042,239 at September 30, 2013, applicable to the Series B 8% Cumulative Convertible Preferred Stock.

Recent Significant Activity

Oil and Gas Segment

On October 6, 2013, the Company entered into an Asset Purchase and Sale Agreement (“APA”) pursuant to which the Company agreed to sell its interest in certain oil and natural gas leasehold deep rights for certain properties located in Burleson County, Texas (“Properties”), for cash, subject to adjustment as to any title defect that is not cured within the timeframe permitted by such agreement. On November 5, 2013, the closing date was delayed from November 6, 2013, to December 6, 2013, in accordance with the APA to allow the Company to address title issues raised by the buyer on November 1, 2013. A First Amendment to the APA was entered into on December 5, 2013, extending the “Delayed Closing Date” until December 17, 2013. On December 17, 2013, the parties closed on the sale of 280 net acres attributable to the Company’s interest in the Properties covered by this portion of the transaction. The Company received $448,038 at the closing and will recognize gain in the amount of proceeds received. The oil and natural gas leasehold deep rights that were sold were undeveloped, and as such not income-producing to the Company. The Company shall use the proceeds for general working capital purposes. On December 16, 2013, a Second Amendment to the APA was entered into by the Company and the Buyer to extend the Delayed Closing Date to January 16, 2014 as to certain Properties to allow the parties to continue to address the Buyer’s concerns about certain issues with the remaining Properties that did not close on December 17, 2013. On January 13, 2014, a Third Amendment to the APA was entered into by the Company and the Buyer to extend the Delayed Closing Date to February 17, 2014.

Texas Zeolite

During September 2013, the company produced saleable minerals from its zeolite mineral deposit in Texas (“Texas Zeolite”). The Company shipped 105 tons of zeolite from its Texas property to a processing and fulfillment facility in Pennsylvania. A portion of such material required additional processing and such processing was completed in October 2013. Backlog orders approximated $2,000 as of September 30, 2013. Sales of the processed and unprocessed product to identified customers commenced in October 2013. On December 16, 2013, the Company entered into an agreement for the purchase of the extraction and crushing equipment of its contract operator of the property for $300,000. On January 16, 2014, the Company borrowed $250,000 from an unrelated party to fund the major portion of the purchase price and closed on the purchase of such equipment. The Company believes the capacity of such equipment is appropriate for anticipated extraction and crushing activities for the next three years. Depending on the level of sales activity, the Company may need to acquire or lease additional equipment. The Company has engaged a contract operator of such equipment and anticipates the commencement of larger-scale extraction activities to commence in February 2014. The Company has also contracted certain micro-processing capabilities to prepare certain samples and test material, including digestive supplements and human consumable products for ZLLC.

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Accelerated Payments

The Certain Creditors, Blackstone and/or Novinskie are entitled to receive accelerated payment of their debt as discussed above. The Company may be required to make Accelerated Payments as a result of the (i) issuances of shares of Common Stock and (ii) the sale of certain oil and gas leasehold rights since the dates of the Forbearance Agreements, Novinskie Agreement and Blackstone Agreement as such issuances and sale did not restrict the use of proceeds from such transactions. The Company anticipates making any required Accelerated Payments in a timely manner.

Commercialization of Existing Assets

The Company has identified fifteen (15) potential development and redevelopment opportunities associated with its existing leasehold acreage in Texas. The Company believes that the potential for the development of such locations will occur within the next few years as a result of renewed interest in the area of its properties. The prevailing oil price and the development of properties in “resource plays” in the area of the Company’s acreage are major factors contributing to such interest. At September 30, 2012 and 2013, the Company had assigned probable and possible reserves to the fifteen (15) potential developmental locations. The Company is actively seeking financing of approximately $2.5 million for its share of the estimated drilling and completion costs of such development opportunities. To obtain the capital necessary to develop these, the Company (1) continues to seek project specific funding commitments and other capital funding alternatives and (2) is evaluating the sale of certain oil and gas producing properties.

The Company continues to pursue plans to commercialize its kaolin and zeolite projects which are critical for the Company to achieve profitability and establish the Company as a market innovator in industrial minerals. Those plans have progressed from the data acquisition and analysis phase into ongoing mineral processing and facility design phase. The Company and its current partner and potential other partners are actively investigating various commercial applications for its mineral based products. The Company continues to focus on establishing business and or financial relationships that will provide the necessary capital to effectively exploit its kaolin and zeolite mineral resource holdings.

In connection with the SPA, the Company entered into an Exclusive Sales Agency and Marketing Agreement with FEI (“Marketing Agreement”). The Marketing Agreement grants to FEI the right to act as the Company’s exclusive marketing and sales agent for natural resources products produced, mined and/or sold by the Company, excluding the Company’s ZeoSure products (see Note 4 of the Notes to Consolidated Financial Statements), in Asia excluding the nation of India.

Zeolite

In respect to sanitary wastewater treatment applications, the Company continues to supply material for use in a sequential batch reactor facility located in Pennsylvania and the Company has provided material for a confirmation test of the use of its ReNuGen^(TM) product in an alternate design treatment plant. Certain small scale tests have progressed to the point where larger scalable pilot tests of commercial applications for zeolite are in progress in respect to soil additives, animal waste treatment and treatment of industrial wastewaters.

In October, 2009, the Company entered into an agreement to sell zeolite to be used in certain agricultural applications limited to feed supplements in a ten state area in the south-central part of the US. The Company has made limited shipments since fiscal 2010. The Company made no shipments during fiscal 2012. The development of this market has been hampered as a result of economic and environmental factors affecting the purchaser. During August 2012, the Company gave notice to the purchaser to terminate the agreement in October 2012 pursuant to the notice provision provided in the agreement. The Company intends to seek alternatives for the sale of its zeolite to be used in agricultural applications.

In February 2010, the Company entered into a License Agreement concerning two US method patents for the treatment of wastewaters. Such patents utilize the Company’s zeolite. The license applies to the US and covers the use of the technology in water, wastewater and waste treatment in animal feed operations, agriculture, and aquaculture. In addition, the license applies to the treatment of sanitary wastewater on Federal facilities, military bases and lands administered by the US Bureau of Indian Affairs. The Company issued 140,000 shares of its Common Stock in consideration for the License Agreement. The Company recorded $40,907 as patents license rights based on an average price of $0.29 per share. Such patent license rights are fully amortized as of September 30, 2013.

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On April 8, 2011, in connection with the efforts of the Musser Group, the Company entered into a Material Supply and Joint Venture Agreement between CAMI (wholly-owned subsidiary) and VitaminSpice, Inc. (“VSI”) pursuant to which CAMI agrees to supply Clinoptilolite (zeolite) to VSI in connection with the introduction by VSI of detoxification products into targeted geographic markets. VSI is obligated to utilize CAMI as its sole supplier of Clinoptilolite. The agreement does not specify any minimum quantity supply requirements of CAMI. In addition to an initial price per ton for Clinoptilolite to be sold to VSI, CAMI will share in the profits from the sales of such products by VSI. CAMI has provided material to VSI for use in product and market strategy development, as well as potential clinical studies. The Company made no shipments of product to VSI and the Company has not received any orders from VSI. VSI has not met certain performance standards as set forth in the agreement. On April 13, 2012, the Company gave notice to VSI and terminated the agreement pursuant to the provision in respect to termination for cause.

On July 3, 2012, CAMI entered into an operating agreement for ZeoSure LLC (“ZLLC”) as one of ZLLC’s two managing members. ZLLC was formed for the purpose of developing human consumption products including but not limited to detoxification and digestive supplements and human consumable products utilizing CAPI’S Clinoptilolite zeolite mineral focusing on markets throughout the world with a primary emphasis on markets in the United States and Asia. CAMI and SafeHatch LLC, an entity controlled by an individual previously affiliated with the Musser Group, are the managing members and each owns 47.5% of ZLLC. The remaining 5% of ZLLC is owned by the Musser Group. The members of ZLLC intend to seek initial capital of $1 million from third parties and enter into product marketing and distribution agreements with participants active within the dietary supplements market in the next few months. The operating agreement has not been ratified by the Audit Committee of the Board of Directors of the Company. Other than seeking initial capital and attempting to identify viable product marketing and distribution partners, ZLLC had no activity through September 30, 2013 (see “Recent Significant Activity” above).

Since hiring its Vice President of Sales in April 2013, the Company has increased its efforts to develop and expand viable markets for zeolite based products. In general these potential markets are based on the results of prior testing efforts. As such, the Company has begun to introduce an absorbent product, Cite-Clean™ for use in minimizing unintended industrial discharges and a natural product additive for municipal compost producer to control odors and enhance the eventual nutrient uptake by plants in agricultural and horticultural applications.

Kaolin

The efforts of the Company and Tecumseh Professional Associates, Inc. (“TPA”) to evaluate the Sierra Kaolin deposit are ongoing. The venture’s efforts to commercialize the Sierra Kaolin deposit have focused on an initial target area encompassing approximately 32 acres out of the project’s 2,740 acres. The test minerals extracted from the target area have been processed into product formulations determined by independent consultants to be suitable (a) for coatings, fillers and pigments for use within the paint and paper manufacturing industries, and (b) as an additive in cement formulations. The analysis results of the processed minerals with respect to its physical properties including brightness, color, opacity, strength, and oil absorption have indicated that commercially viable products can be produced from the deposit’s extracted minerals.

