UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

FORM 10-Q

 

(MARK ONE)

 

x

QUARTERLY REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

 

For the quarterly period ended August 31, 2015

 

o

TRANSITION REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

 

For the transition period from                           to

 

Commission file number 000-53520

 

DISCOVERY ENERGY CORP.

(Exact Name of Registrant as Specified in Its Charter)

 

Nevada	98-0507846
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

 

One Riverway Drive, Suite 1700, Houston, Texas 77056

(Address of principal executive offices)

 

713-840-6495

(Registrant’s telephone number

 

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

 

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

 

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

 

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

 

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

 

Indicate the number of shares outstanding of each of the issuer’s classes of common equity, as of the latest practicable date: 140,089,501 common shares as of September 30, 2015.

 

 

PART I - FINANCIAL INFORMATION

 

Item 1. Financial Statements.

Discovery Energy Corp.

Balance Sheets

(Unaudited)

 

		August 31,				February 28,
		2015				2015
Assets
Current Assets
Cash		$	20,887			$	859
Prepaid expenses			6,025				16,176
Total Current Assets			26,912				17,035
Oil and gas property – unproved (successful efforts method)			2,421,415				2,421,415
Total Assets		$	2,448,327			$	2,438,450
Liabilities and Stockholders’ Equity
Current Liabilities
Accounts payable and accrued liabilities		$	63,418			$	97,256
Accounts payable- related parties			117,071				134,299
Other liabilities			9,501				13,860
Promissory notes-related parties			86,600				143,600
Promissory notes			542,294				542,294
Total Current Liabilities			818,884				931,309
Stockholders' Equity
Preferred stock- 10,000,000 shares authorized, zero issued and outstanding			-				-
Common stock - 500,000,000 shares authorized, $0.001 par value – 140,006,167 and 139,239,500 shares issued and outstanding as of August 31, 2015 and February 28, 2015, respectively			140,089				139,239
Additional paid in capital			3,933,047				3,633,897
Accumulated deficit			(2,446,155	)			(2,259,311	)
Accumulated other comprehensive income (loss)			2,462				-6,684
Total Stockholders' Equity			1,629,443				1,507,141
Total Liabilities and Stockholders' Equity		$	2,448,327			$	2,438,450

 

The accompanying notes are an integral part of these unaudited interim financial statements.

 

 

Discovery Energy Corp.

Statements of Expenses and Other Comprehensive Income (Loss)

(Unaudited)

 

		Three				Three				Six				Six
		Months Ended				Months Ended				Months Ended				Months Ended
		August 31,				August 31,				August 31,				August 31,
		2015				2014				2015				2014
Expenses
General and administrative		$	17,868			$	29,571			$	43,484			$	47,088
Exploration costs			33,747				5,625				36,297				9,095
Professional fees			38,066				29,799				56,733				210,919
Rent			3,089				3,231				8,615				6,341
Travel			0				566				40,000				29,366
Total expenses			92,770				68,792				185,129				302,809
Other (Income) Expenses
Interest expense			5,270				4,308				10,613				9,403
Miscellaneous income			(9	)			(22	)			(25	)			(34	)
Foreign exchange loss/(gain)			(3,306	)			(5,129	)			(8,873	)			(1,518	)
Other (income) expenses			1,955				(843	)			1,715				7,851
Net loss		$	(94,725	)		$	(67,949	)		$	(186,844	)		$	(310,660	)
Comprehensive loss
Net loss			(94,725	)			(67,949	)			(186,844	)			(310,660	)
Foreign currency translation adjustments			(2,097	)			(100	)			9,146				(2,100	)
Total comprehensive loss		$	(96,822	)		$	(68,049	)		$	(177,698	)		$	(312,760	)
Net loss per share – basic and diluted		$	0.00			$	0.00			$	0.00			$	0.00
Weighted average number of shares outstanding- basic and diluted			139,975,732				138,667,994				139,872,109				138,667,994

 

The accompanying notes are an integral part of these unaudited interim financial statements.

 

 

Discovery Energy Corp.

Statements of Cash Flows

(Unaudited)

 

		Six Months Ended				Six Months Ended
		August 31, 2015				August 31, 2014
Cash flows used in operating activities
Net loss		$	(186,844	)		$	(310,660	)
Adjustments to reconcile net loss to net
Cash used in operating activities
Shares issued for services			-				99,520
Changes in assets and liabilities:
Prepaid expenses			10,151				9,545
Accounts payable – related party			(17,228	)			56,261
Interest payable			8,566				-
Accounts payable and accrued liabilities			(46,763	)			(22,036	)
Net cash used in operating activities			(232,118	)			(167,370	)
Cash flows from financing activities
Repayments on notes payable-related party			(64,000	)			-
Common stock issued			250,000				-
Stock subscription proceeds			50,000				55,000
Proceeds from notes payable-related party			7,000				112,200
Net cash flows from financing activities			243,000				167,200
Foreign exchange effect on cash			9,146				-
Change in cash during the period			20,028				(170	)
Cash beginning of the period			859				2,483
Cash end of the period		$	20,887			$	2,313

 

The accompanying notes are an integral part of these unaudited interim financial statements.

 

 

Discovery Energy Corp.

Notes to the Unaudited Financial Statements

 

1.          Nature of Operations and Basis of Presentation

 

The principal business of Discovery Energy, Inc. (the “Company”) is the proposed exploration and development of the 584,651 gross acres (the “Prospect”) in the State of South Australia covered by Petroleum Exploration License (PEL) 512 (the “License”). The Prospect involves a 100% working interest in the preceding acreage, which overlies portions of the Cooper and Eromanga basins. The Company has not presently determined whether the Prospect contains any crude oil and natural gas reserves that are economically recoverable. While the Company’s present focus is on the Prospect, the Company may consider the acquisition of other attractive oil and gas properties under the right circumstances.

