Attached files
| file | filename |
|---|---|
| EXCEL - IDEA: XBRL DOCUMENT - DEEP WELL OIL & GAS INC | Financial_Report.xls |
| EX-31.2 - EXHIBIT 31.2 - DEEP WELL OIL & GAS INC | v312102_ex31-2.htm |
| EX-31.1 - EXHIBIT 31.1 - DEEP WELL OIL & GAS INC | v312102_ex31-1.htm |
| EX-32.1 - EXHIBIT 32.1 - DEEP WELL OIL & GAS INC | v312102_ex32-1.htm |
| EX-23.1 - EXHIBIT 23.1 - DEEP WELL OIL & GAS INC | v312102_ex23-1.htm |
| EX-32.2 - EXHIBIT 32.2 - DEEP WELL OIL & GAS INC | v312102_ex32-2.htm |
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
| (Mark One) | ||
| þ | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 | |
| For the quarterly period ended March 31, 2012 | ||
| or | ||
| o | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 | |
| For the transition period from ________to________ | ||
| Commission file number 0-24012 | ||
DEEP WELL OIL & GAS, INC.
(Exact name of registrant as specified in its charter)
| Nevada | 13-3087510 | |
| (State or other jurisdiction of incorporation or organization) | (I.R.S. Employer Identification No.) | |
| Suite 700, 10150 - 100 Street, Edmonton, Alberta, Canada | T5J 0P6 | |
| (Address of principal executive offices) | (Zip Code) | |
Registrant’s telephone number, including area code: (780) 409-8144
Former name, former address and former fiscal year, if changed since last report: not applicable.
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 þ No o
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 during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes þ No o
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.
| Large accelerated filer o | Accelerated filer o | |
| Non-accelerated filer o (Do not check if a smaller reporting company) | Smaller reporting company þ |
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes o No þ
The number of shares of common stock outstanding as of March 31, 2012 was 136,739,971.
| TABLE OF CONTENTS | ||||||||||||
| Page Number | ||||||||||||
| PART I – FINANCIAL INFORMATION | ||||||||||||
| ITEM 1. | CONSOLIDATED FINANCIAL STATEMENTS (unaudited) | |||||||||||
| Consolidated Balance Sheets | 3 | |||||||||||
| Consolidated Statements of Operations and Comprehensive Loss | 4 | |||||||||||
| Consolidated Statements of Cash Flows | 5 | |||||||||||
| Notes to the Consolidated Financial Statements | 6 | |||||||||||
| ITEM 2. | MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS | 17 | ||||||||||
| ITEM 3. | QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK | 22 | ||||||||||
| ITEM 4. | CONTROLS AND PROCEDURES | 22 | ||||||||||
| PART II – OTHER INFORMATION | ||||||||||||
| ITEM 1. | LEGAL PROCEEDINGS | 22 | ||||||||||
| ITEM 1A. | RISK FACTORS | 22 | ||||||||||
| ITEM 2. | UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS | 22 | ||||||||||
| ITEM 3. | DEFAULTS UPON SENIOR SECURITIES | 22 | ||||||||||
| ITEM 4. | MINE SAFETY DISCLOSURES | 22 | ||||||||||
| ITEM 5. | OTHER INFORMATION | 22 | ||||||||||
| ITEM 6. | EXHIBITS | 23 | ||||||||||
| SIGNATURES | 24 | |||||||||||
| 2 |
DEEP WELL OIL & GAS, INC. (AND SUBSIDIARIES)
(Exploration Stage Company)
Consolidated Balance Sheets
March 31, 2012 and September 30, 2011
| March 31, | September 30, | |||||||
| 2012 | 2011 | |||||||
| (Unaudited) | (Audited) | |||||||
| ASSETS | ||||||||
| Current Assets | ||||||||
| Cash and cash equivalents | $ | 277,316 | $ | 723,766 | ||||
| Accounts receivable net of allowance of $354,172 (September 30, 2011 - $350,298) | 25,825 | 34,727 | ||||||
| Accounts receivable – related party (Note 9) | 1,316 | 2,522 | ||||||
| Prepaid expenses | 58,071 | 48,298 | ||||||
| Total Current Assets | 362,528 | 809,313 | ||||||
| Long term investments (Note 8) | 270,519 | 247,937 | ||||||
| Oil and gas properties (Note 3) | 13,194,655 | 13,140,951 | ||||||
| Property and equipment net of depreciation (Note 7) | 374,550 | 425,895 | ||||||
| TOTAL ASSETS | $ | 14,202,252 | $ | 14,624,096 | ||||
| LIABILITIES | ||||||||
| Current Liabilities | ||||||||
| Accounts payable | $ | 38,729 | $ | 18,926 | ||||
| Accounts payable – related parties (Note 9) | 303,196 | 202,638 | ||||||
| Total Current Liabilities | 341,925 | 221,564 | ||||||
| Asset retirement obligations (Note 10) | 412,392 | 387,368 | ||||||
| TOTAL LIABILITIES | 754,317 | 608,932 | ||||||
| SHAREHOLDERS’ EQUITY | ||||||||
| Common Stock: (Note 11) | ||||||||
| Authorized: 300,000,000 shares at $0.001 par value | ||||||||
| Issued and outstanding: 136,739,971 shares | ||||||||
| (September 30, 2011 – 136,739,971 shares) (Note 11) | 136,739 | 136,739 | ||||||
| Additional paid in capital | 27,138,969 | 27,058,078 | ||||||
| Deficit accumulated during exploration stage | (13,827,773 | ) | (13,179,653 | ) | ||||
| Total Shareholders’ Equity | 13,447,935 | 14,015,164 | ||||||
| TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY | $ | 14,202,252 | $ | 14,624,096 | ||||
See accompanying notes to the consolidated financial statements
| 3 |
DEEP WELL OIL & GAS, INC. (AND SUBSIDIARIES)
(Exploration Stage Company)
(Unaudited)
Consolidated Statements of Operations and Comprehensive Loss
For the Three and Six Months Ended March
31, 2012, and 2011 and the Period from September 10, 2003
(Inception of Exploration Stage) to March 31, 2012
| Three Months | Three Months | Six Months | Six Months | September 10, | ||||||||||||||||
| Ended | Ended | Ended | Ended | 2003 to March 31, | ||||||||||||||||
| March 31, 2012 | March 31, 2011 | March 31, 2012 | March 31, 2011 | 2012 | ||||||||||||||||
| Revenue | $ | – | $ | – | $ | – | $ | – | $ | – | ||||||||||
| Expenses | ||||||||||||||||||||
| General and Administrative | 300,798 | 447,793 | 609,209 | 670,000 | 13,584,200 | |||||||||||||||
| Depreciation and accretion | 33,615 | 41,302 | 65,008 | 82,278 | 607,054 | |||||||||||||||
| Net loss from operations | (334,413 | ) | (489,095 | ) | (674,217 | ) | (752,278 | ) | (14,191,254 | ) | ||||||||||
| Other income and expenses | ||||||||||||||||||||
| Rental and other income | 7,538 | 52 | 24,309 | 1,720 | 48,080 | |||||||||||||||
| Interest income | 919 | 640 | 1,853 | 1,090 | 211,936 | |||||||||||||||
| Interest expense | – | – | – | – | (208,580 | ) | ||||||||||||||
| Forgiveness of loan payable | – | – | – | – | 287,406 | |||||||||||||||
| Settlement of debt | – | – | – | – | 24,866 | |||||||||||||||
| Loss on disposal of assets | – | (188 | ) | (64 | ) | (188 | ) | (226 | ) | |||||||||||
| Net loss and comprehensive loss | $ | (325,956 | ) | $ | (488,591 | ) | $ | (648,119 | ) | $ | (749,656 | ) | $ | (13,827,772 | ) | |||||
| Net loss per common share | ||||||||||||||||||||
| Basic and Diluted | $ | (0.00 | ) | $ | (0.00 | ) | $ | (0.00 | ) | $ | (0.00 | ) | ||||||||
| Weighted Average Outstanding | ||||||||||||||||||||
| Shares (in thousands) | ||||||||||||||||||||
| Basic and Diluted | 136,740 | 136,106 | 136,740 | 136,083 | ||||||||||||||||
See accompanying notes to the consolidated financial statements
| 4 |
DEEP WELL OIL & GAS, INC. (AND SUBSIDIARIES)
(Exploration Stage Company)
(Unaudited)
Consolidated Statements of Cash Flows
For the Six Months Ended March 31, 2012
and 2011 and the Period from September 10, 2003
(Inception of Exploration Stage) to March 31, 2012
| Six Months | Six Months | September 10, | ||||||||||
| Ended | Ended | 2003 to | ||||||||||
| March 31, | March 31, | March 31, | ||||||||||
| 2012 | 2011 | 2012 | ||||||||||
| Cash Provided by (Used in): | ||||||||||||
| Operating Activities | ||||||||||||
| Net loss | $ | (648,119 | ) | $ | (749,656 | ) | $ | (13,827,772 | ) | |||
| Items not affecting cash: | ||||||||||||
| Share based compensation | 80,890 | 210,962 | 1,298,313 | |||||||||
| Bad debts | (10,665 | ) | – | 511,575 | ||||||||
| Depreciation and accretion | 65,008 | 82,278 | 607,053 | |||||||||
| Forgiveness of loan payable | – | – | (287,406 | ) | ||||||||
| Settlement of lawsuit | – | – | 435,549 | |||||||||
| Commissions withheld from loans proceeds | – | – | 121,000 | |||||||||
| Loss on disposal of assets | 64 | 188 | 226 | |||||||||
| Net changes in non-cash working capital (Note 13) | 120,696 | 46,875 | (268,954 | ) | ||||||||
| Net Cash (Used) in Operating Activities | (392,126 | ) | (409,353 | ) | (11,410,416 | ) | ||||||
| Investing Activities | ||||||||||||
| Purchase of property and equipment | (863 | ) | (3,254 | ) | (904,472 | ) | ||||||
| Investment in oil and gas properties | (41,544 | ) | (445,224 | ) | (8,616,918 | ) | ||||||
| Long term investments | (11,917 | ) | (15,678 | ) | (259,854 | ) | ||||||
| Cash from acquisition of subsidiary | – | – | 11,141 | |||||||||
| Return of costs from farmout agreement | – | – | 961,426 | |||||||||
| Net Cash (Used) in Investing Activities | (54,324 | ) | (464,156 | ) | (8,808,677 | ) | ||||||
| Financing Activities | ||||||||||||
| Loan payable | – | – | 275,852 | |||||||||
| Loan advance – related parties | – | – | (811,746 | ) | ||||||||