In December 2009, the Sierra Kaolin Open Pit Clay Mine project cleared the regulatory review process and the project’s definitive USDA Forest Service Plan of Operations was approved. Mine site plans have been prepared to facilitate planned extraction operations. Since receiving project approval, the venture, with the assistance of its consultants, has made technical presentations of the product formulations to entities active (a) in the specialty cement applications and (b) on both the demand and supply sides of the coatings, fillers and pigments sectors of the paint and paper industries. While the feedback from these presentations has been encouraging, market conditions within the paper and housing industries have not been favorable; however, interest in the Sierra Kaolin deposit’s minerals for use in meta-kaolin applications has remained favorable. As such the project manager is focusing its commercialization efforts in this area.

During fiscal 2012, in addition to the meta-kaolin applications, because of its natural brightness, interest has been expressed relative to the use of the Sierra Kaolin material as a possible economic substitute and/or extender for titanium oxide within the filter and coating industries. TPA has also been in discussions with entities within the mining sector relative to other joint venture opportunities involving the mineral claims controlled by the Sierra Kaolin project. To date, the discussions have been exploratory in nature.

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During 2013, third party interest in the Sierra Kaolin Project has increased. Management of the Company believes the market for fillers and coatings (the historical primary uses for Kaolin products) have begun to recover, while the interest in Meta-Kaolin products in the Southwestern United States has continued to increase. This later market is of particular interest to the Company because test data indicates that its Sierra Kaolin mineral has specific physical and chemical properties that support its use in the application. TPA as the project’s manager is aggressively pursuing these commercialization opportunities. Pursuant to the Restated Development and Operating Agreement with TPA, (i) TPA shall earn 65 % of the net cash flow from the Sierra Kaolin operations in the event TPA develops the property, including the construction and funding of an appropriate processing facility and (ii) TPA shall be entitled to 50% of the sale proceeds in the event of a divestiture of the Sierra Kaolin property prior to its development by TPA.

Off-balance Sheet Arrangements, CONTRACTUAL OBLIGATIONS AND COMMITMENTS

We do not have off-balance sheet arrangements, financings, or other relationships with unconsolidated entities or other persons, also known as “Variable Interest Entities,” that have or are reasonably likely to have a current or future material effect on our financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity or capital expenditures. However, the request for project financing for ZeoSure LLC is being presented to potential third parties and management of the Company will evaluate alternative financing structures as part of any negotiations with those potential sources of capital. Also, the company intends to request project financing for the (15) potential development and redevelopment opportunities associated with its existing leasehold acreage in Texas and management of the Company will evaluate alternative financing structures as part of any negotiations with those potential sources of capital.

We have various contractual obligations that are appropriately recorded as liabilities in our consolidated financial statements. Certain other items are not recognized as liabilities in our consolidated financial statements. Examples of items not recognized as liabilities in our consolidated financial statements are commitments to purchase goods and services that have not yet been received or rendered, respectively, as of September 30, 2013, and future minimum lease payments for the use of property and equipment under operating lease agreements.

Certain contractual obligations classified as noncurrent liabilities in the consolidated balance sheet as of September 30, 2013 include accrued bonus expense ($457,944) and Series B 8% Cumulative Convertible Preferred Stock Dividends accrued ($1,826,239). See Note 9 of the Notes to Consolidated Financial Statements regarding the cumulative dividends in arrears of $2,042,239 at September 30, 2013, applicable to the Series B 8% Cumulative Convertible Preferred Stock.

New Accounting Standards

For details of applicable new accounting standards, please, refer to Note 2 of Notes to Consolidated Financial Statements.

Critical Accounting Policies

General

The preparation of financial statements in accordance with accounting standards generally accepted in the United States requires management to make estimates and assumptions that affect both the recorded values of assets and liabilities at the date of the financial statements and the revenues recognized and expenses incurred during the reporting period. Our estimates and assumptions affect our recognition of deferred expenses, bad debts, income taxes, the carrying value of our long-lived assets and our provision for certain contingencies. We evaluate the reasonableness of these estimates and assumptions continually based on a combination of historical information and other information that comes to our attention that may vary our outlook for the future. Actual results may differ from these estimates under different assumptions.

We suggest that the Summary of Significant Accounting Policies, as described in Note 2 of Notes to Consolidated Financial Statements, be read in conjunction with this Management’s Discussion and Analysis of Financial Condition and Results of Operations. We believe the critical accounting policies that most impact our consolidated financial statements are described below.

Going Concern

The financial statements have been prepared on the basis of a going concern, which contemplates that the Company will be able to realize assets and discharge liabilities in the normal course of business. Accordingly, they do not give effect to adjustments that would be necessary should the Company be required to liquidate its assets. For 2013 and 2012, the Company incurred a net loss applicable to common shareholders of $2,132,509 and $884,759, respectively. The ability of the Company to meet its current liabilities of $5,459,700 and its total liabilities of $7,753,883 at September 30, 2013, and to continue as a going concern is dependent upon the availability of future funding, achieving profitability within its mineral segment, and ongoing profitability within its oil and gas operations. If the Company is unable to continue as a going concern, there is uncertainty relative to full recoverability of its assets.

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Fair Value of Financial Instruments

The Company’s only financial instruments are cash, short-term trade receivables, payables, and debt. The carrying amounts reported in the accompanying consolidated financial statements for cash, short-term trade receivables, payables and debt approximate fair values because of the immediate nature of short-term maturities of these financial instruments. The Company has no long-term or short-term bank debt outstanding at September 30, 2013.

Receivables

In the normal course of business, we extend credit to our customers on a short-term basis. Our principal customers are major oil and natural gas exploration, development and production companies. Credit risks associated with these customers are considered minimal. Dealings with smaller, local companies, particularly with the current difficulties in equity and credit markets, pose the greatest risks. We routinely review our accounts receivable balances and make provisions for doubtful accounts as necessary. Accounts are reviewed on a case by case basis and losses are recognized in the period if we determine it is likely that receivables will not be fully collected. We may also provide a general provision for accounts receivables based on existing economic conditions.

Subscriptions Receivable and Interest Receivable

As of September 30, 2013, management of the Company believes that the collection of the principal balance of and interest due pursuant to a certain note receivable is in doubt (see Note 11 of the Notes to Consolidated Financial Statements). As of September 30, 2012, the Company changed to the recovery method in accounting for the notes receivable and interest thereon. Accordingly, the principal and interest will be recorded when, and if, collected. This change to the recovery method resulted in the recognition of $207,025 as an impairment of the interest receivable at September 30, 2012. The principal balance of the notes receivable ($576,000) was previously reflected as subscriptions receivable. Additional paid-in capital was reduced by $576,000 as of September 30, 2012, to reflect the impairment of the notes receivable.

Oil and gas properties

The Company follows the successful efforts method of accounting for the costs of exploration and development activities. Costs of successful exploration wells, development wells, and direct acquisition costs of developed and undeveloped leases containing proved reserves are capitalized and amortized on a unit-of-production method over the life of the related reserves. Costs of exploratory wells found to be dry are expensed. Support equipment and other property and equipment recorded at cost are amortized using the straight-line method over their estimated useful lives.

Mineral properties

The Company recorded the acquisition of Clean Age Minerals, Inc., and associated minerals rights on September 19, 2000, at cost as based on the stated value of the Series B Preferred Stock issued which was less than the appraised value of the entity acquired. The Company has not produced large-scale quantities of any of its mineral deposits. The Company is in the production phase of its Texas Zeolite as saleable minerals have been extracted (produced) from such mineral deposit. Once the Company produces commercial quantities of any of its mineral deposits, the Company will use the unit-of-production method in calculating cost depletion.

Impairment of Long-Lived Assets

Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Recoverability of assets to be held and used is measured by comparison of the carrying amount of an asset to future net cash flows expected to be generated by the asset. If such assets are considered to be impaired, the impairment to be recognized is measured by the amount that the carrying amount of the assets exceeds the fair value of the assets. At September 30, 2013, we reviewed our long-lived assets and determined that the prepaid mineral royalties were impaired as discussed in Note 2 of the Notes to Consolidated Financial Statements. At September 30, 2012, we reviewed our long-lived assets and determined no impairment was necessary.

Long-Lived Assets to be Disposed Of

Assets to be disposed of are reported at the lower of the carrying amount or fair value less costs to sell. The oil and gas leasehold rights subject to a purchase and sale agreement dated October 6, 2013, have no carrying amount in the accompanying Consolidated Balance Sheets as of September 30, 2013 and 2012.

Environmental Remediation

The Company's policy is to accrue environmental and cleanup related costs of a noncapital nature when it is both probable that a liability has been incurred and when the amount can be reasonably estimated. The Company accrues for certain environmental remediation related activities for which commitments or cleanup plans have been developed or for which costs or minimum costs can be reasonably estimated. It is reasonably possible that, due to uncertainties associated with defining the nature and extent of contamination, application of laws and regulations by regulatory authorities and changes in remediation technology, the ultimate cost of remediation could materially change in the future. Any liability established would not necessarily be the minimum or maximum liability, but based upon the Company's experience and the advice of its outside consultants; it would most accurately reflect the Company's liability based on the information currently available. As a general rule, the Company accrues remediation costs for continuing operations on a discounted basis and does not accrue for normal operating and maintenance costs for site monitoring and compliance requirements. It has not been necessary for the Company to record any environmental remediation costs for 2013 and 2012.

Asset Retirement Obligation

The Company may have an obligation to retire property, plant, and equipment at the end of their useful fives. The Company performs periodic reviews for any changes in facts and circumstances that might enable it to determine a reasonable estimate of any asset retirement obligation (“ARO”). When an ARO is necessary, the Company estimates the fair value, establishes a liability, and increases the carrying value of the assets by a corresponding amount.