 

In May 2012, the Company incorporated a wholly-owned Australian subsidiary, Discovery Energy SA Ltd. for purposes of acquiring the License.

 

The accompanying unaudited interim financial statements of the Company have been prepared in accordance with accounting principles generally accepted in the United States of America and the rules of the Securities and Exchange Commission, and should be read in conjunction with the audited financial statements and notes thereto contained in the Company’s February 28, 2014 Annual Report on Form 10-K filed with the SEC. In the opinion of management, all adjustments, consisting of normal recurring adjustments, necessary for a fair presentation of financial position and the results of operations for the interim periods presented have been reflected herein. The results of operations for interim periods are not necessarily indicative of the results to be expected for the full year. Notes to the financial statements, which would substantially duplicate the disclosure contained in the audited financial statements for the most recent fiscal year end February 28, 2015, as reported on Form 10-K, have been omitted.

 

2.         Going Concern

 

The accompanying financial statements have been prepared on a going concern basis, which implies the Company will continue to realize its assets and discharge its liabilities in the normal course of business. The Company has not generated revenues since inception and has never paid dividends and is unlikely to pay dividends or generate earnings in the immediate or foreseeable future. The continuation of the Company as a going concern is dependent upon the ability of the Company to obtain necessary equity or debt financing to continue operations, the successful development of the Prospect or one or more alternative oil and gas properties, and the attainment of profitable operations. As of August 31, 2015, the Company has not generated any revenues and has an accumulated loss of $2,446,155 since inception. These factors raise substantial doubt regarding the Company's ability to continue as a going concern. These financial statements do not include any adjustments to the recoverability and classification of recorded asset amounts and classification of liabilities that might be necessary should the Company be unable to continue as a going concern.

 

3.         Related Party Transactions

 

As of August 31 and February 28, 2015, the Company owed $117,071 and $134,299, respectively, to certain Company directors for reimbursement of expenses paid on behalf of the Company. In addition, as of August 31 and February 28, 2015, the Company owed $86,600 and $143,600, respectively, for promissory notes issued to various related parties. These amounts are unsecured, non-interest bearing and due on demand.

 

4.         Oil and Gas Properties

 

On May 19, 2014, the Company received notice from the Government of South Australia that it had issued certain modifications to the License and suspended the License for a period of six months. Under the amended License, the Company will be required to drill 7 exploratory wells rather than 12, as originally required. These required wells must now be drilled in years 3, 4, and 5 (2, 2, and 3 wells, respectively) giving the Company additional time to execute its work plan. The amount of required 2D seismic was also reduced to 100 kilometers (in year 3) from 250 kilometers (in year 2) but the total 3D seismic work guaranteed increased to 500 square kilometers from 400 square kilometers. However, the 3D seismic survey requirement is spread over years 2, 3 and 4 (100, 200 and 200 sq. km. respectively). The effect of the suspension was to move the end date of the four years remaining in the initial term of the License six months into the future. Hence, year 2 would end on April 27, 2015, year 3 on April 27, 2016, year 4 on April 27, 2017 and the fifth and final year of the initial term would end on April 27, 2018.

 

 

On February 15, 2015, the Company received notice from the government of South Australia that it had suspended the License for a further period of six months. The effect of the suspension was to move the end date of the four years remaining in the initial term of the License six months into the future. Hence, year 2 would end on October 25, 2015, year 3 on October 25, 2016, year 4 on October 25, 2017 and the fifth and final year of the initial term would end October 25, 2018.

 

On July 13, 2015, the Company received confirmation from the government of South Australian that the Company’s application for a further six-month suspension of the work commitment relating to the Petroleum Exploration License (PEL) 512 covering the Company’s 584,651-acre prospect in South Australia had been approved effective July 9, 2015.

 

As further extended, the Company’s remaining work commitments are due to be completed by April 27, 2019, as set out below:

 

	*	Year 2 ending April 27, 2016 - Conduct a new 3D seismic survey totaling at least 100 kilometers.
	*	Year 3 ending April 27, 2017 - Acquire new 2D seismic data totaling at least 100 kilometers, acquire 3D seismic data totaling at least 200 square kilometers and drill two wells.
	*	Year 4 ending April 27, 2018 - Acquire new 3D seismic data totaling at least 200 square kilometers and drill two wells.
	*	Year 5 ending April 27, 2019 - Drill three wells

 

The modification extends the time that the Company has to meet its commitments. If the Company is unable to honor this work commitment, the result could be a need for a further modification or amendment to the most recently approved, amended work plan, or the assignment of the License to Liberty Petroleum Corporation (“Liberty”) pursuant to the terms of the Novation Deed or its reversion to the South Australian Government. Liberty had previously assigned to the Company Liberty’s prospective rights to the License.

 

5.         Notes Payable

 

Two promissory notes were issued on October 26, 2012 to Liberty upon delivery of the License with aggregate principal amount of $650,000. The original terms of the note were:

 

(i)

One note in the original principal amount of $500,000 was originally due on April 26, 2013.

 

(ii)

The other note in the original principal amount of $150,000 was originally due on July 26, 2013.

 

(iii)

Both notes bear interest at a floating rate equal to the one month term LIBOR rate, plus an additional 3%.

 

These promissory notes had undergone a number of amendments, including extensions of the due dates. On September 26, 2013, these promissory notes were combined into a single consolidation promissory note (the “Consolidated Note”) in the original principal amount of $542,294, as some of the principal had been reduced and some interest had accrued. Effective June 2, 2015, the Consolidation Note was amended and extended to September 2, 2015 and if the Company makes prepayments in the aggregate amount of $250,000 prior to the new Initial Due Date, then the due date for the remainder of the principal amount of and accrued interest on the Consolidation Note would be extended until November 2, 2015.