| Note payable repayment | – | – | (111,306 | ) | ||||||||
| Debenture repayment | – | – | (1,004,890 | ) | ||||||||
| Deposit on stock subscription | – | (48,555 | ) | – | ||||||||
| Proceeds from issuance of common stock | – | 2,050,000 | 21,269,499 | |||||||||
| Proceeds from debenture net of commissions | – | – | 879,000 | |||||||||
| Net Cash Provided by Financing Activities | – | 2,001,445 | 20,496,409 | |||||||||
| Increase (decrease) in cash and cash equivalents | (446,450 | ) | 1,127,936 | 277,316 | ||||||||
| Cash and cash equivalents, beginning of period | 723,766 | 103,550 | – | |||||||||
| Cash and cash equivalents, end of period | $ | 277,316 | $ | 1,231,486 | $ | 277,316 | ||||||
| Supplemental Cash Flow Information: | ||||||||||||
| Cash paid for interest | $ | – | $ | – | ||||||||
See accompanying notes to the consolidated financial statements
| 5 |
DEEP WELL OIL & GAS, INC. (AND SUBSIDIARIES)
(Exploration Stage Company)
(Unaudited)
Notes to the Consolidated Financial Statements
March 31, 2012
| 1. | Nature of Business and Basis of Presentation |
Nature of Business
Allied Devices Corporation (“Allied”) and its former subsidiaries were engaged in the manufacture and distribution of standard and custom precision mechanical assemblies and components throughout the United States.
On February 19, 2003, Allied filed a petition for bankruptcy in the United States Bankruptcy Court under Chapter 11 in the Eastern District of New York titled “Allied Devices Corporation, Case No. 03-80962-511.” The company emerged from bankruptcy pursuant to a Bankruptcy Court Order entered on September 10, 2003, with no remaining assets or liabilities and the company name was changed from “Allied Devices Corporation” to Deep Well Oil & Gas, Inc.” (“Deep Well”).
Upon emergence from Chapter 11 proceedings, Deep Well adopted fresh-start reporting in accordance with the American Institute of Certified Public Accountants Statement of Position 90-7, Financial Reporting by Entities in Reorganization Under the Bankruptcy Code (SOP 90-7). In connection with the adoption of fresh-start reporting, a new entity was deemed created for financial reporting purposes. For financial reporting purposes, Deep Well adopted the provisions of fresh-start reporting effective September 10, 2003. In adopting the requirements of fresh-start reporting as of September 10, 2003, the company was required to value its assets and liabilities at fair value and eliminate any accumulated deficit as of September 10, 2003. Deep Well emerged from Chapter 11 proceedings with no assets and liabilities pursuant to the Bankruptcy Order. Because the current business, heavy oil and gas exploration, has no relevance to the predecessor company, there is no basis for financial comparisons between Deep Well’s current operations and the predecessor company.
This report has been prepared showing the name “Deep Well Oil & Gas, Inc. (and Subsidiaries)” (“the Company”) and the post split common stock, with $0.001 par value, from inception. The accumulated deficit has been restated to zero and dated September 10, 2003, with the statement of operations to begin on that date.
Basis of Presentation
The interim consolidated financial statements included herein have been prepared by the Company, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission. Certain information and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America (“US GAAP”) have been condensed or omitted pursuant to such rules and regulations, although the Company believes that the disclosures are adequate so as to make the information presented not misleading.
These interim consolidated financial statements follow the same significant accounting policies and methods of application as the Company’s annual consolidated financial statements for the year ended September 30, 2011.
These statements reflect all adjustments, consisting of normal recurring adjustments which, in the opinion of management, are necessary for a fair presentation of the information contained therein. However, the results of operations for the interim periods may not be indicative of results to be expected for the full fiscal year. It is suggested that these consolidated financial statements be read in conjunction with the audited consolidated financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the year ended September 30, 2011.
| 2. | Summary of Significant Accounting Policies |
Basis of Consolidation
These consolidated financial statements include the accounts of two wholly owned subsidiaries: (1) Northern Alberta Oil Ltd. (“Northern”) from the date of acquisition, being June 7, 2005, incorporated under the Business Corporations Act (Alberta), Canada; and (2) Deep Well Oil & Gas (Alberta) Ltd., incorporated under the Business Corporations Act (Alberta), Canada on September 15, 2005. All inter-company balances and transactions have been eliminated.
| 6 |
Cash and Cash Equivalents
The Company considers all highly liquid instruments with a maturity of three months or less at the time of issuance to be cash equivalents.
Allowance for Doubtful Accounts
The Company determines allowances for doubtful accounts based on aging of specific accounts. Accounts receivable are stated at the historical carrying amounts net of allowances for doubtful accounts and include only the amounts the Company deems to be collectable.
Property and Equipment
Property and equipment are stated at cost less accumulated depreciation. Depreciation expense is computed using the declining balance method over the estimated useful life of the asset. Only half of the depreciation rate is taken in the year of acquisition. The following is a summary of the depreciation rates used in computing depreciation expense:
| Software | - 100% |
| Computer equipment | - 55% |
| Portable work camp | - 30% |
| Vehicles | - 30% |
| Road Mats | - 30% |
| Wellhead | - 25% |
| Office furniture and equipment | - 20% |
| Oilfield Equipment | - 20% |
| Tanks | - 10% |
Expenditures for major repairs and renewals that extend the useful life of the asset are capitalized. Minor repair expenditures are charged to expense as incurred. Leasehold improvements are amortized over the greater of five years or the remaining life of the lease agreement.
Long-Lived Assets
The Company reviews for the impairment of long-lived assets whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. An impairment loss would be recognized when estimated undiscounted future cash flows expected to result from the use of the asset and its eventual disposition is less than its carrying amount. Impairment is measured as the amount by which the assets’ carrying value exceeds its fair value.
Asset Retirement Obligations
The Company accounts for asset retirement obligations by recording the estimated future cost of the Company’s plugging and abandonment obligations. The asset retirement obligation is recorded when there is a legal obligation associated with the retirement of a tangible long-lived asset and the fair value of the liability can reasonably be estimated. Upon initial recognition of an asset retirement obligation, the Company increases the carrying amount of the long-lived asset by the same amount as the liability. Over time, the liabilities are accreted for the change in their present value through charges to oil and gas production and well operations costs. The initial capitalized costs are depleted over the useful lives of the related assets through charges to depreciation, depletion, and amortization. If the fair value of the estimated asset retirement obligation changes, an adjustment is recorded to both the asset retirement obligation and the asset retirement cost.
Revisions in estimated liabilities can result from revisions of estimated inflation rates, escalating retirement costs, and changes in the estimated timing of settling asset retirement obligations. As at March 31, 2012, asset retirement obligations amount to $412,392. The Company has posted bonds, where required, with the Government of Alberta based on the amount the government estimates the cost of abandonment and reclamation to be.
Foreign Currency Translation
The functional currency of the Canadian subsidiaries is the United States dollar. However, the Canadian subsidiaries transact in Canadian dollars. Consequently, monetary assets and liabilities are remeasured into United States dollars at the exchange rate on the balance sheet date and non-monetary items are remeasured at the rate of exchange in effect when the assets are acquired or obligations incurred. Revenues and expenses are remeasured at the average exchange rate prevailing during the period. Foreign currency transaction gains and losses are included in results of operations.
| 7 |
Accounting Method
The Company recognizes income and expenses based on the accrual method of accounting.