An ARO associated with the retirement of a tangible long-lived asset is required to be recognized as a liability in the period in which it is incurred and becomes determinable. Under this method, when liabilities for dismantlement and abandonment costs, excluding salvage values, are initially recorded, the carrying amount of the related assets (mineral, oil and natural gas properties) is increased. The fair value of the ARO asset and liability is measured using expected future cash outflows discounted at the credit-adjusted risk-free interest rate. Accretion of the liability is recognized each period using the interest method of allocation, and the capitalized cost is depleted over the useful life of the related asset. The estimated residual salvage values are taken into account in determining amortization and depreciation rates.

Generally, the salvage value of the Company’s producing wells or mining deposits is expected to exceed the cost of site restoration and abandonment. To date, mining and exploration activities of the Company's mineral deposits have been conducted by contract mining companies. As mining activity increases, the Company may accrue site restoration costs as appropriate.

	37

As of September 30, 2013 and 2012, the Company has accrued future abandonment costs of $10,000 of costs associated with the potential abandonment and restoration of a mining deposit that was abandoned prior to fiscal 2010.

Item 7A. Quantitative and Qualitative Disclosures About Market Risk.

Not required as the registrant is a smaller reporting company.

	38

Item 8. Financial Statements and Supplementary Data.

The following audited financial statements are included herein:

	*	Reports of Independent Registered Public Accounting Firms
	*	Consolidated Balance Sheets
	*	Consolidated Statements of Operations
	*	Consolidated Statements of Shareholders’ Equity
	*	Consolidated Statements of Cash Flows
	*	Notes to Consolidated Financial Statements

The following unaudited supplementary information is included herein in Notes 13 and 14 of the Notes to Consolidated Financial Statements:

	*	Estimated Net Quantities of Proved Oil and Gas Reserves
	*	Standardized Measure of Discounted Future Net Cash Flow from Estimated Production of Proved Oil and Gas Reserves
	*	Summary of Changes in Standardized Measure of Discounted Future Net Cash Flows

	39

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and

Shareholders of Daleco Resources Corporation

We have audited the accompanying consolidated balance sheet of Daleco Resources Corporation and Subsidiaries as of September 30, 2013, and the related consolidated statements of operations, shareholders’ equity, and cash flows for the year then ended. These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audit included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the consolidated financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audit provides a reasonable basis for our opinion.

In our opinion, the 2013 consolidated financial statements referred to above present fairly, in all material respects, the financial position of Daleco Resources Corporation and Subsidiaries as of September 30, 2013, and the results of their operations and their cash flows for the year then ended in conformity with accounting principles generally accepted in the United States of America.

The accompanying consolidated financial statements for the year ended September 30, 2013 have been prepared assuming that the Company will continue as a going concern. As discussed in Note 1 to the consolidated financial statements, the Company has suffered significant recurring net losses from operations and negative operating cash flow, which raise substantial doubt about its ability to continue as a going concern. Management’s plans concerning these matters are also described in Note 1 to the consolidated financial statements. The consolidated financial statements do not include any adjustments that might result from the outcome of these uncertainties.

/s/ MAYER HOFFMAN MCCANN P.C.
Mayer Hoffman McCann P.C.

Plymouth Meeting, PA
February 14, 2014

	40

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders

of Daleco Resources Corporation

We have audited the accompanying consolidated balance sheet of Daleco Resources Corporation and Subsidiaries as of September 30, 2012, and the related consolidated statements of operations, shareholders’ equity, and cash flows for the year then ended. These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audit included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the consolidated financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audit provides a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Daleco Resources Corporation and Subsidiaries as of September 30, 2012, and the results of their operations and cash flows for the year then ended, in conformity with accounting principles generally accepted in the United States of America.

The accompanying financial statements have been prepared assuming that the Company will continue as a going concern. As discussed in Note 1 to the financial statements, the Company has suffered significant recurring net losses and negative operating cash flow, which raise substantial doubt about its ability to continue as a going concern. Management’s plans regarding these matters are also described in Note 1 to the financial statements. The financial statements do not include any adjustments that might result from the outcome of these uncertainties.

/s/ VASQUEZ & COMPANY LLP
Vasquez & Company LLP

Los Angeles, CA
January 31, 2013

	41

DALECO RESOURCES CORPORATION AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

SEPTEMBER 30, 2013 AND 2012

	2013		2012
ASSETS
Current Assets:
Cash	$	140,607	$	190,738
Accounts receivable, net of allowance for doubtful accounts of $25,000 at September 30, 2013 and 2012		257,761		242,182
Inventory		40,500		-
Prepaid consulting fees		30,559		151,237
Other current assets		26,461		8,615
Total Current Assets		495,888		592,772
Other Assets:
Patent rights		6,620		-
Accumulated amortization of patent rights		-		-
Net patent rights		6,620		-
Patents license rights		40,907		40,907
Accumulated amortization of patents license rights		(40,907)		(36,351)
Net patents license rights		-		4,556
Prepaid mineral royalties- long-term		-		509,254
Restricted cash deposits – operations		109,681		109,609
Restricted cash deposits – equity issuances		693,808		-
Total Other Assets		810,109		623,419
Property, Plant and Equipment:
Mineral properties, at cost		9,877,128		9,877,128
Accumulated depreciation, depletion and amortization		(95,000)		(95,000)
Net mineral properties		9,782,128		9,782,128
Oil and gas properties, at cost		4,471,590		4,471,590
Accumulated depreciation, depletion and amortization		(4,144,939)		(4,096,939)
Net oil and gas properties		326,651		374,651
Office equipment, furniture and fixtures, at cost		61,502		61,502
Accumulated depreciation		(61,502)		(61,502)
Net office equipment, furniture and fixtures		-		-
Total Net Property, Plant and Equipment		10,108,779		10,156,779
TOTAL ASSETS	$	11,414,776	$	11,372,970

SEE NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

	42

DALECO RESOURCES CORPORATION AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

SEPTEMBER 30, 2013 AND 2012

	2013		2012
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current Liabilities:
Accounts payable	$	1,317,771	$	1,312,526
Revenue payable to oil and gas royalty and other working interest owners		969,649		917,144
Federal and state income taxes payable		192,427		192,427
Accrued interest expense		1,151,911		1,099,441
Accrued compensation expense		691,800		690,798
Accrued expense reimbursements		-		19,051
EV&T note payable		567,213		567,213
CAMI notes payable		435,943		455,943
Notes payable - related parties		60,000		85,256
7.25% convertible debentures, net of unamortized discount of $2,044 and $4,515 at September 30, 2013 and 2012, respectively		42,956		40,485
Premium finance note payable		11,519		1,380
Note Payable - other		18,511		-
Total Current Liabilities		5,459,700		5,381,664
Long-term Liabilities:
Long-term Debt:
Convertible note payable, net of unamortized discount of $22,908 at September 30, 2012		-		239,717
Convertible accrued interest on convertible note payable		-		5,359
Accrued bonus expense		457,944		1,373,831
Series B 8% cumulative convertible preferred stock dividends accrued		1,826,239		1,826,239
Future abandonment costs		10,000		10,000
TOTAL LIABILITIES		7,753,883		8,836,810

Commitments and Contingencies (see Note 8)

SHAREHOLDERS’ EQUITY:
Preferred Stock – 20,000,000 shares authorized
Series A preferred stock – par value $0.01 per share (issued and outstanding: none)		-		-
Series B 8% cumulative convertible preferred stock – par value $0.01 per share (issued and outstanding: 135,000 shares); liquidation preference of $1,350,000 plus arrearages in cumulative dividends of $2,042,239 and $1,934,239, respectively (see Note 9)		1,350		1,350
Common Stock – 150,000,000 and 100,000,000 shares authorized, respectively – par value $0.01 per share (issued and outstanding: 72,468,458 and 49,441,058 shares, respectively) (see Note 9)		724,685		494,411
Additional Paid-in Capital		47,980,786		45,989,639
Warrants (issued and outstanding) to purchase 22,744,000 and 3,100,000 shares of Common Stock, respectively		1,357,002		429,181
Accumulated deficit		(46,402,930)		(44,378,421)
TOTAL SHAREHOLDERS’ EQUITY		3,660,893		2,536,160
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	$	11,414,776	$	11,372,970

SEE NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

	43

DALECO RESOURCES CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

FOR THE YEARS ENDED SEPTEMBER 30, 2013 AND 2012

	2013		2012
Revenues:
Oil and gas sales	$	404,225	$	373,443
Well management revenue		262,813		287,446
Royalty receipts		4,799		3,532
Mineral sales		7,652		5,626
Total Operating Revenues		679,489		670,047

Expenses:
Lease operating expenses - oil and gas		237,661		182,027
Production and severance taxes – oil and gas		22,022		20,878
Operating and other expenses - minerals		30,083		19,121
Impairment of prepaid mineral royalties		539,237		-
Depreciation, depletion and amortization		52,556		313,612
General and administrative expenses		1,672,371		1,318,177
Total Expenses		2,553,930		1,853,815
Loss From Operations		(1,874,441)		(1,183,768)

Other Income (Expense):
Interest and dividend income		232		20,114
Interest expense		(262,630)		(313,371)
Gain on sale of oil and gas properties		-		898,335
Impairment of interest receivable on subscriptions receivable		-		(207,025)
Gain on debt forgiveness		112,330		43,655
Provision for doubtful account – proceeds receivable from prior sale of oil and gas properties		-		(25,000)
Impairment of securities available for future sale		-		(5,699)
Total Other Income (Expense), Net		(150,068)		411,009
Loss before income taxes		(2,024,509)		(772,759)
Taxes based on income		-		-
Net loss		(2,024,509)		(772,759)
Preferred stock dividends, arrearage accumulated (see Note 9)		(108,000)		(112,000)
Net loss applicable to common shareholders	$	(2,132,509)	$	(884,759)
Basic and fully diluted net loss per share	$	(0.04)	$	(0.02)
Weighted-average number of shares of common stock outstanding		60,135,389		49,187,396