 

On March 9, 2015, the Company entered into an unsecured corporate demand note with William Begley, a related party. The note was in the amount of $4,000, and repayment can be demanded, with 5-days notice, at any time after the passage of 20 business days from the date of the note. If no demand is made on the note, the note becomes due and payable in full on its first anniversary. The note is non-interest bearing.

 

On March 31, 2015, the Company repaid three unsecured corporate demand notes with Keith Spickelmier totaling $50,000. The notes were dated September 26, 2013, December 16, 2013, and January 8, 2014 for $7,500, $17,500, and $25,000, respectively.

 

On May 5, 2015, the Company entered into an amendment of a previous unsecured corporate demand note with related party, Keith Spickelmier. The note was in the amount of $3,100 and the maximum term was amended and extended to the second anniversary from the date of the note. None of the other provisions of the original notes were changed.

 

On June 9, 2015, the Company repaid an unsecured corporate demand note with William Begley totaling $2,000. The note was dated February 21, 2015.

 

 

On July 3, 2015, the Company repaid two unsecured corporate demand notes with William Begley totaling $12,000. The notes were dated December 17, 2014 and January 1, 2015 for $6,000 each.

 

On August 11, 2015, the Company entered into an unsecured corporate demand note with William Begley, a related party. The note was in the amount of $3,000, and repayment can be demanded, with 5-days notice, at any time after the passage of 20 business days from the date of the note. If no demand is made on the note, the note becomes due and payable in full on its first anniversary. The note is non-interest bearing.

 

6.         Common Stock

 

On March 20, 2015, the Company issued 666,667 shares at a price of $0.30.

 

On June 15, 2015, the board of directors approved a private placement of up to 3,000,000 Common Shares at a price of $0.50 per share.

 

On June 26, 2015, the Company received $50,000 from a private investor and subsequently issued 100,000 Common Shares at a price of $0.50 per share.

 

On August 25, 2015, the Company received $50,000 from a private investor. The related 83,334 Common Shares were issued on September 4, 2015 at a price of $0.60 per share.

 

7.         Subsequent Events

 

Effective September 2, 2015, the Company and Liberty Petroleum Corporation amended the Consolidaton Note so that the Initial Due Date will be January 5, 2016, and provided that if the Company makes prepayments in the aggregate amount of $250,000 prior to the new Initial Due Date of Janaury 5, 2016, then the due date for the remainder of the principal amount of and accrued interest on the Consolidation Note would be exteneded until March 2, 2016.

 

 

Item 2. Management’s Discussion and Analysis.

 

CAUTIONARY STATEMENT FOR FORWARD-LOOKING STATEMENTS

 

This Quarterly Report on Form 10-Q includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. We have based these forward-looking statements on our current expectations and projections about future events. These forward-looking statements are subject to known and unknown risks, uncertainties and assumptions about us that may cause our actual results, levels of activity, performance or achievements to be materially different from any future results, levels of activity, performance or achievements expressed or implied by such forward-looking statements. In some cases, you can identify forward-looking statements by terminology such as “may,” “should,” “could,” “would,” “expect,” “plan,” “anticipate,” “believe,” “estimate,” “continue,” or the negative of such terms or other similar expressions. Factors that might cause or contribute to such a discrepancy include, but are not limited to, those described in our other Securities and Exchange Commission filings. The following discussion should be read in conjunction with our Financial Statements and related Notes thereto included elsewhere in this report.

 

General

 

Our company, Discovery Energy Corp., was incorporated under the laws of the state of Nevada on May 24, 2006 under the name “Santos Resource Corp.” Our current business plan is to explore for and produce oil and gas from a tract of land (the “Prospect”) covered by Petroleum Exploration License (PEL) 512 (the “License”) in the State of South Australia. We adopted this business plan near the end of our fiscal 2012, after having previously abandoned our initial business plan involving mining claims in Quebec, Canada and after we had been dormant from a business perspective for a period of time. In connection with the adoption of our current business plan, we had a change in control of our company, a change in our management, a change in our corporate name, and a change of our status from a “shell” company, as that term is defined in Rule 405 of the Securities Act of 1933 and Rule 12b-2 under the Securities Exchange Act of 1934.

 

We made significant strides in our business plan during our fiscal 2013, including the formal grant of the License after the satisfaction of a number of significant preconditions. During our fiscal 2014, we focused our efforts on completing a major capital raising transaction or procuring one or more major joint venture partners to further our business plan. We continued these efforts throughout our fiscal 2015.

 

Beginning in the second quarter of fiscal 2015 a significant decline in the price of oil has affected the oil and gas industry worldwide. This decline began in June 2014 when the price of Brent oil was above US$110 per barrel and continued to a low of US$49 per barrel in January of 2015. Prices then recovered near upper US$60s per barrel in May 2015, only to decline about 24% to US$48.38/bbl on September 30, 2015. Current oil prices make our ability to complete a capital raising transaction or procure a joint venture partner more difficult. Although we believe that we will continue to be challenged by low oil prices for the near future, we are not currently in a position to determine the full extent of that impact. As a result of the decline in oil prices we have and are making changes to our ongoing business strategy to best position ourselves for when the markets improve.