Dividend Policy
The Company has not yet adopted a policy regarding payment of dividends.
Financial, Concentration and Credit Risk
The Company does not have any concentration or related financial credit risk as most of the Company’s funds are maintained in a financial institution which has its deposits fully guaranteed by the Government of Alberta and the accounts receivable are considered to be fully collectable.
Income Taxes
The Company utilizes the liability method of accounting for income taxes. Under the liability method, deferred tax assets and liabilities are determined based on the differences between financial reporting and the tax bases of the assets and liabilities, and are measured using the enacted tax rates and laws that will be in effect when the differences are expected to reverse. An allowance against deferred tax assets is recorded when it is more likely than not that such tax benefits will not be realized.
Due to the uncertainty regarding the Company’s profitability, a valuation allowance has been recorded against the future tax benefits of its losses and no net benefit has been recorded in the consolidated financial statements.
Revenue Recognition
The Company is in the business of exploring for, developing, producing, and selling crude oil and natural gas. Crude oil revenue is recognized when the product is taken from the storage tanks on the lease and delivered to the purchaser. Natural gas revenues are recognized when the product is delivered into a third party pipeline downstream of the lease. Occasionally the Company may sell specific leases, and the gain or loss associated with these transactions will be shown separately from the profit or loss from the operations or sales of oil and gas products.
Advertising and Market Development
The Company expenses advertising and market development costs as incurred.
Basic and Diluted Net Income (Loss) Per Share
Basic net income (loss) per share amounts are computed based on the weighted average number of shares actually outstanding. Diluted net income (loss) per share amounts are computed using the weighted average number of common shares and common equivalent shares outstanding as if shares had been issued on the exercise of the common share rights, unless the exercise becomes antidilutive and then the basic and diluted per share amounts are the same.
Financial Instruments
Fair Values
Financial instruments include cash and cash equivalents, accounts receivable, accounts receivable - related party, long term investments, investment in equity securities, accounts payable and accounts payable - related parties. The fair value of these financial instruments approximates their carrying value because of the short-term maturity of these items unless otherwise noted. The fair value of the investment in equity securities cannot be determined as the market value is not readily obtainable. The equity securities are reported using the cost method.
Environmental Requirements
At the report date, environmental requirements related to the oil and gas properties acquired are unknown and therefore an estimate of any future cost cannot be made.
| 8 |
Share-Based Compensation
The Company accounts for stock options granted to directors, officers, employees and non-employees using the fair value method of accounting. The fair value of stock options for directors, officers and employees are calculated at the date of grant and is expensed over the vesting period of the options on a straight-line basis. For non-employees, the fair value of the options is measured on the earlier of the date at which the counterparty performance is complete or the date at which the performance commitment is reached. The Company uses the Black-Scholes model to calculate the fair value of stock options issued, which requires certain assumptions to be made at the time the options are awarded, including the expected life of the option, the expected number of granted options that will vest and the expected future volatility of the stock. The Company reflects estimates of award forfeitures at the time of grant and revises in subsequent periods, if necessary, when forfeiture rates are expected to change.
Recently Adopted Accounting Standards
In June 2011, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2011-05, “Comprehensive Income (Topic 220) – Presentation of Comprehensive Income.” ASU 2011-05 amends ASC 220 to now require: (1) an entity should present each component of net income along with total net income, each component of other comprehensive income along with a total for other comprehensive income, and a total amount for comprehensive income; and (2) the entity should present on the face of the financial statements reclassification adjustments for items that are reclassified from other comprehensive income to net income in the statement(s) where the components of net income and the components of other comprehensive income are presented; and (3) the tax effect for each component must be disclosed in the notes to the financial statements or presented in the statement in which other comprehensive income is presented. ASU 2011-05 is effective for fiscal years, and interim periods within those years, beginning after December 15, 2011. Early adoption is permitted. The amendments do not require any transition disclosures. The adoption of these accounting standards has not had a significant effect on the financial statement presentation.
In May 2011, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2011-04, “Fair Value Measurement (Topic 820) – Amendments to Achieve Common Fair Value Measurement and Disclosure Requirements in U.S. GAAP and IFRSs.” ASU 2011-04 change the wording used to describe many of the requirements in U.S. GAAP for measuring fair value and for disclosing information about fair value measurements. The amendments are effective for annual periods beginning after December 15, 2011. Early application by public entities is not permitted.
Estimates and Assumptions
Management uses estimates and assumptions in preparing financial statements in accordance with generally accepted accounting principles. Those estimates and assumptions affect the reported amounts of the assets and liabilities, the disclosure of contingent assets and liabilities, and the reported revenues and expenses. Actual results could vary from the estimates that were used in preparing these consolidated financial statements.
Significant estimates by management include valuations of oil and gas properties, valuation of accounts receivable, useful lives of long-lived assets, asset retirement obligations, valuation of share-based compensation, and the realizability of future income taxes.
| 3. | Oil and Gas Properties |
The Company has acquired interests in certain oil sands properties located in North Central Alberta, Canada. The terms include certain commitments related to oil sands properties that require the payments of rents as long as the leases are non-producing. As of March 31, 2012, Northern’s net payments due in Canadian dollars under this commitment are as follows:
| 2012 | $ | 22,579 |
| 2013 | $ | 45,158 |
| 2014 | $ | 45,158 |
| 2015 | $ | 45,158 |
| 2016 | $ | 45,158 |
| 2017 | $ | 45,158 |
| Subsequent | $ | 88,883 |
The Government of Alberta owns this land and the Company has acquired the rights to perform oil and gas activities on these lands. If the Company meets the conditions of the 15-year leases the Company will then be permitted to drill on and produce oil from the land into perpetuity. These conditions give the Company until the expiration of the leases to meet the following requirements on its primary oil sands leases:
| a) | drill 68 wells throughout the 68 sections; or |
| b) | drill 44 wells within the 68 sections and having acquired and processed 2 miles of seismic on each other undrilled section. |
| 9 |
The Company plans to meet the second of these conditions. As at March 31, 2012, the Company has an interest in ten wells, which can be counted towards these requirements.
The Company has identified 2 other wells drilled on these leases, which may be included in the satisfaction of this requirement. The Company has also acquired and processed 25 miles of seismic on the leases, which can be counted towards these requirements.
The Company follows the successful efforts method of accounting for costs of oil and gas properties. Under this method, only those exploration and development costs that relate directly to specific oil and gas reserves are capitalized; costs that do not relate directly to specific reserves are charged to expense. Producing, non-producing and unproven properties are assessed annually, or more frequently as economic events indicate, for potential impairment.
This consists of comparing the carrying value of the asset with the asset’s expected future undiscounted cash flows. Estimates of expected future cash flows represent management’s best estimate based on reasonable and supportable assumptions. Proven oil and gas properties are reviewed for impairment on a field-by-field basis. No impairment losses were recognized for the period ended March 31, 2012 (September 30, 2011 - $nil).
Capitalized costs of proven oil and gas properties are depleted using the unit-of-production method when the property is placed in production.
Substantially all of the Company’s oil and gas activities are conducted jointly with others. The accounts reflect only the Company’s proportionate interest in such activities.
| 4. | Capitalization of Costs Incurred in Oil & Gas Activities |
The Company accounts for the cost of exploratory wells and continues to capitalize exploratory well costs after the completion of drilling as long as sufficient progress is being made in assessing the oil sands reserves to justify its completion as a producing well.
For the period ended March 31, 2012, the Company’s management determined that sufficient progress has been made in assessing its oil sands reserves for continued capitalization of exploratory well costs. In relation to this sufficient progress assessment of its oil sands project the Company considered among other criteria; long lead times in getting regulatory approval for oil sands thermal recovery projects, road bans, winter access only properties and governmental and environmental regulations which can and often delay development of oil sands projects. Because of these and other factors, the Company’s oil sands project can take significantly longer to complete than regular conventional drilling programs for lighter oil. To date the Company’s geological, engineering and economic studies continue to lead them to believe that there is continuing progress toward bringing the project to commercial production. Therefore, the Company has continued to capitalize its costs associated with its oil sands project.
For the Company’s exploratory wells, drilling costs are capitalized on the balance sheet under “Oil and Gas Properties” line item, pending a determination of whether potentially economic oil sands reserves have been discovered by the drilling effort to justify completion of the find as a producing well. The Company periodically assesses the exploration and drilling capitalized costs for impairment and once a determination is made that a well is of no potential economic value, the costs related to that well are expensed as dry hole and reported in exploration expense.