SEE NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

	44

DALECO RESOURCES CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF SHAREHOLDERS’ EQUITY

FOR THE YEARS ENDED SEPTEMBER 30, 2013 AND 2012

																	Accumu-
	Preferred Stock ⁽¹⁾										Warrants						lated
	Series B Cumulative										to						Other		Total
	Convertible Preferred								Additional		Purchase				Subscrip-		Compre-		Share-
	Stock				Common Stock				Paid-in		Common		Accumulated		tions		hensive		holders’
	Shares		Amount		Shares		Amount		Capital		Stock		Deficit		Receivable		Loss		Equity
Balance, September 30, 2011		145,000	$	1,450		48,988,914	$	489,889	$	46,289,089	$	429,181	$	(43,605,662)	$	(576,000)	$	(5,699)	$	3,022,248
Issuance of common stock in payment of debt and interest						298,290		2,983		101,281										104,264
Conversion of Series B preferred stock into common stock		(10,000)		(100)		80,000		800		(700)										-
Issuance of Common Stock in fulfillment of Series B preferred stock dividend obligation						73,854		739		78,643										79,382
Impairment of subscriptions receivable										(576,000)						576,000				-
Other comprehensive loss																		5,699		5,699
Stock-based compensation expense										97,326										97,326
Net loss														(772,759)						(772,759)
Balance, September 30, 2012		135,000		1,350		49,441,058		494,411		45,989,639		429,181		(44,378,421)		-		-		2,536,160
2013 Private Placement: Issuance of common stock and warrants to purchase 1,644,000 shares of common stock						4,110,000		41,100		248,917		120,983								411,000
FEI/DTE Stock Purchase Agreement:
Issuance of common stock and warrants to purchase 18 million shares of common stock						15,000,000		150,000		543,162		806,838								1,500,000
Costs of issuance										(44,466)										(44,466)
Issuances of common stock:
In payment of interest						50,000		500		5,000										5,500
Consulting services agreement						600,000		6,000		60,000										66,000
Repayment of convertible note						498,000		4,980		79,680										84,660
Payment of compensation						600,000		6,000		94,000										100,000
Settlement with Benediktson						2,169,400		21,694		856,745										878,439
Stock-based compensation expense										148,109										148,109
Net loss														(2,024,509)						(2,024,509)
Balance, September 30, 2013		135,000	$	1,350		72,468,458	$	724,685	$	47,980,786	$	1,357,002	$	(46,402,930)	$	-	$	-	$	3,660,893

(1)

No shares of Series A preferred stock were outstanding at September 30, 2011 and no shares were issued or outstanding during 2012 and 2013.

SEE NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

	45

DALECO RESOURCES CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

FOR THE YEARS ENDED SEPTEMBER 30, 2013 AND 2012

	2013		2012
Cash Flows From Operating Activities:
Net loss	$	(2,024,509)	$	(772,759)
Adjustments to reconcile net loss to net cash used in operations:
Depreciation, depletion and amortization		52,556		313,612
Impairment of prepaid mineral royalties		539,237		-
Amortization of prepaid consulting services agreements		186,678		366,575
Amortization of discount on notes payable		4,177		29,128
Amortization of discount on 7.25% convertible debentures		2,471		2,477
Gain on debt forgiveness		(112,330)		(43,655)
Provision for doubtful account - proceeds receivable from prior sale of oil and gas properties		-		25,000
Impairment of securities available for future sale		-		5,699
Impairment of interest receivable on subscriptions receivable		-		207,025
Stock-based compensation expense		148,109		97,326
Gain on sale of oil and gas properties		-		(898,335)
Changes in operating assets and liabilities:
Receivables		53,027		296,807
Inventory		(40,500)		-
Other current assets		(17,846)		(1,190)
Prepaid mineral royalties		(29,983)		(29,986)
Restricted cash deposits – operations		(72)		(1,131)
Accounts payable		5,245		(204,234)
Revenue payable		52,505		(93,188)
Accrued interest expense		69,139		176,276
Other accrued expenses		(13,964)		(6,555)
Net cash used in operating activities		(1,126,060)		(531,108)

Cash Flows From Investing Activities:
Acquisition of proved developed producing oil and gas properties		-		(47,078)
Additions of patents costs		(6,620)		-
Cash restricted pursuant to equity issuance agreement		(693,808)		-
Proceeds from sale of oil and gas properties		-		898,335
Net cash provided by (used in) investing activities		(700,428)		851,257

Cash Flows From Financing Activities:
Payments on notes and debt		(141,915)		(197,980)
Proceeds from borrowings		51,738		19,652
Proceeds from equity issuances, net of cash issuance costs and expenses of $44,466		1,866,534		-
Net cash provided by (used in) financing activities		1,776,357		(178,328)
Net change in cash		(50,131)		141,821
Cash at beginning of year		190,738		48,917
Cash at end of year	$	140,607	$	190,738

SEE NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

	46

DALECO RESOURCES CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

FOR THE YEARS ENDED SEPTEMBER 30, 2013 AND 2012

	2013		2012

Supplemental Information:
Income taxes paid	$	-	$	-
Interest paid	$	158,948	$	55,126

Supplemental Disclosure of Non-cash Transactions:
Issuance of common stock in satisfaction of Series B 8% cumulative preferred stock dividend arrearages due a related party	$	-	$	88,319
Conversion of Series B 8% cumulative preferred stock into common stock	$	-	$	100,000
Issuance of common stock in payment of principal on convertible note payable	$	84,660	$	70,000
Issuance of common stock in payment of principal and interest on CAMI note payable due a related party	$	5,500	$	34,264
Impairment of subscriptions receivable	$	-	$	(576,000)
Issuance of common stock in payment of compensation	$	100,000	$	-
Issuance of common stock for consulting fees	$	66,000	$	-
Benediktson settlement agreement:
Settlement of accounts receivable	$	37,448	$	-
Settlement of bonus expense	$	(915,887)	$	-
Issuance of common stock	$	878,439	$	-

SEE NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

	47

DALECO RESOURCES CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED SEPTEMBER 30, 2013 AND 2012

1.	CONTINUED OPERATIONS

The financial statements have been prepared on the basis of a going concern, which contemplates that Daleco Resources Corporation and its subsidiaries (the “Company”) will be able to realize assets and discharge liabilities in the normal course of business. Accordingly, they do not give effect to adjustments that would be necessary should the Company be required to liquidate its assets. At September 30, 2013, the Company’s current assets total $495,888. For the fiscal years ended September 30, 2013 (“2013”) and 2012 (“2012”), the Company incurred net losses applicable to common shareholders of $2,132,509 and $884,759, respectively. The ability of the Company to meet its current liabilities of $5,459,700 and its total liabilities of $7,753,883 and to continue as a going concern is dependent upon the availability of future funding, achieving profitability within its mineral segment and ongoing profitability within its oil and gas operations. If the Company is unable to continue as a going concern, there is uncertainty relative to full recoverability of its assets. The financial statements do not reflect any adjustments relating to these uncertainties.

FEI/DTE Stock Purchase Agreement

On March 25, 2013, the Company finalized a Stock Purchase Agreement (“SPA”) with Far East Investments, LLC, a California limited liability company (“FEI”) and DTE Investment Ltd., a British Virgin Island company (“DTE”) (hereinafter FEI and DTE are sometimes collectively referred to as the “Investors” and individually as an “Investor”). The Investors paid the Company $1.5 million for 15 million shares of the Company’s common stock, par value $.01 (“Common Stock”) and the Company issued warrants for the purchase of up to 18 million shares of Common Stock to FEI and DTE (“FEI/DTE Warrants”). The FEI/DTE Warrants have a term of five (5) years (“Term”) and may be exercised at a price of $0.20 per share (“Exercise Price”). In the third through fifth years of the Term, the Exercise Price may be satisfied by exchanging Common Stock at the current market price. The FEI/DTE Warrants may be exercised in whole or in part at any time during the Term.

Under the SPA for so long as the Investors retain 51% or more of the Common Stock issued under the SPA (7,650,000 shares), the Investors are entitled to request that the Registrant nominate for election, by the shareholders of the Registrant at the Registrant’s annual meeting of shareholders, two persons suitable to serve as directors of the Registrant.

A provision of the Agreement requires that the Company shall not make any public announcement or statement concerning the Agreement other than that which the Company is required to disclose on Form 8-K and other required filings with the Securities and Exchange Commission. Consistent with its obligations under the securities laws, the Company is required to seek confidential treatment of the information set forth in the Annex and Exhibits to the SPA.

As a condition precedent to entering into the FEI/DTE Stock Purchase Agreement, the Company was required to enter into (i) forbearance agreements with certain of its major creditors and debtors (“Certain Creditors”) (“Forbearance Agreements”), (ii) the Second Amendment to Employment Agreement with Mr. Blackstone, Vice President and Chief Accounting Officer (“Blackstone Agreement”) and (iii) the First Amendment to Employment Agreement with Mr. Novinskie, President and Chief Financial Officer (“Novinskie Agreement”). The Forbearance Agreements provide for the Certain Creditors to agree to forbear from making a demand on the Company for payment of their debt for a period of two years from the date of the SPA. The Certain Creditors, Blackstone and/or Novinskie are entitled to receive accelerated payment of their debt should the Company, among other things, (i) have net income, (ii) sell equity securities, (iii) sell assets in excess of stated amounts and/or (iv) if the Company permits an Event of Default (as defined in the respective agreements) (“Accelerated Payments”). See notes 6, 7 and 11 of the notes to Consolidated Financial Statements for discussions regarding the Forbearance Agreements, the Blackstone Agreement and the Novinskie Agreements. At September 30, 2013, the Company is not required to make Accelerated Payments to the Certain Creditors, Blackstone or Novinskie.