 

Although we are continuing efforts to complete a major capital raising transaction, we are shifting our emphasis away from a single capital raising transaction that would meet our financial needs for an extended period of time. Our new emphasis will be on obtaining sufficient funds for us to complete the second year of our work commitment and positioning our company to exploit commercially the Prospect at the appropriate time in the future. This shift in strategy will minimize the dilution to shareholders and is partly due to depressed energy prices which presently do not justify efforts to produce hydrocarbons and that presently have made more difficult capital raising transactions under acceptable terms. Our strategy will be to optimally position our company to begin the development of the Prospect after energy prices have recovered sufficiently. Part of our positioning includes the following:

 

*

Efforts to procure purchase/off-take contracts for our hydrocarbons once we are in a production mode.

*

Efforts to procure one or more joint venture partners to undertake jointly 3D seismic surveys at reduced costs to all parties, which surveys will satisfy in part our License work commitment

*

Efforts to procure one or more joint venture partners that would drill wells on the Prospect, which wells will satisfy in part our License work commitment

*

Efforts to procure funds at a minimum or even an optimal level so that we are able to satisfy our financial obligations and at even greater levels so that we are able to pursue our business plan in the manner that we prefer

 

 

While we are guardedly optimistic that these efforts will be successful, we have no assurance of this.

 

Our fiscal 2015 did have several positive developments. One such development was a beneficial modification of our five-year work commitment, which now takes into account new technologies and developments in the Cooper Basin. We also received an extension of the work commitment relating to the License for a second time. The details of these developments are discussed herein. The modification and extension of the work commitment early in our fiscal 2015 reduced our obligations under the work commitment. The changes to and two extensions of the work commitment are allowing us additional time to pursue capital raising transactions or procure a major joint venture partner, and perhaps benefit from a recovery in the price of oil. Moreover, one benefit of lower oil and gas prices is that the costs of third party service providers (such as seismic firms and contract drillers) have declined significantly as well, creating a more favorable business environment when we are able to take advantage of it.

 

Even though we have not completed a major capital raise under acceptable/attractive terms, we still have regular and ongoing payments and expenditures. These payments and expenditures and non-payment consequences (which could be materially adverse to our interests) are discussed in detail herein. So far we have been successful in satisfying or deferring the most important of these payments and expenditures, and we expect to continue to do so in the future. However, while we have been successful in this regard to date, we have no assurance that we will continue to be successful in this regard in the future.

 

In the remainder of this Report, Australian dollar amounts are prefaced by “AU$” while United States dollar amounts are prefaced simply by “$” or (when used in close proximity to Australian dollar amounts) by “US$.” When United States dollar amounts are given as equivalents of Australian dollar amounts, such United States dollar amounts are approximations only and not exact figures. During the three months ended August 31, 2015, that exchange rate has varied from a low of US$1.00/AU$1.2822 to a high of US$1.00/AU$1.4057. On September 30, 2015 the rate stood at US$1.00/AU$1.4245.

 

Plan of Operation

 

General

 

We intend to engage primarily in the exploration and conventional development of oil and gas on the Prospect in an effort to develop oil and gas reserves, and related natural gas liquids and condensates. Our principal products will be crude oil and natural gas. Our development strategy will be directed in the multi-pay target areas of South Australia, with principal focus on the prolific Cooper/Eromanga Basin, towards initiating and rapidly expanding production rates and proving up significant reserves primarily through exploratory drilling. Our mission will be to generate superior returns for our stockholders by working with industry partners, suppliers and the community to build a focused exploration and production company with strong development assets in the oil and gas sector.

 

In the right circumstances, we might assume the entire risk of the drilling and development of the Prospect. More likely, we will determine that the drilling and development of the Prospect can be more effectively pursued by inviting industry participants to share the risk and the reward of the Prospect by financing some or all of the costs of drilling wells. Such arrangements are frequently referred to as “farm-outs.” In such cases, we may retain a carried working interest or a reversionary interest, and we may be required to finance all or a portion of our proportional interest in the Prospect. Although this approach will reduce our potential return should the drilling operations prove successful, it will also reduce our risk and financial commitment to a particular prospect. Prospective participants regarding possible “farm-out” arrangements have already approached us, and we continue to have discussions with some of these persons.

 

There can be no assurance that we will be successful in our exploratory and production activities. The oil and gas business involves numerous risks, the principal ones of which are listed in our 2015 Annual Report on Form 10-K in “Item 1A. Risk Factors -RISKS RELATING TO OUR INDUSTRY - PARTICIPANTS IN THE OIL AND GAS INDUSTRY ARE SUBJECT TO NUMEROUS RISKS.” As we become more involved in the oil and gas exploration and production business, we will give more detail information regarding these risks.

 

Although our primary focus is on the exploration and development of the Prospect, we have received information about, and have had discussion regarding possible acquisition of or participation in, other oil or gas opportunities. None of these discussions has led to any agreement in principle. Nevertheless, given an attractive opportunity and our ability to consummate the same, we could acquire one or more other crude oil and natural gas properties, or participant in one or more other crude oil and natural gas opportunities.

 

 

Proposed Initial Activities

 

We have just begun the initial phase of our plan of operation. To date we have not commenced any drilling or other exploration activities on the Prospect, and thus we do not have any estimates of oil and gas reserves. Consequently we have not reported any reserve estimates to any governmental authority. We cannot assure anyone that we will find commercially producible amounts of oil and gas. Moreover, at the present time, we cannot finance the initial phase of our plan of operation solely through our own current resources. Therefore, we have undertaken certain financing activities described in “Liquidity and Capital Requirements - Major Financing Efforts and Other Sources of Capital” below. The success of the initial phase of our plan of operation depends upon our ability to obtain additional capital to acquire seismic data with respect to the Prospect, and to drill exploratory and developmental wells. We cannot assure anyone that we will obtain the necessary capital.