The following table illustrates capitalized costs relating to oil and gas – producing activities for two periods ended March 31, 2012 and September 30, 2011:
| March 31, 2012 | September 30, 2011 | |||||||
| Unproved Oil and Gas Properties | $ | 13,223,349 | $ | 13,165,546 | ||||
| Proved Oil and Gas Properties | – | – | ||||||
| Accumulated Depreciation | (28,694 | ) | (24,595 | ) | ||||
| Net Capitalized Cost | $ | 13,194,655 | $ | 13,140,951 | ||||
| 10 |
| 5. | Exploration Activities |
The following table presents information regarding the Company’s costs incurred in the oil and gas property acquisition, exploration and development activities for two periods ended March 31, 2012 and September 30, 2011:
| March 31, 2012 | September 30, 2011 | |||||||
| Acquisition of Properties: | ||||||||
| Proved | $ | – | $ | – | ||||
| Unproved | 57,803 | 422,362 | ||||||
| Exploration costs | 36,947 | 163,914 | ||||||
| Development costs | – | – | ||||||
| 6. | Investment in Equity Securities |
On February 25, 2005, the Company acquired an interest in Signet Energy Inc. (“Signet” formerly Surge Global Energy, Inc.) as a result of a Farmout Agreement. As of November 19, 2008, the Company converted its Signet shares into 2,241,558 shares of Andora Energy Corporation (“Andora”), which represents an equity interest in Andora of approximately 3.9% as of December 31, 2011, which is Andora’s fiscal year end. These shares are carried at a nominal value using the cost method and their value is included under oil and gas properties on our balance sheet.
| 7. | Property and Equipment |
| March 31, 2012 | ||||||||||||
| Accumulated | Net Book | |||||||||||
| Cost | Depreciation | Value | ||||||||||
| Computer equipment | $ | 31,084 | $ | 28,501 | $ | 2,583 | ||||||
| Office furniture and equipment | 33,199 | 19,647 | 13,552 | |||||||||
| Software | 5,826 | 5,826 | – | |||||||||
| Leasehold improvements | 4,936 | 3,232 | 1,704 | |||||||||
| Portable work camp | 170,580 | 110,190 | 60,390 | |||||||||
| Vehicles | 38,077 | 24,597 | 13,480 | |||||||||
| Oilfield equipment | 154,713 | 73,685 | 81,028 | |||||||||
| Road mats | 364,614 | 235,532 | 129,082 | |||||||||
| Wellhead | 3,254 | 763 | 2,491 | |||||||||
| Tanks | 96,085 | 25,844 | 70,240 | |||||||||
| $ | 902,368 | $ | 527,817 | $ | 374,550 | |||||||
| September 30, 2011 | ||||||||||||
| Accumulated | Net Book | |||||||||||
| Cost | Depreciation | Value | ||||||||||
| Computer Equipment | $ | 30,655 | $ | 28,060 | $ | 2,595 | ||||||
| Office furniture and equipment | 33,199 | 18,141 | 15,058 | |||||||||
| Software | 5,826 | 5,826 | – | |||||||||
| Leasehold improvements | 4,936 | 2,277 | 2,659 | |||||||||
| Portable work camp | 170,580 | 99,533 | 71,047 | |||||||||
| Vehicles | 38,077 | 22,218 | 15,859 | |||||||||
| Oilfield equipment | 154,713 | 64,682 | 90,031 | |||||||||
| Road mats | 364,614 | 212,752 | 151,862 | |||||||||
| Wellhead | 3,254 | 407 | 2,847 | |||||||||
| Tanks | 96,085 | 22,148 | 73,937 | |||||||||
| $ | 901,939 | $ | 476,044 | $ | 425,895 | |||||||
There was $52,144 of depreciation expense for the period ended March 31, 2012 (September 30, 2011 - $141,031).
| 11 |
| 8. | Long Term Investments |
Long term investments consist of cash held in trust by the Energy Resources Conservation Board (“ERCB”) which bears interest at a rate of prime minus 0.375% and has no stated date of maturity. These investments are required by the ERCB to ensure there are sufficient future cash flows to meet the expected future asset retirement obligations, and are restricted for this purpose.
| 9. | Significant Transactions With Related Parties |
Accounts receivable – related party was $1,316 as of March 31, 2012 (September 30, 2011 - $2,522) for rents receivable from a corporation owned by a director. This amount is unsecured, non-interest bearing and has no fixed terms of repayment. The balance was repaid subsequent to quarter end.
Accounts payable – related parties was $303,196 as of March 31, 2012 (September 30, 2011 - $202,638) for fees payable to corporations owned by directors. This amount is unsecured, non-interest bearing, and has no fixed terms of repayment.
As of March 31, 2012, officers, directors, their families, and their controlled entities have acquired 52.19% of the Company’s outstanding common capital stock. This percentage does not include unexercised warrants or stock options.
The Company incurred expenses totalling $166,122 to two related parties for professional fees and consulting services during the period ended March 31, 2012 (September 30, 2011 - $209,117).
| 10. | Asset Retirement Obligations |
The total future asset retirement obligation is estimated by management based on the Company’s net working interests in all wells and facilities, estimated costs to reclaim and abandon wells and facilities and the estimated timing of the costs to be incurred in future periods. At March 31, 2012, the Company estimates the undiscounted cash flows related to asset retirement obligation to total approximately $655,447 (September 30, 2011 - $644,226). The fair value of the liability at March 31, 2012 is estimated to be $412,392 (September 30, 2011 - $387,368) using a risk free rate of 3.74% and an inflation rate of 2%. The actual costs to settle the obligation are expected to occur in approximately 35 years.
Changes to the asset retirement obligation were as follows:
| March 31, 2012 | September 30, 2011 | |||||||
| Balance, beginning of period | $ | 387,368 | $ | 386,934 | ||||
| Liabilities incurred | – | – | ||||||
| Effect of foreign exchange | 16,259 | (5,490 | ) | |||||
| Disposal | – | (6,839 | ) | |||||
| Accretion expense | 8,765 | 12,763 | ||||||
| Balance, end of period | $ | 412,392 | $ | 387,368 | ||||
| 11. | Common Stock |
On November 9, 2010, the Company completed two private placements for an aggregate of 29,285,713 units at a price of $0.07 per unit for an aggregate of $2,050,000 (including the Deposit received prior to September 30, 2010 of $48,555). Each unit consists of one common share and one common share purchase warrant. Each warrant entitles the holder to purchase one additional common share at a price of $0.105 per common share for a period of three years from the date of closing, provided that if the closing price of the Common Shares of the Company on the principal market on which the shares trade is equal to or exceeds $1.00 for 30 consecutive trading days, the warrant term shall automatically accelerate to the date which is 30 calendar days following the date that written notice has been given to the warrant holders. The warrants expire on November 9, 2013.
On March 23, 2011, the Board of Directors (the “Board”) approved the issuance of 500,000 restricted common shares valued at $70,000 to be issued to a new director as an incentive to join the Board. Also, on March 23, 2011, the Board approved issuance of 180,000 restricted common shares valued at $25,200 to be issued on April 1, 2011 to a contractor as compensation for services provided to the Company during the period from April 1, 2010 to March 31, 2011. These transactions have been recorded in the Balance Sheets under Shareholders’ Equity at the fair value of the common shares issued.
On August 14, 2011, 12,638,297 warrants previously granted on August 14, 2008 expired unexercised.
| 12 |
On October 31, 2011, 14,500,000 warrants previously granted on October 31, 2008 expired unexercised.
There were 30,324,513 warrants outstanding as of March 31, 2012, (September 30, 2011 – 44,824,513), which have a historical fair market value of $1,058,429.
| 12. | Stock Options |
On November 28, 2005, the Board of Deep Well adopted the Deep Well Oil & Gas, Inc. Stock Option Plan (the “Plan’). The Plan was approved by the majority of shareholders at the February 24, 2010 general meeting of shareholders. The Plan, is administered by the Board, permits options to acquire shares of the Company’s common stock (the “Common Shares”) to be granted to directors, senior officers and employees of the Company and its subsidiaries, as well as certain consultants and other persons providing services to the Company or its subsidiaries.
The maximum number of shares, which may be reserved for issuance under the Plan, may not exceed 10% of the Company’s issued and outstanding Common Shares, subject to adjustment as contemplated by the Plan. The aggregate number of Common Shares with respect to which options may be vested to any one person (together with their associates) in any one year, together with all other incentive plans of the Company, may not exceed 500,000 Common Shares, and in total may not exceed 2% of the total number of Common Shares outstanding.
On November 28, 2010, all of the stock options previously granted to Dr. Horst A. Schmid, Portwest Investments Ltd., Mr. Curtis James Sparrow, Concorde Consulting, Trebax Projects Ltd., Mr. Cyrus Spaulding, Mr. Donald E.H. Jones and Mr. Moses Ling, expired unexercised. In total 2,727,500 options granted to directors and former directors and their controlled companies expired.
On March 23, 2011, the Board approved to decrease the exercise price of the stock options to purchase 36,000 shares of common stock of Deep Well previously granted to an employee of the Company on September 20, 2007. The exercise price of the stock option is reduced from $0.47 per Common Share to $0.14 per Common Share, effective immediately. All other terms and conditions of the option agreement will remain unchanged. The options expire on September 20, 2012.