	48

DALECO RESOURCES CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED SEPTEMBER 30, 2013 AND 2012

The SPA contains provisions that restrict the use of the $1.5 million received by the Company as follows:

	Initial		Restricted cash at
	Restriction		September 30,
	per the SPA		2013
Forbearance Agreements, Novinskie Agreement and Blackstone Agreement	$	350,000	$	15,000
Marketing Agreement payments to FEI		120,000		60,000
Other marketing and sales activities		360,000		283,730
Transaction closing costs and related		80,000		3,383
Oil and gas properties activities		75,000		23,000
Mineral properties activities		50,000		35,000
Future general and administrative expenses		345,000		225,650
Other costs and expenses		120,000		48,045
Total	$	1,500,000	$	693,808

2013 Private Placement

Certain Debt and Other Obligations

Such defaulted obligations at September 30, 2013 include the following:

Amounts included in accounts payable:
Consulting services and interest due a licensor	$	19,009
EV&T – fees, expenses and accrued interest (subject to forbearance agreement)		213,040
CAMI notes payable and accrued interest:
Subject to forbearance agreements		830,534
Not subject to forbearance agreements		32,171
EV&T note and interest (subject to forbearance agreement)		1,202,318
Note payable to related party and interest thereon (subject to forbearance agreement)		69,587
7.25% Convertible Debentures and interest due a related party (subject to forbearance agreement)		46,689
Note payable to former related party and interest thereon (subject to forbearance agreement)		19,949
Amounts included in accrued compensation expense:
Subject to forbearance agreements		597,009
Not subject to forbearance agreements		94,791
Total	$	3,125,097

Liquidity

	49

DALECO RESOURCES CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED SEPTEMBER 30, 2013 AND 2012

At present, the Company does not have in place a credit facility or other line of credit upon which it may draw. As operating activities increase, the Company will evaluate the need for such a credit facility. For desired acquisitions or project enhancements, the Company must seek project specific financing. None of the Company’s properties are encumbered. See Note 4 regarding ZeoSure LLC.

In an effort to address the liquidity shortfall, the Company sold certain of its oil and gas properties in 2012, is selling certain of its oil and gas properties in fiscal 2014 (see Note 15) and is evaluating the sale of certain additional oil and gas properties. It may take months and possibly longer to sell these properties at a suitable price. The market is affected by many factors, such as general economic conditions, availability of financing, interest rates and other factors, including supply and demand that are beyond our control. We cannot predict whether we will be able to sell a property for the price or on terms acceptable to us or whether any price or other terms offered by a prospective purchaser would be acceptable to us. We cannot predict the length of time needed to find a willing purchaser and to close the sale of any property.

The Company has used and shall use the proceeds from the transaction with FEI and DTE in an effort to establish additional profitable revenue generating activities. The Company is implementing its plan and creating sales, marketing, and distribution programs. The Company has employed a Vice President of Sales and intends to use internal and external resources to focus on mineral sales. In anticipation of increased sales, the Company’s plans include handling, storage and transportation modifications for the mineral properties. Also, the Company plans to continue its workover operations and other activities in certain of its Texas and West Virginia oil and gas properties to enhance its existing revenue stream and profitability.

2.	BASIS OF PRESENTATION

Description of Business

Daleco Resources Corporation (“DRC”) is a Nevada corporation (organized in Nevada during 2002). DRC’s Articles provide for, among other things, authorized capital stock of 150 million shares of common stock and 20 million shares of preferred stock. During June 2013, DRC’s authorized shares of common stock were increased to 150 million shares from 100 million shares. DRC and its consolidated subsidiaries are referred to as the “Company”. The Company's segments consist of two separate categories: oil and natural gas and non-metallic minerals. DRC is a holding company whose subsidiaries are engaged in: (i) the exploration, development and production of oil and gas; (ii) the exploration for naturally occurring minerals; (iii) the marketing and sales of such minerals; and (iv) the marketing and sales of products utilizing such minerals. DRC’s wholly-owned subsidiaries include Westlands Resources Corporation (“WRC”), Deven Resources, Inc. (“DRI”), DRI Operating Company, Inc. (“DRIOP”), Tri-Coastal Energy, Inc. (“TCEI”), Clean Age Minerals, Inc. (“CAMI”), CA Properties, Inc. (“CAPI”), International Aggregation and Trading Company, LLC (IATC”), Sustainable Forest Industries, Inc. (“SFI”) and The Natural Resources Exchange, Inc. (“NREX”).

IATC, TCEI, SFI and NREX are inactive.

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DALECO RESOURCES CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED SEPTEMBER 30, 2013 AND 2012

As of September 30, 2013, the Company owned working interests in 28 wells in Texas and West Virginia. Throughout 2013, the Company has experienced an average increase of 3% in the unit of production weighted average sales price it received for its oil and natural gas products as compared to 2012.

CAMI, through its wholly-owned subsidiary, CAPI (collectively “CAM”), owns a fee title interest, leasehold interest and Federal Placer and Lode mining claims containing non-metallic and other minerals in Texas, New Mexico and Utah. CAM is presently engaged in the exploration for such minerals. CAM intends to mine the minerals through the use of contract miners and arrangements with its joint venture partner.

The Company is primarily engaged in oil and gas operations and non-metallic minerals activities.

We follow accounting standards set by the Financial Accounting Standard Board, commonly referred to as “FASB”. The FASB sets generally accepted accounting principles (“GAAP”) that we follow to ensure we consistently report our consolidated financial position, results of operations, and cash flows. References to GAAP issued by the FASB in these footnotes are to the FASB Accounting Standards Codification, sometimes referred to as the “Codification” or “ASC”. From time to time, the FASB may issue an Accounting Standards Update (“ASU”) which may impact the consolidated financial statements and disclosures therein (see “Recent Accounting Pronouncements”).

Use of Estimates

The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosures of contingencies at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from these estimates.

Significant estimates made in preparing these consolidated financial statements include, among other things, estimates of the proved oil and natural gas reserve volumes used in calculating depletion, depreciation and amortization expense (“DD&A”); the estimated future cash flows and fair value of properties used in determining the need for any impairment write-down; volumes and prices for revenues accrued; estimates of the fair value of equity-based compensation awards; deferred tax valuation and the timing and amount of future abandonment costs used in calculating asset retirement obligations. Future changes in the assumptions used could have a significant impact on reported results in future periods. The significant estimates are based on current assumptions that may be materially affected by changes to future economic conditions such as the market prices received for sales of volumes of oil and natural gas, interest rates and our ability to generate future income.

Basis of Consolidation

The consolidated financial statements have been prepared in accordance with generally accepted accounting principles and include the accounts of DRC and its wholly-owned subsidiaries. The Company’s investments in oil and gas leases are accounted for using proportionate consolidation whereby the Company’s pro rata share of each of the assets, liabilities, revenues and expenses of the investments are aggregated with those of the Company in its consolidated financial statements. The Company’s investments in minerals are accounted for using purchase accounting methods.

Certain reclassifications have been made to prior period consolidated financial statements to conform to the current presentation.

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DALECO RESOURCES CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED SEPTEMBER 30, 2013 AND 2012

Cash and Restricted Cash Deposits

Cash totals $140,607 and $190,738 at September 30, 2013 and 2012, respectively.

Restricted cash deposits - operations totaling $109,681 and $109,609 at September 30, 2013 and 2012, respectively, are classified as other assets in the accompanying balance sheets as they support financial assurance requirements for the Company’s operations of its mineral properties and its oil and gas properties in certain states as follows:

	2013		2012
Texas and West Virginia oil and gas operations bonding requirements	$	60,012	$	60,010
New Mexico minerals operations bonding requirements	$	49,669	$	49,599

Restricted cash deposits – equity issuances total $693,808 as of September 30, 2013 as discussed in Note 1.

Accounts Receivable

Our trade accounts receivable, which are primarily from oil and natural gas sales and joint interest billings, are recorded at the invoiced amount and include production receivables. The production receivables are valued at the invoiced amounts and do not bear interest. Accounts receivable also include joint interest billing receivables which represent billings to the non-operators associated with the drilling and operation of wells and are based on those owners’ working interests in the wells. We have assessed the financial strength of our customers and joint owners and determined that an allowance of $25,000 for estimated uncollectible amounts was necessary at September 30, 2013 and 2012.

Subscriptions Receivable and Interest Receivable

As of September 30, 2013, management of the Company believes that the collection of the principal balance of and interest due pursuant to a certain note receivable is in doubt (see Note 11). As of September 30, 2012, the Company changed to the recovery method in accounting for the notes receivable and interest thereon. Accordingly, the principal and interest will be recorded when, and if, collected. This change to the recovery method resulted in the recognition of $207,025 as an impairment of the interest receivable at September 30, 2012. The principal balance of the notes receivable ($576,000) was previously reflected as subscriptions receivable. Additional paid-in capital was reduced by $576,000 as of September 30, 2012, to reflect the impairment of the notes receivable.

Inventory

At September 30, 2013, we have $40,500 of inventory relating to our minerals activities. During September 2013, the company produced saleable minerals from its zeolite mineral deposit in Texas and shipped the material to a processing and fulfillment facility in Pennsylvania. Such inventory is recorded at the lower of average cost or market. Sales of the processed and unprocessed product to identified customers commenced in October 2013. We had no inventory at September 30, 2012, relating to our minerals activities.