 

The License is subject to a five-year work commitment. We have completed the first year of this work commitment and in this first year we conducted geological and geophysical studies including interpretation of existing seismic data. In management’s view, the geotechnical work completed in the first year was sufficient to satisfy this requirement, and we filed our report in this connection with the South Australian government. We have received no comments from the government relating to this report.

  

We received from the South Australian Minister for Mineral Resources and Energy three six-month extensions of the work commitment relating to the License, the first in May 2014, the second in February 2015 and the third in July 2015. The first of these extensions also reduced our obligations under the work commitment. In view of this reduction and these extensions, our remaining work commitment involves the following:

 

	*	Year 2 ending about April 27, 2016 - Conduct a new 3D seismic survey totaling at least 100 square kilometers.
	*	Year 3 ending about April 27, 2017 - Acquire new 2D seismic data totaling at least 100 kilometers, acquire 3D seismic data totaling at least 200 square kilometers and drill two wells
	*	Year 4 ending about April 27, 2018 - Acquire new 3D seismic data totaling at least 200 square kilometers and drill two wells
	*	Year 5 ending about April 27, 2019 - Drill three wells

 

Although our remaining work commitment has been reduced and extended, we have no assurance that we will be able to extend the work commitment again or to fulfill it timely, as we need to complete capital raising transactions, or procure a joint venture partner, or both, to do so.

 

The prices of the equipment and services that we must employ to fulfill the work commitment vary based on both local and international demand for such products by others involved in exploration for and production of oil and gas. Previous high worldwide energy prices had resulted in growing demand, which lent support to higher prices being charged by suppliers. Prices being charged by suppliers have declined with the decline in energy prices. Nevertheless, we have no assurance that the steps in the work plan (e.g. shooting 100 square kilometers of 3D seismic) can be accomplished at current or lower costs.

 

Based on our research and technical analysis to date, we believe that the License work plan can be justified. Hence, the initial phase of our plan of operation involves (among other things) conducting 3D seismic surveys totaling 300 square kilometers (approximately 116 sq. miles), conducting a 2D seismic survey of 100 kilometers (approximately 62 miles) and drilling of at least two exploration wells. This activity will take place on the south portion of the Prospect and meets the near-term work requirements under the License. Subject to the availability of funds plus proper equipment and personnel or a farm-out arrangement, management feels that US$15 million or more can be productively invested under the license as defined in the Year 2 and Year 3 work commitments.

 

We are seeking a joint venture partner, which might act as the operator to conduct seismic work and drill our wells. Our ability to accomplish this seemingly has been impaired by the recent dramatic decline in oil prices. If we are unable to procure such a partner and provided that we procure funds therefor, we intend to engage the services of a qualified seismic company to acquire additional 3D seismic data and (once we have identified proposed drilling sites) a third party contractor for drilling operations. Subject to necessary financing, management foresees no problem in procuring the services of one or more qualified operators and drillers in connection with the initial phase of our plan of operation. In all cases, the operator will be responsible for all regulatory compliance regarding the well, including any necessary permitting for the well. In addition to regulatory compliance, the operator will be responsible for hiring the drilling contractor, geologist and petroleum engineer to make final decisions relative to the zones to be targeted, well design, and bore-hole drilling and logging. Should the well be successful, the operator would thereafter be responsible for completing the well, installing production facilities and interconnecting with gathering or transmission pipelines if economically appropriate. We expect to pay third party operators (i.e. not joint venture partner with us) commercially prevailing rates.

 

 

The operator will be responsible for the well(s) once production has commenced. Additionally, the operator will formulate and deliver to all interest owners an operating agreement establishing each participant’s rights and obligations in that particular well based on the location of the well and the ownership. The operator will also be responsible for paying bills related to the well, billing working interest owners for their proportionate expenses in drilling and completing the well, and selling the production from the well. Unless each interest owner sells its production separately, the operator will collect sale proceeds from oil and gas purchasers, and, once a division order has been established and confirmed by the interest owners, the operator will issue the checks to each interest owner in accordance with its appropriate interest. The operator will not perform these functions when each interest owner sells its production separately, in which case the interest owners will undertake these activities separately. After production commences on a well, the operator also will be responsible for maintaining the well and the wellhead site during the entire term of the production or until such time as the operator has been replaced.

 

The principal oil, natural gas and gas liquids transportation hub for the region of South Australia surrounding the Prospect is located in the vicinity of Moomba. This processing and transportation center is approximately 60 km (36 miles) due east of the Prospect’s eastern boundary. Large diameter pipelines deliver oil and gas liquids from Moomba south to Port Bonython (Whyalla). Natural gas is also moved south to Adelaide or east to Sydney. A gas transmission pipeline also connects Moomba to Ballera, which is located northeastward in the State of Queensland. From Ballera gas can be moved to Brisbane and Gladstone, where several liquefied natural gas (LNG) projects are under development. The Moomba treating and transportation facilities and the southward pipelines were developed and are operated by a producer consortium led by Santos Limited (no relation to us).

 

We cannot accurately predict the costs of transporting our production until we locate our first successful well. The cost of installing infrastructure to deliver our production to Moomba or elsewhere will vary depending upon distance traversed, negotiated handling/treating fees, and pipeline tariffs.