On March 23, 2011, the Company granted its directors, Dr. Horst A. Schmid, Mr. Said Arrata, Mr. Satya Das, Mr. David Roff, Mr. Curtis Sparrow and Mr. Malik Youyou, options to purchase 450,000 shares each of common stock at an exercise price of $0.14 per Common Share, 150,000 vesting immediately and the remaining vesting one-third on March 23, 2012, and one-third on March 23, 2013, with a five-year life.
On October 25, 2011, 375,000 stock options previously granted on October 25, 2006 to Mr. David Roff expired unexercised.
For the period ended March 31, 2012, the Company recorded share based compensation expense related to stock options in the amount of $80,890 (September 30, 2011 – $199,081) on the 2,700,000 stock options issued March 23, 2011. No options were exercised during the period ended March 31, 2012, therefore, the intrinsic value of the options exercised during the period ended March 31, 2012 is $nil. As of March 31, 2012, there was remaining unrecognized compensation cost of $53,725 related to the non-vested portion of these unit option awards. Compensation expense is based upon straight-line depreciation of the grant-date fair value over the vesting period of the underlying unit option.
| Shares Underlying Options Outstanding | Shares Underlying Options Exercisable | |||||||||||||||||||
| Range of Exercise Prices | Shares Underlying Options Outstanding | Weighted Average Remaining Contractual Life | Weighted Average Exercise Price | Shares Underlying Options Exercisable | Weighted Average Exercise Price | |||||||||||||||
| $0.47 at March 31, 2012 | 240,000 | 0.47 | $ | 0.47 | 240,000 | $ | 0.47 | |||||||||||||
| $0.14 at March 31, 2012 | 2,736,000 | 3.93 | 0.14 | 1,836,000 | 0.14 | |||||||||||||||
| 2,976,000 | 3.66 | $ | 0.17 | 2,076,000 | $ | 0.18 | ||||||||||||||
The aggregate intrinsic value of exercisable options as of March 31, 2012, was $nil (September 30, 2011 - $nil).
| 13 |
The following is a summary of stock option activity as at March 31, 2012:
| Number of Shares | Weighted Average Exercise Price | Weighted Average Fair Market Value | ||||||||||
| Balance, September 30, 2011 | 3,351,000 | $ | 0.23 | $ | 0.15 | |||||||
| Options expired October 25, 2011 | (375,000 | ) | 0.71 | 0.27 | ||||||||
| Balance, March 31, 2012 | 2,976,000 | $ | 0.17 | $ | 0.13 | |||||||
| Exercisable, March 31, 2012 | 2,076,000 | $ | 0.18 | $ | 0.14 | |||||||
The following table summarizes the activity of the Company’s non-vested stock options since September 30, 2011:
| Non-Vested Options | ||||||||
| Number of Shares | Weighted Average Exercise Price | |||||||
| Non-vested at September 30, 2011 | 1,800,000 | $ | 0.14 | |||||
| Options vested at March 23, 2012 | (900,000 | ) | $ | 0.14 | ||||
| Non-vested at March 31, 2012 | 900,000 | $ | 0.14 | |||||
Measurement Uncertainty
The Black-Scholes option pricing model was developed for use in estimating the fair value of traded options that have no vesting restrictions and are fully transferable. Stock options and the warrants attached to the units issued by the Company are non-transferable. Option pricing models require the input of subjective assumptions including expected share price volatility. The fair value estimate can vary materially as a result of changes in the assumptions. The following assumptions are used in the Black-Scholes option-pricing model:
Expected Term – Expected term of 5 years represents the period that the Company’s stock-based awards are expected to be outstanding.
Expected Volatility – Expected volatilities are based on historical volatility of the Company’s stock, adjusted where determined by management for unusual and non-representative stock price activity not expected to recur. The expected volatility used was 116%.
Expected Dividend – The Black-Scholes valuation model calls for a single expected dividend yield as an input. The Company currently pays no dividends and does not expect to pay dividends in the foreseeable future.
Risk-Free Interest rate – The Company bases the risk-free interest rate on the implied yield currently available on U.S. Treasury zero-coupon issues with an equivalent remaining term. The risk-free rate used was 2.07%.
| 13. | Changes in Non-Cash Working Capital |
| Six Months Ended | Six Months Ended | |||||||
| March 31, 2012 | March 31, 2011 | |||||||
| Accounts receivable | $ | 10,108 | $ | (19,672 | ) | |||
| Prepaid expenses | (9,773 | ) | 26,789 | |||||
| Accounts payable | 120,361 | 39,758 | ||||||
| $ | 120,696 | $ | 46,875 | |||||
| 14 |
| 14. | Commitments |
Compensation to Directors
Since the acquisition of Northern Alberta Oil Ltd., the Company and Northern have entered into the following contracts with the following companies for the services of their officers:
| 1) | Portwest Investments Ltd., a company owned 100% by Dr. Horst A. Schmid, for providing services to the Company as Chief Executive Officer and President for Cdn $12,500 per month. As of March 31, 2012, the Company has accrued Cdn $206,875 owing to Portwest Investments Ltd., and did not pay out this accrued portion to Portwest Investments Ltd. for the services of Dr. Schmid as Chief Executive Officer and President of the Company. |
| 2) | Concorde Consulting, a company owned 100% by Mr. Curtis J. Sparrow, for providing services as Chief Financial Officer to the Company for $15,000 Cdn per month. |
Rental Agreement
On November 20, 2007 and December 1, 2008, the Company entered into two office lease agreements commencing December 1, 2007 and January 1, 2009 and expiring on November 30, 2012 and December 31, 2013, respectively. The annual payments due in Canadian dollars are as follows:
| 2012 | $ | 36,690 |
| 2013 | $ | 47,647 |
| 2014 | $ | 10,625 |
| 15. | Legal Actions |
IGM Resources Corp vs. Deep Well Oil & Gas, Inc., et al
On March 10, 2005, I.G.M. Resources Corp. (“the Plaintiff”) filed against Classic Energy Inc., 979708 Alberta Ltd., Deep Well Oil & Gas, Inc., Nearshore Petroleum Corporation, Mr. Steven P. Gawne, Rebekah Gawne, Gawne Family Trust, 1089144 Alberta Ltd., John F. Brown, Diane Lynn McClaflin, Cassandra Doreen Brown, Elissa Alexandra Brown, Brown Family Trust, Priority Exploration Ltd., Northern Alberta Oil Ltd. and Gordon Skulmoski (“the Defendant”) a Statement of Claim in the Court of Queen's Bench of Alberta Judicial District of Calgary. This suit is a part of a series of lawsuits or actions undertaken by the Plaintiff against some of the other above defendants.
The Plaintiff was and still is a minority shareholder of 979708 Alberta Ltd. ("979708"). 979708 was in the business of discovering, assembling and acquiring oil and gas prospects. In 2002 and 2003, 979708 acquired oil and gas prospects in the Sawn Lake area of Alberta. On or about the 14th of July, 2003, all or substantially all the assets of 979708 were sold to Classic Energy Inc. The Plaintiff claims the value of the assets sold was far in excess of the value paid for those assets. On April 23, 2004, Northern purchased Classic Energy Inc.'s assets, some of which are under dispute by the Plaintiff. On June 7, 2005, Deep Well acquired all of the common shares of Northern thereby giving Deep Well an indirect beneficial interest in the assets in which the Plaintiff is claiming an interest.
The Plaintiff seeks an order setting aside the transaction and returning the assets to 979708, compensation in the amount of $15,000,000 Cdn, a declaration of trust declaring that Northern and Deep Well hold all of the assets acquired from 979708 and any property acquired by use of such assets, or confidential information of 979708, in trust for the Plaintiff.
This lawsuit has been stayed pending the outcome of the other litigation by the Plaintiff against some of the above defendants other than Deep Well and Northern. The Company believes the claims are without merit and will vigorously defend against them. As at March 31, 2012, no contingent liability has been recorded, as the Company believes that a successful outcome for the Plaintiff is remote.