We have no inventory at September 30, 2013 or 2012 relating to our oil and gas activities.

Prepaid Consulting Services Agreements Fees

Consulting Services Agreement

The Company issued 2,400,000 shares in connection with the Consulting Services Agreement with the Musser Group during 2011 which has been extended to February 2014. The shares of common stock issued to individuals associated with the Musser Group were valued at $360,000, the market price at time of issuance ($0.15 per share). Also, the Company issued to individuals associated with the Musser Group warrants for the purchase of 2,500,000 shares of Common Stock at an exercise price of $0.15 per share. The warrants may not be exercised unless and until the average bid and asking closing price of the Company’s Common Stock exceeds $1.00 per share for a period of thirty consecutive trading days. The warrants are exercisable through February 24, 2016. The fair value of the warrants was determined to be $375,153 using the Black-Scholes valuation model and the following assumptions: a contractual term of 5 years, risk free interest rate of 2.16%, dividend yields of 0%, and volatility of 163%. The Company filed a registration statement under the Securities Act of 1933 on Form S-8 for the shares of Common Stock issued to individuals associated with the Musser Group. The total fair value of the shares of Common Stock and the warrants issued individuals associated with to the Musser Group amounted to $735,153 and such amount was recorded as prepaid consulting fees.

Investor Relations Firm Consulting Agreement

In March 2013, the Company engaged an investor relations firm (“IR Firm”) to assist management in such activities for one year. The Company issued 600,000 shares (valued at $0.11 per share) of Common Stock to the IR Firm and such contract requires monthly payments of cash of $5,000 during the term of the agreement. The Company is amortizing the prepaid consulting fees of $66,000, the value of the shares, over the term of the contract with the IR Firm and unamortized consulting fees total $30,559 at September 30, 2013.

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DALECO RESOURCES CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED SEPTEMBER 30, 2013 AND 2012

The prepaid consulting fees are being amortized over the lives (initial terms) of the respective agreements. At September 30, 2013 and 2012, prepaid consulting services agreement fees totaled $30,559 and $151,237, respectively, and was classified as a current asset. Amortization of $186,678 and $366,575, respectively, is included in general and administrative expenses during 2013 and 2012.

Intangible Assets

The Company follows FASB issued authoritative guidance for recording intangible assets, including prepaid mineral royalties, which discontinues the amortization of identifiable intangible assets that have indefinite lives. In accordance with FASB issued authoritative guidance, these identifiable intangible assets that have indefinite lives are tested for impairment on an annual basis, or whenever events or changes in circumstances indicate that the carrying amount of the intangible asset may not be recoverable. Should we determine that such carrying amounts are greater than the estimated future benefit of the expected production from the mineral properties, we consider the asset to be impaired. The impairment to be recognized is measured by the amount that the carrying amount of an asset group exceeds the fair value of such asset group.

Prepaid Mineral Royalties

The Company receives a credit in the nature of prepaid mineral royalties for advance royalties paid on the Texas zeolite lease located in Presidio County, Texas. At September 30, 2013 and 2012, recoupable mineral royalties were $539,237 and $509,254, respectively. At September 30, 2012, such amount of prepaid mineral royalties is classified as an Other Asset in the accompanying Consolidated Balance Sheets. No portion was classified as a current asset as the Company’s agreements concerning sales of such mineral do not have any minimum supply requirements (as discussed in Note 8). As part of our annual impairment test as of September 30, 2013, and in connection with the Company entering the production phase of its Texas Zeolite minerals in the fourth quarter of fiscal 2013, we assessed the estimated future benefit of the royalty advances paid. This assessment was based on the expected production from the mineral properties. Although we are optimistic about the future cash flow of our mineral properties, the future results from our sales efforts and market growth cannot be assured. Based upon this information, we have determined that we are uncertain when we will be able to realize the prepaid mineral royalties at September 30, 2013, and that these assets may not be recoverable through future operations; therefore, we recognized an impairment expense of $539,237 in 2013.

Patent Rights and Patent License Rights

At September 30, 2013, the intangible assets consisted of patent rights of $6,620. The patent rights will be amortized over the life of such patents commencing in fiscal 2014.

The patent license rights were amortized over the initial term of the agreement. Such initial term expired in 2013. See Note 5.

Mineral Properties and Reserves

The Company has not produced large-scale quantities of any of its mineral deposits. During September 2013, the company produced saleable minerals from its zeolite mineral deposit in Texas (“Texas Zeolite”). The Company is in the production phase of its Texas Zeolite as saleable minerals have been extracted (produced) from such mineral deposit. By definition, the Company is in the Development Stage in respect to its Texas Zeolite and is in the Exploration Stage in respect to its Sierra Kaolin mineral holdings in New Mexico (“Sierra Kaolin”) and its zeolite mineral holdings in Utah (“Utah Zeolite”). As such, no proved reserves are estimated. At September 30, 2013 and 2012, net mineral properties were $9,782,128. The Company previously amortized its mineral properties at a nominal amortization rate as the Company has not produced commercial quantities of any of its mineral deposits. Once the Company produces commercial quantities of any of its mineral deposits, we will use the unit-of-production method in calculating cost depletion.

We recorded the acquisition of Clean Age Minerals, Inc., and associated minerals rights on September 19, 2000, at cost as based on the stated value of the Series B Preferred Stock issued which was less than the appraised value of the entity acquired.

Oil and Natural Gas Property - Depreciation, Depletion and Amortization (“DD&A”)

We account for natural gas and oil exploration and production activities under the successful efforts method of accounting. Proved developed natural gas and oil property acquisition costs are capitalized when incurred. Unproved properties with individually significant acquisition costs are assessed periodically on a property-by- property basis, and any impairment in value is recognized. If the unproved properties are determined to be productive, the appropriate related costs are transferred to proved natural gas and oil properties. Natural gas and oil exploration costs, other than the costs of drilling exploratory wells, are charged to expense as incurred. The costs of drilling exploratory wells are capitalized pending determination of whether they have discovered proved commercial reserves. If proved commercial reserves are not discovered, such drilling costs are expensed. Costs to develop proved reserves, including the costs of all development well and related equipment used in the production of natural gas and oil, are capitalized.

DD&A is calculated using the unit-of-production method on estimated proved oil and gas reserves at the field, lease, unit or well level. In arriving at rates under the unit-of-production method, the quantities of recoverable oil and natural gas are established based on estimates made by our independent engineers. We periodically review estimated proved reserve estimates and make changes as needed to DD&A expenses to account for new wells drilled, acquisitions, divestitures and other events which may have caused significant changes in our estimated proved developed producing reserves. The costs of unproved properties are withheld from the depletion base until such time as they are either developed or abandoned. When proved reserves are assigned, the cost of the property is added to costs subject to depletion calculations. Non-producing properties consist of undeveloped leasehold costs and costs associated with the purchase of certain proved undeveloped reserves. Undeveloped leasehold cost is allocated to the associated producing properties as the undeveloped acreage is developed. Individually significant non-producing properties are periodically assessed for impairment of value. Service properties, equipment and other assets are depreciated using the straight-line method over their estimated useful lives of three to 30 years.

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DALECO RESOURCES CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED SEPTEMBER 30, 2013 AND 2012

When circumstances indicate that an asset may be impaired, we compare expected undiscounted future cash flows at a producing field to the unamortized capitalized cost of the asset. If the future undiscounted cash flows, based on our estimate of future natural gas and oil prices, operating costs, anticipated production from proved reserves and other relevant data, are lower than the unamortized capitalized cost, the capitalized cost is reduced to fair value. Fair value is calculated by discounting the future cash flows at an appropriate risk-adjusted discount rate. When evaluating our unproved oil and gas properties, we utilize active market prices for similar acreage to use as a comparison tool against the carrying value of our properties. If the active market prices for similar acreage do not support our carrying values we then utilize estimates of future value that will be created from the future development of these properties. If future estimated fair value of these properties is lower than the capitalized cost, the capitalized cost is reduced to the estimated future fair value.

Expenditures for repairs and maintenance to sustain production from the existing producing reservoirs are charged to expense as incurred. Expenditures to recomplete a current well in a different unproved reservoir are capitalized pending determination that economic reserves have been added. If the recompletion is not successful, the expenditures are charged to expense.

Significant tangible equipment added or replaced that extends the useful or productive life of the property is capitalized. Expenditures to construct facilities or increase the productive capacity from existing reservoirs are capitalized.

Upon the sale or retirement of a proved natural gas or oil property, or an entire interest in unproved leaseholds, the cost and related accumulated DD&A are removed from the property accounts and the resulting gain or loss is recognized. For sales of a partial interest in unproved leaseholds for cash or cash equivalents, sales proceeds are first applied as a reduction of the original cost of the entire interest in the property and any remaining proceeds are recognized as a gain.

Natural Gas and Oil Reserve Quantities

Our estimate of proved reserves is based on the quantities of oil and natural gas that engineering and geological analyses demonstrate, with reasonable certainty, to be recoverable from established reservoirs in the future under current operating and economic parameters. For the years ended September 30, 2013 and 2012, Hall Energy, Inc. (“HEI”) prepared a consolidated reserve and economic evaluation of our proved oil and gas reserves. The preparation of our proved reserve estimates are completed in accordance with our internal control procedures, which include the verification of input data used by HEI, as well as management review and approval. Reserves and their relation to estimated future net cash flows impact our depletion and impairment calculations. As a result, adjustments to depletion and impairment are made concurrently with changes to reserve estimates. Estimates of our crude oil and natural gas reserves, and the projected cash flows derived from these reserve estimates, are prepared by HEI in accordance with guidelines established by the SEC, including the rule revisions designed to modernize the oil and gas company reserves reporting requirements and which we adopted effective September 30, 2010. The independent reserve engineer estimates reserves annually on September 30. This annual estimate results in a new DD&A rate, which we use for the preceding fourth quarter after adjusting for fourth quarter production.