 

Results of Operations

 

Our results of operation for the three- and six-month periods ended August 31, 2015 and 2014 are summarized in the table below:

 

		Three months Ended				Three months Ended				Six months Ended				Six months Ended
		August 31, 2015				August 31, 2014				August 31, 2015				August 31, 2014
Revenue		$	0			$	0			$	0			$	0
Operating Expenses		$	92,770			$	68,792			$	185,129			$	302,809
Other (income)/expenses		$	1,955			$	(843	)		$	1,715			$	7,851
Net Loss		$	(94,725	)		$	(67,949	)		$	(186,844	)		$	(310,660	)

 

Our operating expenses for the six-month periods ended August 31, 2015 and 2014 are outlined in the table below:

 

		Three months Ended				Three months Ended				Six months Ended				Six months Ended
		August 31, 2015				August 31, 2014				August 31, 2015				August 31, 2014
General and Administrative		$	17,868			$	29,571			$	43,484			$	47,088
Exploration Costs		$	33,747			$	5,625			$	36,297			$	9,095
Professional Fees		$	38,066			$	29,799			$	56,733			$	210,919
Rent		$	3,089			$	3,231			$	8,615			$	6,341
Travel		$	0			$	566			$	40,000			$	29,366
Total Operating Expenses		$	92,770			$	68,792			$	185,129			$	302,809

 

 

Results of Operations for the Three-Month Periods Ended August 31, 2015 and 2014

 

Revenues. We did not earn any revenues for either the quarter ended August 31, 2015 or the similar period in 2014. We do not anticipate earning revenues until such time as we have entered into commercial production of oil and natural gas. We are presently in the exploration stage of our business, and we can provide no assurance that we will discover commercially exploitable levels of hydrocarbons on our properties, or if such resources are discovered, that we will enter the commercial production.

 

Expenses. Total expenses incurred during the quarter ended August 31, 2015 were approximately 39% higher than those incurred during the quarter ended August 31, 2014. The increase of approximately $24,000 reflects greater exploration costs, and professional fees partially offset by lower general and administrative expenses. The bulk of our activities during the quarter ended August 31, 2015 were aimed at achieving an enhanced understanding of the License area’s technical potential and prospectivity. This work was in part a response to due diligence inquiries by a potential investor.

 

As noted above, the enhancement and extension of our technical database and analysis was a focus during the quarter ended August 31, 2015. As a result, exploration costs increased about $28,000 compared to the similar period in 2014. Improved analytics were achieved by, among other things, incorporating recently released 3D seismic and well completion data from operations adjacent to the License area into our technical database.

 

Professional fees for the quarter ended August 31, 2015 increased approximately $8,000, or 28% compared to the quarter ended August 31, 2014 due primarily to higher cost associated with meeting the financial reporting obligations of a company that reports to the U.S. Securities and Exchange Commission.

 

General and administrative expenses were about $11,700 lower during the quarter ended August 31, 2015 compared to the same period last fiscal year. This drop was almost entirely explained by reduced non-cash charges associated with the impact of currency fluctuations on assets held by our Australian subsidiary.

 

Net loss. Our net loss for the quarter ended August 31, 2015 increased by approximately $26,800 as compared to the quarter ended August 31, 2014. While various operating cost components moved up or down, as discussed above, the net increase in the loss is mostly attributable to higher exploration costs during the period ended August 31, 2015. On a per share basis, our losses for both the three-month periods ended August 31, 2015 and August 31, 2014 were less than $0.01

 

Results of Operations for the Six-Month Periods Ended August 31, 2015 and 2014

 

Revenues. We did not earn any revenues for either the six months ended August 31, 2015 or the similar period in 2014. We do not anticipate earning revenues until such time as we have entered into commercial production of oil and natural gas. We are presently in the exploration stage of our business, and we can provide no assurance that we will discover commercially exploitable levels of hydrocarbons on our properties, or if such resources are discovered, that we will enter into commercial production.

 

Expenses. The total expenses incurred during the six months ended August 31, 2015 were nearly $118,000 or 39% less than those incurred during the six months ended August 31, 2014. A substantial decline in professional fee payments was the primary reason for the decline. This drop was somewhat offset by increased exploration costs and travel costs and expenses. These changes reflect differences in the types of activities required to support and sustain our capital raising activities.

 

As noted above, the largest component of our reduced expenses was dramatically lower professional fees during six months ended August 31, 2015 compared to the same period ended August 31, 2014. The reduction reflects the lack of investment banking and financial advisory fee payments (third party fund raising assistance) during the most recent six-month period compared to the six-month period ended August 31, 2014. As a result, expenses in this category were less by about $154,000.

 

Our exploration costs during the six months ended August 31, 2015 increased by over $27,000 compared to the same period ended August 31, 2014. As noted above, this increase reflects work done to extend and enhance our technical database and understanding to, among other things respond to a potential investor’s due diligence inquiries.

 

Travel expenses during the six months ended August 31, 2015 were about 36% higher than for the six months ended August 31, 2014. The increase reflects the cost of an extended stay in Australia for face-to-face meetings with government officials, investment bankers and potential farm-in partners.

 

 

Rent payments were somewhat higher, and general and administrative expenses were somewhat lower in the six months ended August 31, 2015 compared to the six months ended August 31, 2014. The dollar amounts of these two variances were relatively small and, combined resulted in a net decrease in expenses of about $1,300 for the six months ended August 31, 2015 compared to the same period ended August 31, 2014.

 

Net loss. Our net loss for the six months ended August 31, 2015 was approximately 40% less than the loss recorded for the six months ended August 31, 2014. As noted above, this result was driven by lower professional fee payments, partially offset by higher exploration expenses. On a per share basis, our losses for both the six-month periods ended August 31, 2015 and August 31, 2014 were less than $0.01.

 

Off-Balance Sheet Arrangements

 

We have no off-balance sheet arrangements.

 

Liquidity and Capital Requirements

 

Financing History and Immediate, Short-Term Capital Needs

 

Since the change in our corporate direction in January 2012, we have financed our business primarily through private placements of common stock. Since January 2012 we conducted several rounds of financing in which we raised total “seed” capital in the amount of $2,703,750 resulting in the issuance of 19,557,501 shares of our common stock. These figures include the results-to-date of the current private placement discussed below. As of August 31, 2015, we had drawn $10,650 in funds against our bank credit card. From time to time, our officers and directors have advanced short-term funds. As of September 30, 2015, we had outstanding loans totaling $86,600 from two directors and an entity controlled by one officer. These loans are each evidenced by demand notes, which are non-interest bearing.