Hardie & Kelly vs. Brown et al
On June 2, 2006, Hardie and Kelly (“the Plaintiff”), Trustee of the Estate of John Forbes Brown, filed against John Forbes Brown, a bankrupt, Diane Lynn McClaflin, 1089144 Alberta Ltd., and Deep Well (“the Defendants”) an Amended Statement of Claim in the Court of Queen's Bench of Alberta Judicial District of Calgary. John Forbes Brown was a former officer and then sub-contractor of Deep Well before and during the time he was assigned into bankruptcy on July 12, 2004. The Plaintiff claims, in addition to other issues unrelated to Deep Well, that John Forbes Brown received 4,812,500 Deep Well shares as a result of his employment at Deep Well and that John Forbes Brown improperly assigned these shares to the numbered company as a ruse entered into on the eve of insolvency by John Forbes Brown in order to facilitate the hiding of assets from his creditors and the trustee of his bankruptcy. The Plaintiff further claims that on August 23, 2004, John Forbes Brown advised the Plaintiff that he in fact owned the above shares and did not disclose this ownership in his filed bankruptcy statement of affairs.
| 15 |
The Plaintiff further claims that John Forbes Brown would lodge the said shares with his lawyer until such time as these shares could be transferred to the Plaintiff. The Plaintiff further claims that, unbeknownst to them, John Forbes Brown surreptitiously removed the shares from his lawyer's office and delivered them to Deep Well so that Deep Well could cancel them. The Plaintiff claims that Deep Well conspired with John Forbes Brown to defraud the creditors of John Forbes Brown by taking receipt and cancelling the said shares. The Plaintiff claims that consideration paid by Deep Well for the said shares was invested in the home owned by John Forbes Brown and his wife. The Plaintiff seeks: (1) an accounting of the proceeds and benefits derived by the dealings of the shares; (2) the home owned by John Forbes Brown and his wife, to be held in trust on behalf of the Plaintiff and an accounting of proceeds related to this trust; (3) damages from the Defendants because of their actions; (4) a judgement for $15,612,645 Cdn; (5) an order to sell John Forbes Brown's home; and (6) interest and costs.
Deep Well plans to vigorously defend itself against the Plaintiff's claims. As at March 31, 2012, no contingent liability has been recorded, as the Company believes that a successful outcome for the Plaintiff is remote.
| 16 |
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
The following discussion and analysis should be read in conjunction with our consolidated financial statements and related notes. For the purpose of this discussion, unless the context indicates another meaning, the terms: “Deep Well,” “Company,” “we,” “us” and “our” refer to Deep Well Oil & Gas, Inc. and its subsidiaries. This discussion includes forward-looking statements that reflect our current views with respect to future events and financial performance that involve risks and uncertainties. Our actual results, performance or achievements could differ materially from those anticipated in the forward-looking statements as a result of certain factors including risks discussed in Management’s Discussion and Analysis of Financial Condition and Results of Operations – “Forward-Looking Statements” below and elsewhere in this report, and under the heading “Risk Factors” and “Environmental Laws and Regulations” in our annual report on Form 10-K for the fiscal year ended September 30, 2011, filed with the Securities and Exchange Commission on December 29, 2011.
Our consolidated financial statements and information are reported in U.S. dollars and are prepared based upon United States generally accepted accounting principles (“US GAAP”).
General Overview
Deep Well Oil & Gas, Inc., along with its subsidiaries through which it conducts business, is an emerging independent junior oil and gas exploration and development company headquartered in Edmonton, Alberta, Canada. Our immediate corporate focus is to develop the existing land base that we presently control in the Peace River oil sands area in Alberta, Canada. Our principal office is located at suite 700, 10150 - 100 Street, Edmonton, Alberta, Canada T5J 0P6, our telephone number is (780) 409-8144, and our fax number is (780) 409-8146. Deep Well Oil & Gas, Inc. is a Nevada corporation and trades on the OTCQB marketplace under the symbol DWOG. We maintain a website at www.deepwelloil.com.
On April 21, 2010, we announced our quotation on the OTCQB marketplace. This graduation from the “Pink Sheets – Current Information” tier recognizes the progress that we have made in meeting our reporting requirements under the Securities Exchange Act of 1934. The OTCQB is a market that requires companies to be up to date in their filing requirements under the Securities Exchange Act of 1934.
Results of Operations for the Three and Six Months Ended March 31, 2012
We are an exploration stage company and as such do not have commercial production on any of our properties and, accordingly, we currently do not generate cash from operations. Since the inception of our current business plan, our operations have consisted primarily of various exploration and start-up activities relating to our properties, which included acquiring lease holdings by acquisitions and public offerings, seeking investors, locating joint venture partners, acquiring and analyzing seismic data, engaging various firms to comply with leasehold conditions and environmental regulations as well as project management, and developing our long term business strategies. For the six months ended March 31, 2012, and for the comparable period in the prior year, we generated no revenues from operations.
| Three Months | Three Months | Six Months | Six Months | September 10, | ||||||||||||||||
| Ended | Ended | Ended | Ended | 2003 to March 31, | ||||||||||||||||
| March 31, 2012 | March 31, 2011 | March 31, 2012 | March 31, 2011 | 2012 | ||||||||||||||||
| Revenue | $ | – | $ | – | $ | – | $ | – | $ | – | ||||||||||
| Expenses | ||||||||||||||||||||
| General and administrative | 300,798 | 447,793 | 609,209 | 670,000 | 13,584,200 | |||||||||||||||
| Depreciation and accretion | 33,615 | 41,302 | 65,008 | 82,278 | 607,054 | |||||||||||||||
| Net loss from operations | (334,413 | ) | (489,095 | ) | (674,217 | ) | (752,278 | ) | (14,191,254 | ) | ||||||||||
| Other income and expenses | ||||||||||||||||||||
| Rental and other income | 7,538 | 52 | 24,309 | 1,720 | 48,080 | |||||||||||||||
| Interest income | 919 | 640 | 1,853 | 1,090 | 211,936 | |||||||||||||||
| Interest expense | – | – | – | – | (208,580 | ) | ||||||||||||||
| Forgiveness of loan payable | – | – | – | – | 287,406 | |||||||||||||||
| Settlement of debt | – | – | – | – | 24,866 | |||||||||||||||
| Loss on disposal of assets | – | (188 | ) | (64 | ) | (188 | ) | (226 | ) | |||||||||||
| Net loss and comprehensive loss | $ | (325,956 | ) | $ | (488,591 | ) | $ | (648,119 | ) | $ | (749,656 | ) | $ | (13,827,772 | ) | |||||
| 17 |
For the three months ended March 31, 2012, our general and administrative expenses decreased by $146,995 compared to the three months ended March 31, 2011, which was 33% decrease primarily due to a decrease in share-based compensation charged to expense, which was related to vested stock options that were granted to our directors and general office expenses.
For the six months ended March 31, 2012, our general and administrative expenses decreased by $60,791 compared to the six months ended March 31, 2011, which was a 10% decrease primarily due to a decrease in share-based compensation charged to expense, which was related to vested stock options that were granted to our directors and general office expenses. On March 23, 2011, our Board of Directors granted our directors, Dr. Horst A. Schmid, Mr. Said Arrata, Mr. Satya Das, Mr. David Roff, Mr. Curtis James Sparrow and Mr. Malik Youyou, options to purchase 450,000 shares of common stock at an exercise price of $0.14 per common share, 150,000 vesting immediately and the remaining vesting one-third on March 23, 2012, and one-third on March 23, 2013, with an expiration date of March 23, 2016.
For the three months ended March 31, 2012, depreciation and accretion expense decreased by $7,687 compared to the three months ended March 31, 2011, due to the depreciating value of our assets.
For the six months ended March 31, 2012, depreciation and accretion expense decreased by $17,270 compared to the six months ended March 31, 2011, which was due to the depreciating value of our assets. Depreciation expense is computed using the declining balance method over the estimated useful life of the asset. In compliance with our accounting policy, only half of the depreciation is taken in the year of acquisition. No significant asset purchases were made in the six months ended March 31, 2012.
For the three months ended March 31, 2012, rental and other income increased by $7,486 compared to the three months ended March 31, 2011, which was primarily due to an increase in income earned from subleasing a portion of our office space.
For the six months ended March 31, 2012, rental and other income increased by $22,589 compared to the six months ended March 31, 2011, which was primarily due to an increase in income earned from subleasing a portion of our office space.
For the three months ended March 31, 2012, interest income increased by $279 compared to the three months ended March 31, 2011, which was primarily due to an increase in interest income received from our cash held in banks.
For the six months ended March 31, 2012, interest income increased by $763 compared to the six months ended March 31, 2011, which was primarily due to an increase in interest income received from our cash held in banks.
As a result of the above transactions, our net loss and comprehensive loss from operations for the three months ended March 31, 2012 decreased by $162,635 compared to the three months ended March 31, 2011. As discussed above, this decrease was due primarily to a decrease in share-based compensation charged to expense and a decrease in general office expenses.
As a result of the above transactions, our net loss and comprehensive loss from operations for the six months ended March 31, 2012 decreased by $101,537 compared to the six months ended March 31, 2011. As discussed above, this decrease was due primarily to a decrease in share-based compensation charged to expense and a decrease in general office expenses.
Operations
Currently we have in place joint operating agreements with two other joint interest partners to manage our joint oil sands leases, which are all based on the 1990 Canadian Association of Petroleum Landmen (“CAPL”) Operating Procedure. Under these agreements our joint oil sands leases were evaluated seismically, geologically and by drilling to establish the continuity and the distribution of the crude bituminous-bearing Bluesky reservoir zone across our joint lands.