Office Equipment, Furniture and Fixtures

Office Equipment, Furniture and Fixtures are recorded at cost and depreciated using the straight-line method over a period of three to seven years.

Impairment of Long-Lived Assets

Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Recoverability of assets to be held and used is measured by comparison of the carrying amount of an asset to future net cash flows expected to be generated by the asset. If such assets are considered to be impaired, the impairment to be recognized is measured by the amount that the carrying amount of the assets exceeds the fair value of the assets. At September 30, 2013 and 2012, we assessed the recovery of our long-lived assets, including our minerals properties and we determined that the carrying amount of each of the asset groups of mineral properties did not exceed the estimated future net cash flows expected to be generated by each respective asset group.

Long-Lived Assets to be Disposed Of

Assets to be disposed of are reported at the lower of the carrying amount or fair value less costs to sell. The oil and gas leasehold rights subject to a purchase and sale agreement dated October 6, 2013 (see Note 15), have no carrying amount in the accompanying Consolidated Balance Sheets as of September 30, 2013 and 2012.

Environmental Remediation

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DALECO RESOURCES CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED SEPTEMBER 30, 2013 AND 2012

Capital Leases

As of September 30, 2013, we had no capital leases. As a lessee, we determine if a lease is a capital lease if it meets one of four of the following criteria:

	•	The ownership of the leased property transfers to us by the end of the lease term, or shortly thereafter, in exchange for the payment of a nominal fee.
	•	The lease contains a bargain purchase option.
	•	The lease term is equal to 75% or more of the estimated economic life of the leased property.
	•	The present value at the beginning of the lease term of the minimum lease payments, excluding that portion of the payments representing executor costs such as insurance, maintenance, and taxes to be paid by the lessor, including any profit thereon, equals or exceeds 90% of the excess of the fair value of the leased property to the lessor at the lease inception over any related investment tax credit retained by the lessor and expected to be realized by the lessor.

Asset Retirement Obligation

Fair Value Measurements

The Company’s only financial instruments are cash, short-term trade receivables, payables and debt. The carrying amounts reported in the accompanying consolidated financial statements for cash, short-term trade receivables, payables and debt approximate fair values because of the immediate nature of short-term maturities of these financial instruments. The Company has no long-term or short-term bank debt outstanding at September 30, 2013.

Revenue Recognition

Oil and Gas Sales

Oil and natural gas revenue is recognized when the oil or natural gas is delivered to or collected by the respective purchaser, a sales agreement exists, collection for amounts billed is reasonably assured and the sales price is fixed or determinable. Title to the produced quantities transfers to the purchaser at the time the purchaser collects or receives the products. In the case of oil sales, title is transferred to the purchaser when the oil leaves the stock tanks and enters the purchaser’s trucks. In the case of gas production, title is transferred when the gas passes through the meter of the purchaser. It is the measurement of the purchaser that determines the amount of oil or gas purchased (although there are provisions for challenging these measurements if the Company believes the measurements are incorrect). Prices for such production are defined in sales contracts and may be based on certain publicly available indices. The purchasers of such production have historically made payment for oil and natural gas purchases within 30-60 days of the end of each production month. The Company periodically reviews the difference between the date of production and the date the Company collects payment for such production to ensure that receivables from those purchasers are collectible. The point of sale for the oil and natural gas production is at its applicable measurement facility; generally, the Company does not incur transportation costs related to our sales of oil and natural gas production. The Company does not currently participate in any gas-balancing arrangements. The Company does not recognize revenue for oil production held in stock tanks before delivery to the purchaser.

To the extent actual quantities and values of oil and natural gas are unavailable for a given reporting period because of timing or information not received from third parties, the expected sales volumes and price for those properties are estimated and recorded as Accounts Receivable in the accompanying consolidated financial statements.

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DALECO RESOURCES CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED SEPTEMBER 30, 2013 AND 2012

Well Management Revenue

The amounts which may be charged by the Company for well management are set forth in the joint operating agreements governing the wells operated by the Company. Such well management fees consist of monthly operating charges as well as fees related to certain maintenance and capital improvements charged by the Company as operator of the applicable properties. Revenue is recognized when such fees are earned pursuant to the terms of such underlying agreements and collection for amounts billed is reasonably assured.

Mineral Sales

Mineral sales revenue is recognized when the mineral is delivered to or collected by the respective purchaser, a sales agreement exists, collection for amounts billed is reasonably assured and the sales price is fixed or determinable. Title to the product transfers to the purchaser at the time the purchaser collects or receives the products.

Income Taxes

We provide for income taxes using the asset and liability method of accounting for income taxes. Under the asset and liability method, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and operating loss and tax credit carry-forwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date. We evaluate our tax positions in a two-step process. The first step is to determine whether it is more likely than not that a tax position will be sustained upon examination. The second step is a measurement process whereby a tax position that meets the more-likely-than-not threshold is calculated to determine the amount of benefit to recognize in the consolidated financial statements. See Note 10.

Stock-based Compensation

We account for all stock-based compensation (options) in accordance with FASB ASC 718. Under ASC 718, the fair value of stock options and compensation costs are measured as of the grant date. Under ASC 718, stock-based awards granted prior to its adoption will be expensed over the remaining portion of their vesting period. We amortize stock-based compensation expense on a straight-line basis over the requisite vesting period, which generally ranges from one to five years.

ASC 718 requires forfeitures to be estimated at the time of grant and revised, if necessary, in subsequent periods if actual forfeitures differ from initial estimates. Stock-based compensation expense has been recorded for 2013 and 2012 such that expense was recorded only for those stock-based awards that are expected to vest. Options granted to non-employees are recognized in these consolidated financial statements as compensation expense (See Note 9) using the Black-Scholes option-pricing model.

Comprehensive Loss

Summary of items of comprehensive loss for fiscal 2013 and 2012 are as follows:

		2013			2012
Net loss (comprehensive loss)		$	(2,024,509)		$	(772,579)

During March 2012, management of the Company concluded that the securities available for future sale were permanently impaired and accordingly $5,699 was recognized as impairment of securities available for future sale in the accompanying consolidated statement of operations and is reflected in net loss for 2012. See Note 5.

Net Income (Loss) Per Share

Net income (loss) per share is computed in accordance with FASB ASC Topic 260, "Earnings per Share". Basic net income (loss) per share is calculated by dividing the net income (loss) available to common stockholders by the weighted average number of shares outstanding during the year. Diluted earnings per share reflect the potential dilution of securities that could share in earnings of an entity. In a loss year, dilutive common equivalent shares are excluded from the loss per share calculation as the effect would be antidilutive.

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DALECO RESOURCES CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED SEPTEMBER 30, 2013 AND 2012

At September 30, 2013 and 2012, options and warrants to purchase 26,144,000 and 5,250,000 shares of common stock, respectively, were outstanding. Such shares were not included in the computation of diluted earnings per share because such shares subject to options and warrants would have an antidilutive effect on net loss per share. The 321,429 shares of Common Stock issuable upon the conversion of the 7.25% Convertible Debentures (see Note 6) at September 30, 2013 and 2012 have not been included in the computation of diluted earnings per share because such shares would have an anti-dilutive effect on net loss per share. The 1,071,937 shares of Common Stock issuable upon the conversion of the Convertible Note Payable as of September 30, 2012 (see Note 6) have not been included in the computation of diluted earnings per share because such shares would have an anti-dilutive effect on net loss per share and because the price at which such shares are convertible was in excess of the market price of the Common Stock at September 30, 2012. The 1,080,000 shares of Common Stock issuable upon the conversion of the Series B 8% Cumulative Convertible Preferred Stock as of September 30, 2013 and 2012 (see Note 9), have not been included in the computation of diluted earnings per share because the price ($1.25) at which such shares are convertible was in excess of the market price of the Common Stock at such date. No other adjustments were made for purposes of per share calculations.

Concentrations of Credit Risk

At times during the fiscal years ended September 30, 2013 and 2012, the cash balance exceeded the Federal Deposit Insurance Corporation’s limit of $250,000. There were no losses incurred due to such concentrations.

During the fiscal years ended September 30, 2013 and 2012, the Company did not use derivative instruments to hedge exposure to changes in commodity prices.

The Company also depends on a relatively small number of purchasers for a substantial portion of our revenue. At September 30, 2013, accounts receivable includes approximately $225,399 of joint interest billings and production receivables due primarily from four customers – ETC Texas Pipeline, Ltd., GulfMark Energy, Inc., Sheridan Production Company LLC and Volunteer Energy Services, Inc.

Recent Accounting Pronouncements

In July 2013, the FASB issued ASU 2013-11, Income Taxes (Topic 740), Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists. The ASU’s main provision: An unrecognized tax benefit, or a portion of an unrecognized tax benefit, should be presented in the financial statements as a reduction to a deferred tax asset for a net operating loss carryforward, a similar tax loss, or a tax credit carryforward, except to the extent a net operating loss carryforward, a similar tax loss, or a tax credit carryforward is not available at the reporting date under the tax law of the applicable jurisdiction to settle any additional income taxes that would result from the disallowance of a tax position or the tax law of the applicable jurisdiction does not require the entity to use, and the entity does not intend to use, the deferred tax asset for such purpose, the unrecognized tax benefit should be presented in the financial statements as a liability and should not be combined with deferred tax assets. The assessment of whether a deferred tax asset is available is based on the unrecognized tax benefit and deferred tax asset that exist at the reporting date and should be made presuming disallowance of the tax position at the reporting date. The amendments in this ASU are effective for fiscal years, and interim periods within those years, beginning after December 15, 2013, and early adoption is permitted. Entities are permitted to provide the new disclosures retrospectively for all comparative periods. The Company is currently assessing the impact that the adoption may have on its consolidated financial statements.

