UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-KSB
(Mark One)
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ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 | |
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For the fiscal year ended December 31, 2005 | ||
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TRANSITION REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the transition period from otoo
Commission file number 333-93383
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SNRG Corporation (Formerly Texen Oil & Gas, Inc.) | ||
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Nevada |
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90-0082485 |
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14300 N Northsight Blvd, Suite 227 |
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85260 |
Issuer's telephone number (480) 991-2040
Securities registered pursuant to Section 12(b) of the Act:
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Title of each class |
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Name of each exchange on which registered |
Securities registered pursuant to Section 12(g) of the Act:
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Common Stock, par value $0.00001 |
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Check whether the issuer is not required to file reports pursuant to Section 13 or 15(d) of the Exchange Act. | ||||
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(Check one): |
Yes [ |
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No x. |
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Note: Checking the box above will not relieve any registrant required to file reports pursuant to Section 13 or 15(d) of the Exchange act from their obligations under those Sections.
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
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Yes o |
No [X ] |
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Check whether the Issuer (1) filed all reports required to be filed by Section 13 or 15(d) of the Exchange Act during the past 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.
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Yes x |
No o |
Check if there is no disclosure of delinquent filers in response to Item 405 of Regulation S-B is not contained in this form, and no disclosure will be contained, to the best of registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-KSB or any amendment to this Form 10-KSB. o
State Issuer's revenues for its most recent fiscal year: $484,480
State the aggregate market value of the voting and non-voting common equity held by non-affiliates computed by reference to the price at which the common equity was sold, or the average bid and asked price of such common equity, as of a specified date within the past 60 days:
121,055,202 common shares at $0.18(1) = $21,789,936
(1) Average of bid and ask closing prices on April 20, 2006
(APPLICABLE ONLY TO CORPORATE REGISTRANTS)
State the number of shares outstanding of each of the Issuer's classes of common stock, as of the latest practicable date.
184,220,866 common shares issued and outstanding as of March 31, 2006
DOCUMENTS INCORPORATED BY REFERENCE
None.
Transitional Small Business Disclosure Format (Check one): Yes o No x
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PART I
Item 1. Description of Business.
This annual report contains forward-looking statements as that term is defined in the Private Securities Litigation Reform Act of 1995. These statements relate to future events or our future financial performance. In some cases, you can identify forward-looking statements by terminology such as "may", "should", "expects", "plans", "anticipates", "believes", "estimates", "predicts", "potential" or "continue" or the negative of these terms or other comparable terminology. These statements are only predictions and involve known and unknown risks, uncertainties and other factors, including the risks in the section entitled "Risk Factors", that may cause our or our industry's actual results, levels of activity, performance or achievements to be materially different from any future results, levels of activity, performance or achievements expressed or implied by these forward-looking statements.
Although we believe that the expectations reflected in the forward-looking statements are reasonable, we cannot guarantee future results, levels of activity, performance or achievements. Except as required by applicable law, including the securities laws of the United States, we do not intend to update any of the forward-looking statements to conform these statements to actual results.
Our financial statements are stated in United States Dollars (US$) and are prepared in accordance with United States Generally Accepted Accounting Principles.
In this annual report, unless otherwise specified, all dollar amounts are expressed in United States dollars. All references to "CDN$" refer to Canadian dollars and all references to "common shares" refer to the common shares in our capital stock.
As used in this annual report, the terms "we", "us", "our", and "SNRG" mean SNRG Corporation, unless otherwise indicated.
Glossary of Terms
We are engaged in the business of exploring for and producing oil and natural gas. Oil and gas exploration is a specialized industry. Many of the terms used to describe our business are unique to the oil and gas industry. The following glossary clarifies certain of these terms that may be encountered while reading this report:
"Acquisition costs of properties" means the costs incurred to obtain rights to production of oil and gas. These costs include the costs of acquiring oil and gas leases and other interests. These costs also include lease costs, finder's fees, brokerage fees, title costs, legal costs, recording costs, options to purchase or lease interests and any other costs associated with the acquisitions of an interest in current or possible production.
"Area of mutual interest" means, generally, an agreed upon area of land, varying in size, included and described in an oil and gas exploration agreement which participants agree will be subject to rights of first refusal as among themselves, such that any participant acquiring any minerals, royalty, overriding royalty, oil and gas leasehold estates or similar interests in the designated area, is obligated to offer the other participants the opportunity to purchase their agreed upon percentage share of the interest so acquired on the same basis and cost as purchased by the acquiring participant. If the other participants, after a specific time period, elect not to acquire their pro-rata share, the acquiring participant is typically then free to retain or sell such interests.
"Back-in interests" also referred to as a carried interest, involve the transfer of interest in a property with provision to the transferor to receive a reversionary interest in the property after the occurrence of certain events.
"Bbl" means barrel, 42 U.S. gallons liquid volume, used in this annual report in reference to crude oil or other liquid hydrocarbons.
"Bcf" means billion cubic feet, used in this annual report in reference to gaseous hydrocarbons.
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"BcfE" means billions of cubic feet of gas equivalent, determined using the ratio of six thousand cubic feet of gas to one barrel of oil, condensate or gas liquids.
"Casing point" means the point in time at which an election is made by participants in a well whether to proceed with an attempt to complete the well as a producer or to plug and abandon the well as a non-commercial dry hole. The election is generally made after a well has been drilled to its objective depth and an evaluation has been made from drill cutting samples, well logs, cores, drill stem tests and other methods. If an affirmative election is made to complete the well for production, production casing is then generally cemented in the hole and completion operations are then commenced.