During our winter drilling season of 2008/2009 we successfully completed a drilling program and met our objectives by drilling six vertical wells, three of which were drilled on our oil sands permit in order to provide technical data to support the required Alberta Department of Energy regulation to convert our 5-year oil sands permit into a 15-year primary lease. The other three wells were drilled further to the North of any of our existing wells confirming the continuation of the main reservoir trend to the northwest. These wells were drilled to a depth of approximately 700 meters each. Along with the acquisition of road infrastructure on our properties, we acquired a well on our oil sands lease that was previously drilled and cased for heavy oil production in the Bluesky reservoir zone by an unrelated third party. In addition, we have a 40% working interest in three horizontal wells, which were previously drilled by our former farmout partner and are pending further evaluation and the development of an exploitation plan with our joint interest partner. All of our exploratory wells were logged, cored and analyzed by independent expert service providers.
In September 2009, we submitted an application to the Energy Resources Conservation Board (“ERCB”) for a commercial bitumen recovery scheme to evaluate one of our wells for potential development using Cyclical Steam Stimulation (“CSS”). Over a year later in October 2010, this application was approved by the ERCB. We are putting together a team of reservoir, drilling and completions engineers, along with project management consultants to assist us in the development of our pilot project using in-situ recovery technology. The CSS process involves steam injection into a well for a period of up to 60 days, potentially a “soaking” period of up to 5 days, followed by production of heavy oil for up to 60 days or more. This CSS thermal recovery scheme is not only for the production of heavy oil from the Bluesky reservoir zone of our Sawn Lake project but it will also aid in quantifying proven and probable reserves of oil.
| 18 |
In July 2010 and June 2011, it was determined through two separate independent reservoir engineering firms that our exploratory wells have found sufficient quantities of heavy oil in place to justify the completion of our wells for future production. It was also confirmed that our properties are suitable for employing thermal recovery methods on them. In addition, another hydrocarbon bearing zone was identified up-hole from the Bluesky reservoir zone presently being concentrated on by our Company. This secondary heavy oil zone is in the Peace River formation. We intend to continue the development of the larger Bluesky reservoir and at the same time we intend to evaluate this newly discovered reservoir by coring future wells where they intersect this zone.
In December 2010 and January 2011, two separate independent reservoir engineering firms prepared National Instrument 51-101 (a Canadian evaluation engineering standard) compliant resource appraisal reports for one of our joint venture partners. These reports evaluated the resource of some of our Sawn Lake joint properties and included an economic evaluation of the oil sands leases in the Sawn Lake area based on using thermal recovery to exploit the resource.
In 2011, we evaluated the options for production available to us to determine the preferable course of action for our Sawn Lake project. Drilling on 80% owned lands has opened new avenues for testing and further development of our Sawn Lake project. We have worked with two independent reservoir engineering companies to prepare a reservoir modeling simulation studies to determine the preferred method for us to develop our reservoir. Following these reservoir models and the recommendation of our reservoir engineers, we intend to develop a thermal pilot project on our properties, followed by a commercial expansion project. To further this goal in 2011, we engaged environmental consultants to proceed with the environmental studies mandated by Alberta environmental regulations before we can embark on our proposed thermal pilot project. The development progress of our properties is governed by several factors, such as federal and provincial governmental regulations.
On February 3, 2012, we submitted an application to the ERCB to modify our previously approved in-situ pilot project for a well to test thermal production on our Sawn Lake oil sands leases. The modification seeks to change the vertical CSS earlier approved, into a pilot project with test wells that use a horizontal application of CSS.
On April 16, 2012, we received a reserves report as of December 31, 2011 from DeGolyer & MacNaughton Canada Limited (“DeGolyer”) an independent third party reservoir engineering firm, the report estimated the heavy oil reserves from the working interests held by our subsidiaries in the Peace River Oil Sands area of Alberta. DeGolyer estimated and assigned probable and possible reserves on the north half square mile of land located on section 10-92-13W5 designated for our CSS pilot project. This half square mile of land covers 316 gross acres (128 gross hectares) of land. DeGolyer has estimated that in that portion alone there are probable reserves of 7,806,000 barrels of heavy oil and probable plus possible reserves of 9,370,000 barrels attributable to our working interests before adjusting for any Provincial or potential royalties. These estimated probable plus possible reserves are classified as undeveloped at this time. Proved reserves cannot be assigned until production begins.
Proved Reserves are those quantities of oil and gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward, from known reservoirs, under existing economic conditions, operating methods, and governmental regulations.
Probable Reserves are those additional reserves that are less certain to be recovered than proved reserves but which, together with proved reserves, are as likely as not to be recovered.
Possible Reserves are those additional reserves that are less certain to be recovered than probable reserves.
Statements of reserves are only estimates and may not correspond to the ultimate quantities of oil discovered.
We currently have an 80% working interest in 56 contiguous sections on seven oil sands leases where we are the operator and a 40% working interest in an additional 12 contiguous sections on two oil sands leases in the Peace River oil sands area of Alberta. These nine oil sands leases cover 43,015 gross acres (17,408 gross hectares) with Deep Well having 31,376 net acres (12,698 net hectares).
Our proposed pilot project will be located on the north half of section 10-92-13W5 which has good road access on most of Penn West Petroleum Ltd.’s (“Penn West”) hard packed roads. The proposed pilot project location is approximately 1.4 kilometers away from the nearest Penn West road. We intend to upgrade our existing winter road to section 10-92-13W5 to an all-weather road. We also intend to acquire the remaining road and build it as an all-weather road up to the proposed pilot project site. We plan to upgrade and or build the all-weather road to our proposed pilot project well site location during the initial phase of the project development.
| 19 |
Liquidity and Capital Resources
As of March 31, 2012, our total assets were $14,202,252. The decrease in our total assets from September 30, 2011 was primarily due to cash used to pay for costs relating to our CSS pilot project, which included engineering fees to evaluate our properties and general office expenses. Our total liabilities as of March 31, 2012 were $754,317. The increase in our total liabilities from September 30, 2011 was primarily due to an increase in accounts payable relating to fees we accrued that were payable to executive officers of our Company. As of March 31, 2012, our working capital was $20,603.
Our working capital (current liabilities subtracted from current assets) as of March 31, 2012 and September 31, 2011 was as follows:
| Six Months | ||||||||
| Ended | Year Ended | |||||||
| March 31, 2012 | September 30, 2011 | |||||||
| Current Assets | $ | 362,528 | $ | 809,313 | ||||
| Current Liabilities | 341,925 | 221,564 | ||||||
| Working Capital | $ | 20,603 | $ | 587,749 | ||||
As reported on our Consolidated Statement of Cash Flows under “Operating Activities”, for the six months ended March 31, 2012, our net cash used in operating activities was $392,126 compared to $409,353 for the six months ended March 31, 2011. This was a decrease of $17,227. The decrease was primarily due to an increase in rental income and a decrease in our daily general office expenses. We did not pay any director fees for this quarter.
As reported on our Consolidated Statement of Cash Flows under “Investing Activities”, we had a decrease of $403,680 on investment in our oil and gas properties for the six months ended March 31, 2012 compared to the six months ended March 31, 2011, which was primarily due to a decline in our field operations. For the quarter ended March 31, 2012, no additional money was required to be deposited with the ERCB to be held in trust. These investments are required by the ERCB to ensure there are sufficient future cash to meet the expected future asset retirement obligations, and are restricted for this purpose.
As reported on our Consolidated Statement of Cash Flows under “Financing Activities”, we did not enter into any agreements for cash proceeds from the issuance of our common stock for the six months ended March 31, 2012. For the six months ended March 31, 2011, we received cash proceeds from two private placements we completed in November 2010, in connection with which we issued an aggregate of 29,285,713 shares of common stock to two investors, at a price of $0.07 per common share, for total gross cash proceeds of $2,050,000, of which we had previously received a $48,555 deposit that was recorded in our consolidated financial statements in respect of our fiscal year ended September 30, 2010.
Our cash and cash equivalents as of March 31, 2012 was $277,316 compared to $1,231,486 as of March 31, 2011. This decrease was primarily due to cash used to pay for costs relating to our CSS pilot project, which included engineering fees to evaluate our properties and general office expenses. Since March 10, 2005, we have financed our business operations through a loan, fees derived from the farmout of some of our lands, private offerings of our common stock and other securities, and the sale of our common stock upon the exercise of certain warrants, realizing gross proceeds of approximately $21.6 million in cash. In some of these offerings, we sold units comprised of common stock and warrants to purchase additional common stock, and as a result of these offerings, we have an aggregate of 30,324,513 warrants outstanding as of March 31, 2012 with exercise prices ranging from $0.105 to $1.20 per share and are exercisable into 30,324,513 common shares of our Company stock. The warrants expiration dates range from June 22, 2012 to November 9, 2013. If all of these warrants are exercised we may realize aggregate cash proceeds of approximately $4.3 million. However, the warrant holders have complete discretion as to when and if the warrants are exercised before they expire and we cannot guarantee that the warrant holders will exercise any of the warrants.