In January 2013, the FASB issued ASU 2013-01, Balance Sheet (topic 210), Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities The ASU’s main provision: The amendments clarify that the scope of Update 2011-11 applies to derivatives accounted for in accordance with Topic 815, Derivatives and Hedging, including bifurcated embedded derivatives, repurchase agreements and reverse repurchase agreements, and securities borrowing and securities lending transactions that are either offset in accordance with Section 210-20-45 or Section 815-10-45 or subject to an enforceable master netting arrangement or similar agreement. The disclosure requirements are effective for annual reporting periods beginning on or after January 1, 2013, and interim periods within those annual periods. Entities are required to provide the new disclosures retrospectively for all comparative periods. The Company is currently assessing the impact that the adoption may have on its consolidated financial statements.

3.	OIL AND GAS PROPERTIES

Oil and Gas Properties at September 30:

	2013		2012
Proved oil and gas properties	$	4,471,590	$	4,471,590
Support equipment and facilities		-		-
Uncompleted wells, equipment and facilities		-		-
		4,471,590		4,471,590
Accumulated depletion, depreciation and amortization		(4,144,939)		(4,096,939)
Net Oil and Gas Properties	$	326,651	$	374,651

During 2013, the Company did not incur any property acquisition, exploration or development costs. During 2012, the Company (1) incurred $47,078 of acquisition costs of proved developed producing properties and (2) did not incur any exploration or development costs. The Company did not have any capitalized exploratory well costs at the beginning of 2012. All of the Company’s oil and gas activities are on-shore in the United States.

See Notes 13, 14 and 15 for more information regarding the Company’s oil and gas properties.

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DALECO RESOURCES CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED SEPTEMBER 30, 2013 AND 2012

Results of Operations for Oil and Gas Producing Activities for Fiscal 2013 and 2012:

	2013		2012
Revenues:
Oil and gas sales	$	404,225	$	373,443
Well management revenue		262,813		287,446
Royalty receipts		4,799		3,532
Total revenues		671,837		664,421
Expenses and other:
Lease operating expenses		237,661		182,027
Production and severance taxes		22,022		20,878
Depreciation, depletion, amortization and valuation provisions		48,000		60,000
Total Expenses		307,683		262,905
Revenues in excess of expenses		364,154		401,516
Provision for doubtful account - proceeds receivable from prior sale of oil and gas properties		-		(25,000)
Gain on sale of oil and gas properties		-		898,335
Results of operations before income tax expenses		364,154		1,274,851
Income tax expenses (1)		-		-
Results of operations from oil and gas producing activities (excluding corporate overhead and interest costs)	$	364,154	$	1,274,851

(1) The Company presently has approximately $24 million of loss carryforwards for Federal income tax purposes. Based on these loss carryforwards, no income tax expense is recognized for this segment.

Sale of Oil and Gas Property Leasehold Deep Rights

On January 20, 2012, the Company entered into a purchase and sale agreement (the “PSA”) pursuant to which the Company agreed to sell certain oil and natural gas leasehold deep rights in Pennsylvania for cash of $898,335, subject to adjustment as to any title defect that is not cured within the timeframe permitted by the PSA. The sale closed on March 28, 2012. The Company received $898,335 at the closing and recognized gain in the amount of proceeds received. The oil and natural gas leasehold deep rights that were sold were undeveloped, and as such not income-producing to the Company. There is no material relationship between the purchaser of the assets and the registrant or any of its affiliates, or any director or officer of the registrant, or any associate of any such director or officer. A provision of the Agreement requires that the Company shall not make any public announcement or statement concerning the Agreement other than that which the Company is required to disclose on Form 8-K and other filings with the Securities and Exchange Commission. Also see Note 15 for asset purchase and sale agreement entered into subsequent to September 30, 2013.

Customers

The Company’s customers who purchased in excess of five percent (5%) of the Company’s oil and gas during 2013 and 2012 are as follows:

	Percentage
Name of Purchaser	2013		2012
ETC Texas Pipeline, Ltd.	24	%	27	%
GulfMark Energy, Inc.	53	%	45	%
Sheridan Production Company LLC	13	%	16	%
Volunteer Energy Services, Inc.	7	%	10	%

Provision for Doubtful Accounts - Proceeds Receivable from Prior Sale of Oil and Gas Properties

As of September 30, 2013, management of the Company believes that the collection of a portion of a $50,000 receivable relating to the sale of certain oil and gas properties during 2008 is in doubt. The Company recognized a provision for doubtful accounts of $25,000 during 2012.

	58

DALECO RESOURCES CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED SEPTEMBER 30, 2013 AND 2012

4.	MINERAL PROPERTIES AND RESULTS OF OPERATIONS

Clean Age Minerals, Inc.

DRC acquired CAMI in September 2000. CAMI, through its wholly-owned subsidiary, CA Properties, Inc., a Nevada corporation, owns or has under long-term lease: (a) approximately 5,200 acres in Marfa, Presidio County, Texas, containing high grade zeolite; (b) twenty-five mining claims located in Sierra County, New Mexico, covering approximately 2,720 acres of kaolin; and (c) eleven zeolite mining claims covering approximately 220 acres located in Beaver County, Utah. The Company has not produced large-scale quantities of any of its mineral deposits. During 2013 and 2012, the Company continued extraction of minor quantities of its zeolite for use in testing and field trial applications of ReNuGen™ and for testing in air purification and soil decontamination. During September 2013, the company produced saleable minerals from its Texas Zeolite. The Company is in the production phase of its Texas Zeolite as saleable minerals have been extracted (produced) from such mineral deposit. By definition, the Company is in the Development Stage in respect to its Texas Zeolite and is in the Exploration Stage in respect to its Sierra Kaolin and Utah Zeolite. The Company’s ability to develop these mineral deposits is dependent on its success in bringing in strategic partners with experience or a demand for specific minerals and raising capital through third parties.

At September 30, 2013, we have $40,500 of inventory relating to our minerals activities. Such inventory is recorded at the lower of average cost or market. Sales of the processed and unprocessed product to identified customers commenced in October 2013. We had no inventory at September 30, 2012, relating to our minerals activities.

Minerals Properties and Equipment

At September 30:	2013		2012
Undeveloped lease costs	$	9,877,128	$	9,877,128
Mine development costs		-		-
		9,877,128		9,877,128
Accumulated, depreciation, depletion and amortization (see Note 2)		(95,000)		(95,000)
Net Mineral Properties	$	9,782,128	$	9,782,128

Results of Operations for Minerals Properties Activities for Fiscal 2013 and 2012:

	2013		2012
Mineral Sales	$	7,652	$	5,626
Operating and other expenses		(30,083)		(19,121)
Impairment of prepaid mineral royalties (see Note 2)		(539,237)		-
Depreciation, depletion, amortization and valuation provisions		(4,556)		(253,612)
		(566,224)		(267,107)
Income tax expenses (benefits) ⁽¹⁾		-		-
Results of operations from mineral properties activities (excluding corporate overhead and interest costs)	$	(566,224)	$	(267,107)

(1)

The Company presently has approximately $24 million of loss carryforwards for Federal income tax purposes. Based on these loss carryforwards, no income tax benefits are recognized for this segment.

The Company sells one of its CA Series Products under a tradename, ReNuGen™, which is used in wastewater treatment facilities. Shipment totaled six and five tons for 2013 and 2012, respectively.

The Company sells another of its CA Series Products under a tradename, CiteClean™, which is used in remediation activities. The Company shipped one ton during 2013.

Depreciation, depletion, amortization and valuation provisions include amortization of patent rights and patent license rights (see Note 5) of $4,556 and $253,612 for 2013 and 2012, respectively.

The Company previously amortized its mineral properties at a nominal amortization rate as the Company has not produced commercial quantities of any of its mineral deposits. Once the Company produces commercial quantities of any of its mineral deposits, the Company will use the unit-of-production method in calculating cost depletion.

In fiscal 2005, the Company entered into the Sierra Kaolin Operating Agreement with TPA covering the Company’s kaolin claims in Sierra County, New Mexico. In fiscal 2007, the Company entered into a Revised and Restated Agreement with TPA governing operations of the Sierra Kaolin claims. Under these agreements, TPA assumed the duties to mine, test and market the Company’s Sierra Kaolin. In December 2009, the proposed Sierra Kaolin Open Pit Clay Mine project cleared the regulatory review process and the project’s definitive USDA Forest Service Plan of Operations was approved. This will facilitate the project moving to the next phases, including site preparation for extraction operations and the continued evaluation of potential product specific marketing arrangements with certain third parties.

During fiscal 2010, the Company entered into an agreement to sell zeolite to be used in certain agricultural applications including but not limited to feed supplements and soil additives in a ten state area in the south-central part of the US. On August 10, 2012, the Company gave notice to the purchaser to terminate the agreement in October 2012 pursuant to the notice provision provided in the agreement. The Company is seeking alternatives for the sale of its zeolite to be used in agricultural applications. There were no shipments during fiscal 2013 and 2012.

DALECO RESOURCES CORP 10-K