 

As of August 31, 2015, we had cash in the amount of $20,887, and we had a working capital deficit of about $792,000. As of September 30, 2015, we had the US dollar equivalent of approximately $9,120 of cash on hand. The bulk of the current working capital deficit is associated with the consolidation promissory note in the original principal amount of $542,294 made payable to Liberty Petroleum Corporation (“Liberty”). As extended, this consolidation promissory note is due and payable on or before January 5, 2016, provided that if we make prepayments in the aggregate amount of $250,000 prior to the due date, then the due date for the remainder of the principal amount of and accrued interest on the note would be extended until March 2, 2016.

 

Given the amount of cash on hand, we anticipate the need to raise an estimated $3.4 million of additional funds by end of April 2016 for operating expenses, retirement of the Liberty note and completion of the second year of our work commitment. We intend to try to do this by common stock private placements to individual and institutional investors. We have no assurances that we will be successful in raising required additional funds. If we are unable to raise the required additional funds in the immediate future, we will need (among other things) to seek a further extension of the Liberty note and our work commitment under the License. While Liberty and the related governmental authorities have accommodated us in the past in this regard, we have no assurance that they would accommodate us again. Our inability to raise required additional funds and our subsequent failure to obtain an extension of the Liberty note and our work commitment under the License could have adverse consequences for us, including our inability to continue our business plan, which could result in a complete loss of stockholders’ equity.

 

Long-Term Capital Needs

 

The five-year work commitment relating to the License imposes certain financial obligations on us. In management’s view, the geotechnical work completed in year-one was sufficient to satisfy the requirement for year-one, and we filed our report in this connection with the South Australian government. We have received no comments from the government relating to this report. However, we will need to obtain additional financing above that discussed above before we can fully implement our current plan of operation. This includes monies to meet the second year requirements of the work commitment. This second year will end on April 27, 2016, though the South Australian has assured us that, if fieldwork has been initiated, time will be allowed to complete the seismic survey. Moreover, we expect to need a substantial amount of funds to develop the Prospect. In addition to the preceding, we will need working capital to satisfy our general and administrative expenses.

 

Between November 2015 and the end of April 2017, we estimate that at least $11.4 million of additional capital will be required to continue operations and satisfy our obligations for the third year of our work commitment. This amount will be needed before we are able to commence production on the Prospect. Accordingly, this amount must be raised. Moreover, this amount would not allow us to develop the Prospect in any meaningful way.

 

 

Beyond the third License year, we have developed a work plan for the Prospect that is expected to include additional 3D seismic surveying and exploratory drilling. Assuming availability of funding, timely governmental approvals, and access to proper equipment and trained personnel, we feel that a total of about US$19.0 million of outside capital must be invested across the Prospect the final two years of the initial License term.

 

If we are successful with the early wells, we will continue with a full development plan, the scope of which is now uncertain but will be based on technical analysis of acquired seismic data collected and/or reprocessed, field drilling reports and well log reports. However, all of the preceding plans are subject to the availability of sufficient funding and the procurement of all governmental approvals. We do not now have sufficient available funds to undertake these tasks, and will need to procure a joint venture partner or raise additional funds as described above. The failure to procure a joint venture partner or raise additional funds will preclude us from pursuing our business plan, as well as exposing us to the loss of the License, as discussed below. Moreover, if our business plan proceeds as just described, but our first wells do not prove to hold producible reserves, we could be forced to cease our exploration efforts on the Prospect.

 

Major Financing Efforts and Other Sources of Capital

 

Starting in October 2012, we have entered into engagement agreements with several financial intermediaries to assist us in completing a major capital raising transaction. None of these engagements resulted in the completion of such a transaction, and we are not now bound by any such engagement agreement. We are now pursuing our own independent capital raising initiatives, and we have several prospects in this regard.

 

Our capital strategy for most of the past two years or so has been to try to engage in a single major capital raising transaction to provide sufficient funds to satisfy our capital needs for a number of years to come. While we are not completely abandoning this strategy, we are shifting our emphasis in an effort to try to engage in one or more smaller capital raising transactions to provide sufficient funds to satisfy our capital needs through April 2016. We are engaged in discussions regarding smaller financings at this time, but we have not reached an agreement in principle, much less a definitive agreement, in this regard. We have no assurance that we will be successful in obtaining required funds.

 

In addition to smaller, equity placements for short-term needs and a major capital raising transaction for long-term needs, we expect to pursue other possible sources of capital. For example, one source of funding being pursued is the sale of a portion of our interest in the Prospect to a joint venture partner for a cash payment and/or a work commitment. We have had preliminary discussions with several companies to become joint venture partners. To obtain the maximum combination of cash and work commitment in connection with the sale of an interest in the Prospect, we have conducted extensive geological and geophysical work, including the reprocessing of existing 3D seismic data relating to a portion of the Prospect, and we may seek to add further value by completing a 3D seismic survey over other portions of the Prospect. We have no assurance that we will secure a joint venture partner. A joint venture arrangement is unlikely to help with our immediate cash needs, but (if secured) one would help with our longer-term cash needs.

  

Production from successful exploration and drilling efforts would provide us with cash flow. The proven reserves associated with production would increase the value of our rights in the Prospect. This, in turn, should enable us to obtain bank financing (after the wells have produced for a period of time to satisfy the related lender). Both of these results would enable us to continue with our development activities. Cash flow is a critical factor to our plan of operation in the long run. Management believes that, if our plan of operation progresses (and production is realized) as planned, sufficient cash flow and debt financing will be available for purposes of properly pursuing our plan of operation, although we can make no assurances in this regard.