For our short-term operations, and as requested by Dr. Horst A. Schmid, we are not paying out the accrued consulting fee of $207,433 to Portwest Investments Ltd, a company owned 100% by Dr. Horst A. Schmid, for providing services to Deep Well as Chief Executive Officer and President. By removing that amount from the current liabilities, we have a working capital of $228,036 which can support our daily operations.
For our long-term operations we anticipate that, among other alternatives, we may raise funds during the next 24 months through sales of our equity securities. We also note that if we issue more shares of our common stock, our stockholders may experience dilution in the percentage of their ownership of our common stock. We may not be able to raise sufficient funding from stock sales for long-term operations and if so, we may be forced to delay our business plans until adequate funding is obtained. We believe debt financing will not be an alternative for funding our operations, as we are an exploration stage company and due to the risky nature of our business.
| 20 |
Off-Balance Sheet Arrangements
We do not have any off-balance sheet arrangements.
Cautionary Note Regarding Forward-Looking Statements
This quarterly report on Form 10-Q, including all referenced exhibits, contains “forward-looking statements” within the meaning of the United States federal securities laws. All statements other than statements of historical facts included or incorporated by reference in this report, including, without limitation, statements regarding our future financial position, business strategy, projected costs and plans and objectives of management for future operations, are forward-looking statements. The words "may," "believe," “intend,” "will," "anticipate," "expect," "estimate," "project," "future," “plan,” “strategy,” or “continue,” and other expressions that are predictions of or indicate future events and trends and that do not relate to historical matters, often identify forward-looking statements. For these statements, Deep Well claims the protection of the safe harbor for forward-looking statements contained in the Private Securities Litigation Reform Act of 1995. The forward-looking statements in this quarterly report on Form 10-Q include, among others, statements with respect to:
| · | our current business strategy; |
| · | our future financial position and projected costs; |
| · | our projected sources and uses of cash; |
| · | our plan for future development and operations; |
| · | our drilling and testing plans; |
| · | our proposed enhanced oil recovery test well project; |
| · | the sufficiency of our capital in order to execute our business plan; |
| · | reserves and resource estimates; |
| · | the timing and sources of our future funding; and |
| · | the timing for receipt of regulatory approvals. |
Reliance should not be placed on forward-looking statements because they involve known and unknown risks, uncertainties, and other factors, which may cause the actual results to differ materially from the anticipated future results expressed or implied by such forward-looking statements. Factors that could cause actual results to differ materially from those set forward in the forward-looking statements include, but are not limited to:
| · | changes in general business or economic conditions; |
| · | changes in legislation or regulation that affect our business; |
| · | our ability to obtain necessary regulatory approvals and permits; |
| · | our ability to receive approvals from the ERCB for additional tests to further evaluate the wells on our lands; |
| · | opposition to our regulatory requests by various third parties; |
| · | actions of aboriginals, environmental activists and other industrial disturbances; |
| · | the costs of environmental reclamation of our lands; |
| · | availability of labor or materials or increases in their costs; |
| · | the availability of sufficient capital to finance our business plans on terms satisfactory to us; |
| · | adverse weather conditions and natural disasters; |
| · | risks associated with increased insurance costs or unavailability of adequate coverage; |
| · | volatility of oil and natural gas prices; |
| · | competition; |
| · | changes in labor, equipment and capital costs; |
| · | future acquisitions or strategic partnerships; |
| · | the risks and costs inherent in litigation; |
| · | imprecision in estimates of reserves, resources and recoverable quantities of oil and natural gas; |
| · | product supply and demand; |
| · | fluctuations in currency and interest rates; and |
| · | the additional risks and uncertainties, many of which are beyond our control, referred to elsewhere in this quarterly report on Form 10-Q and in our other SEC filings. |
The preceding bullets outline some of the risks and uncertainties that may affect our forward-looking statements. For a full description of risks and uncertainties, see the sections entitled “Risk Factors” and “Environmental Laws and Regulations” of our annual report on Form 10-K for the fiscal year ended September 30, 2011, filed with the SEC on December 29, 2011. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual results may vary materially from those anticipated, believed, estimated or expected. Any forward looking statement speaks only as of the date on which it was made and, except as required by law, we disclaim any obligation to publicly update any forward-looking statements, whether as a result of new information, future events or otherwise. However, any further disclosures made on related subjects in subsequent reports on Forms 10-K, 10-Q, 8-K and any other SEC filing or amendments thereto should be consulted.
| 21 |
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
We are a smaller reporting company as defined by Rule 12b-2 under the Exchange Act and therefore we are not required to provide the information required under this item.
ITEM 4. CONTROLS AND PROCEDURES
Disclosure Controls and Procedures
As of the end of our fiscal quarter ended March 31, 2012, an evaluation of the effectiveness of our “disclosure controls and procedures” (as such term is defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934) was carried out under the supervision and with the participation of our principal executive officer and principal financial officer. Based upon that evaluation, our principal executive officer and principal financial officer have concluded that as of the end of that quarter, our disclosure controls and procedures were effective to ensure that information required to be disclosed by us in reports that we file or submit under the Exchange Act is (i) recorded, processed, summarized and reported within the time periods specified in Securities and Exchange Commission rules and forms and (ii) accumulated and communicated to our management, including our principal executive officer and principal financial officer, to allow timely decisions regarding required disclosure.
Changes In Internal Control Over Financial Reporting
During the fiscal quarter ended March 31, 2012, there were no changes in our internal control over financial reporting that materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
PART II. OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
There have been no new material developments in our litigation proceedings from those disclosed in our annual report on Form 10-K for the fiscal year ended September 30, 2011, filed with the Securities and Exchange Commission on December 29, 2011.
ITEM 1A. RISK FACTORS
Although we are a smaller reporting company, as defined by Rule 12b-2 under the Exchange Act, and therefore not required to provide the information required under this item, there have been no material changes in our risk factors from those disclosed in our annual report on Form 10-K for the fiscal year ended September 30, 2011, filed with SEC on December 29, 2011, other than the following:
Our reserves data and any future net revenue are only estimates and are uncertain. There are numerous uncertainties inherent in estimating quantities of crude oil, oil sands and natural gas reserves and their estimated values, including many factors beyond the Company’s control. The reserves data disclosed in this report represent estimates only and may prove to be inaccurate because of these uncertainties. In general, estimates of economically recoverable crude oil, oil sands and natural gas reserves and the future net cash flows there from are based upon a number of variable factors and assumptions, such as product prices, future operating and capital costs, availability of future capital, historical production from the properties and the assumed effects of regulation by governmental agencies, including with respect to royalty payments, all of which may vary considerably from actual results. All such estimates are to some degree uncertain, and classifications of reserves are only attempts to define the degree of uncertainty involved.
For those reasons, estimates of the economically recoverable crude oil, oil sands and natural gas reserves attributable to any particular group of properties, classification of such reserves based on risk of recovery and estimates of future net revenues expected there from, prepared by different engineers or by the same engineers at different times, may vary substantially. Accordingly, reserve estimates may be subject to downward or upward adjustment. Reservoir engineering is a subjective and inexact process of estimating underground accumulations of crude oil, oil sands and natural gas that cannot be measured in an exact manner.
Estimates with respect to reserves that may be developed and produced in the future are often based upon volumetric calculations and upon analogy to similar types of reserves, rather than upon actual production history. Estimates based on these methods generally are less reliable than those based on actual production history. Subsequent evaluation of the same reserves based upon production history will result in variations, which may be material, in the estimated reserves.
ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
None.
ITEM 3. DEFAULTS UPON SENIOR SECURITIES
None.
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable.
ITEM 5. OTHER INFORMATION
Information to be Reported on Form 8-K
We reported all information that was required to be disclosed on Form 8-K during the period covered by this quarterly report on Form 10-Q.
| 22 |
ITEM 6. EXHIBITS
| Exhibit No. | Description | |||
| 23.1 | Consent of DeGolyer and MacNaughton Canada Limited, independent petroleum engineers. | |||
| 31.1 | Certification of President and Chief Executive Officer pursuant to Rule 13a-14(a). | |||
| 31.2 | Certification of Chief Financial Officer pursuant to Rule 13a-14(a). | |||
| 32.1 | Certification of President and Chief Executive Officer pursuant to 18 U.S.C. Section 1350. | |||
| 32.2 | Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350. | |||
| 101 | Interactive Data Files | |||
| 23 |
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
| DEEP WELL OIL & GAS, INC. | |||
| By | /s/ Horst A. Schmid | ||
| Dr. Horst A. Schmid | |||
| Chief Executive Officer and President | |||
| (Principal Executive Officer) | |||
| Date | May 15, 2012 | ||
| By | /s/ Curtis Sparrow | ||
| Mr. Curtis James Sparrow | |||
| Chief Financial Officer | |||
| (Principal Financial and Accounting Officer) | |||
| Date | May 15, 2012 | ||
| 24 |