 

Finally, to conserve on our cash requirements, we may try to satisfy some of our obligations by issuing shares of our common stock, which will result in dilution to our existing stockholders.

 

Consequences of a Financing Failure

 

The amount of cash on hand, the pending maturity of the Liberty note, and the need to raise additional capital of at least $3.5 million by the end of April 2016 to continue operations and satisfy our obligations for the second year of our work commitment have all heightened our need to raise a significant amount of additional capital in the near future. If required financing is not available on acceptable terms, we could be prevented from satisfying our debt or work commitment obligations, or developing the Prospect. Our failure to pay timely the Liberty note could result in Liberty’s exercise of the rights of an unsecured creditor and possibly levy encumbrances on all or a large part of our assets. Our failure to honor our work commitment could result in our loss of the Prospect. Our failure to procure required financing on acceptable terms could prevent us from developing the Prospect. If any of the preceding events were to occur, we could be forced to cease our business plan altogether, which could result in a complete loss of stockholders’ equity. If we do not obtain additional financing through an equity or debt offering, we may be constrained to attempt to sell some portion of the Prospect under unfavorable circumstances and at an undesirable price. However, we cannot assure anyone that we will be able to find interested buyers or that the funds received from any such sale would be adequate to fund our activities. Our future liquidity will depend upon numerous factors, including the success of our business efforts and our capital raising activities.

 

 

Item 4T. Controls and Procedures.

 

Evaluation of Disclosure Controls and Procedures

 

Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we have evaluated the effectiveness of the design and operation of its disclosure controls and procedures pursuant to Exchange Act Rule 13a-15(e) and Rule 15d-15(e) as of the end of the period covered by this quarterly report. Based on that evaluation, the principal executive officer and principal financial officer have identified that the lack of segregation of accounting duties as a result of limited personnel resources is a material weakness of its financial procedures. Other than for this exception, the principal executive officer and principal financial officer believe the disclosure controls and procedures are effective to ensure that information required to be disclosed by us in the reports we file or submit under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms and that our disclosure and controls are designed to ensure that information required to be disclosed by us in the reports that we file or submit under the Exchange Act is accumulated and communicated to our management, including our principal executive officer and principal financial officer, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure. There were no significant changes in our internal controls or in other factors that could significantly affect internal controls subsequent to the date of their evaluation and there were no corrective actions with regard to significant deficiencies and material weaknesses.

 

Limitations on Effectiveness of Controls and Procedures

 

Our management, including our Chief Executive Officer and Chief Financial Officer, does not expect that our disclosure controls and procedures or our internal controls will prevent all error and all fraud. A control system, no matter how well conceived and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Further, the design of a control system must reflect the fact that there are resource constraints and the benefits of controls must be considered relative to their costs. Because of the inherent limitations in all control systems, no evaluation of controls can provide absolute assurance that all control issues and instances of fraud, if any, within our company have been detected. These inherent limitations include, but are not limited to, the realities that judgments in decision-making can be faulty and that breakdowns can occur because of simple error or mistake. Additionally, controls can be circumvented by the individual acts of some persons, by collusion of two or more people, or by management override of the control. The design of any system of controls also is based in part upon certain assumptions about the likelihood of future events and there can be no assurance that any design will succeed in achieving its stated goals under all potential future conditions; over time, control may become inadequate because of changes in conditions, or the degree of compliance with the policies or procedures may deteriorate.

 

Changes in Internal Controls over Financial Reporting

 

There have not been any changes in our internal control over financial reporting, as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act, during the period of this report that have materially affected, or are reasonably likely to materially affect our internal control over financial reporting.

 

PART II - OTHER INFORMATION

 

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds.

 

During August 2015, we effected a private placement of 50,000 of our shares of common stock (“Shares”) with one investor at a price of $0.60 per Share. The issuances of these Shares are claimed to be exempt pursuant to Section 4(2) of the Act and Rule 506 of Regulation D under the Act. No advertising or general solicitation was employed in offering these securities. The offering and sale was made only to a single accredited investor, and subsequent transfers were restricted in accordance with the requirements of the Act.

 

 

Item 6. Exhibits.

 

The following exhibits are filed with this Quarterly Report or are incorporated herein by reference:

 

Exhibit Number		Description
31.01		Certification pursuant to Rule 13a-14(a) of the Securities Exchange Act of 1934.
31.02		Certification pursuant to Rule 13a-14(a) of the Securities Exchange Act of 1934.
32.01		Certification Pursuant to 18 U.S.C. Section 1350, as pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.02		Certification Pursuant to 18 U.S.C. Section 1350, as pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS		XBRL Instance Document
101.SCH		XBRL Taxonomy Extension Schema
101.CAL		XBRL Taxonomy Extension Calculation Linkbase
101.DEF		XBRL Taxonomy Extension Definition Linkbase
101.LAB		XBRL Taxonomy Extension Labels Linkbase
101.PRE		XBRL Taxonomy Extension Presentation Linkbase

 

SIGNATURES

 

In accordance with the requirements of the Exchange Act, the Registrant has duly caused this Report to be signed on its behalf by the undersigned, thereunto duly authorized.

 

	DISCOVERY ENERGY CORP.
	(Registrant)
	By:	/s/ Keith J. McKenzie
		Keith J. McKenzie,
		Chief Executive Officer
		(Principal Executive Officer)
	By:	/s/ William E. Begley
		William E. Begley,
		Chief Financial Officer
		(Principal Financial Officer and Principal Accounting Officer)

 

October 13, 2015