"Development costs" are costs incurred to drill, equip, or obtain access to proved reserves. They include costs of drilling and equipment necessary to get products to the point of sale and may entail on-site processing.
"Exploration costs" are costs incurred, either before or after the acquisition of a property, to identify areas that may have potential reserves, to examine specific areas considered to have potential reserves, to drill test wells, and drill exploratory wells. Exploratory wells are wells drilled in unproven areas. The identification of properties and examination of specific areas will typically include geological and geophysical costs, also referred to as G&G, which include topological studies, geographical and geophysical studies, and costs to obtain access to properties under study. Depreciation of support equipment, and the costs of carrying unproved acreage, delay rentals, ad valorem property taxes, title defense costs, and lease or land record maintenance are also classified as exploratory costs. "Farmout" involves an entity's assignment of all or a part of its interest in or lease of a property in exchange for consideration such as a royalty.
"Future net revenue, before income taxes" means an estimate of future net revenue from a property, based on the production of the proven reserves of oil and natural gas believed to be recoverable at a specified date, after deducting production and ad valorem taxes, future capital costs and operating expenses, before deducting income taxes. Future net revenue, before income taxes, should not be construed as being the fair market value of the property.
"Future net revenue, net of income taxes" means an estimate of future net revenue from a property, based on the proven reserves of oil and natural gas believed to be recoverable at a specified date, after deducting production and ad valorem taxes, future capital costs and operating expenses, net of income taxes. Future net revenues, net of income taxes, should not be construed as being the fair market value of the property.
"Gross" oil or gas well or "gross" acre is a well or acre in which we have a working interest.
"Mcf" means thousand cubic feet, used in this annual report to refer to gaseous hydrocarbons.
"McfE" means thousands of cubic feet of gas equivalent, determined using the ratio of six thousand cubic feet of gas to one barrel of oil, condensate or gas liquids.
"MMcf" means million cubic feet, used in this annual report to refer to gaseous hydrocarbons.
"MBbl" means thousand barrels, used in this annual report to refer to crude oil or other liquid hydrocarbons.
"Net" oil and gas wells or "net" acres are determined by multiplying "gross" wells or acres by our percentage interest in such wells or acres.
"Oil and gas lease" or "Lease" means an agreement between a mineral owner, the lessor, and a lessee which conveys the right to the lessee to explore for and produce oil and gas from the leased lands. Oil and gas leases usually have a primary term during which the lessee must establish production of oil and or gas. If production is established within the primary term, the term of the lease generally continues in effect so long as production occurs on the lease. Leases generally provide for a royalty to be paid to the lessor from the gross proceeds from the sale of production.
"Overpressured reservoir" are reservoirs subject to abnormally high pressure as a result of certain types of subsurface conditions.
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"Present value of future net revenue, before income taxes" means future net revenue, before income taxes, discounted at an annual rate of 10% to determine their "present value." The present value is shown to indicate the effect of time on the value of the revenue stream and should not be construed as being the fair market value of the properties.
"Present value of future net revenue, net of income taxes" means future net revenue, net of income taxes discounted at an annual rate of 10% to determine their "present value." The present value is shown to indicate the effect of time on the value of the revenue stream and should not be construed as being the fair market value of the properties. Also known as the "Standardized Measure of Discounted Future Net Cash Flows" if SEC pricing assumptions are used.
"Production costs" means operating expenses and severance and ad valorem taxes on oil and gas production.
"Prospect" means a location where both geological and economical conditions favor drilling a well.
"Proved oil and gas reserves" are the estimated quantities of crude oil, natural gas and natural gas liquids which geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions, i.e. prices and costs as of the date the estimate is made. Prices include consideration of changes in existing prices provided only by contractual arrangements, but not on escalations based upon future conditions. Reservoirs are considered proved if economic recovery by production is supported by either actual production or conclusive formation test. The area of a reservoir considered proved includes (A) that portion delineated by drilling and defined by gas-oil and/or oil-water contacts, if any, and (B) the immediately adjoining portions not yet drilled, but which can reasonably be judged as economically productive on the basis of available geological and engineering data. In the absence of information on fluid contacts the lowest known structural occurrence of hydrocarbons controls the lower proved limit of the reservoir.
"Proved developed oil and gas reserves" are those proved reserves that can be expected to be recovered through existing wells with existing equipment and operating methods. Additional oil and gas reserves expected to be obtained through the application of fluid injection or other improved secondary or tertiary recovery techniques for supplementing the natural forces and mechanisms of primary recovery are included as "proved developed reserves" only after testing by a pilot project or after the operation of an installed recovery program has confirmed through production response that increased recovery will be achieved. "Proved undeveloped oil and gas reserves" are those proved reserves that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required. Reserves on undrilled acreage are limited to those drilling units offsetting productive units that are reasonably certain of production when drilled. Proved reserves for other undrilled units are claimed only where it can be demonstrated with reasonable certainty that there is continuity of production from the existing productive formation. Estimates for proved undeveloped reserves attributable to any acreage do not include production for which an application of fluid injection or other improved recovery technique is required or contemplated, unless such techniques have been proved effective by actual tests in the area and in the same reservoir. "Reserve target" see "Prospect."
"Royalty interest" is a right to oil, gas, or other minerals that are not burdened by the costs to develop or operate the related property. "Seismic option" generally means an agreement in which the mineral owner grants the right to acquire seismic data on the subject lands and grants an option to acquire an oil and gas lease on the lands at a predetermined price.
"Trend" means a geographical area along which a petroleum pay occurs (fairway).
"Working interest" is an interest in an oil and gas property that is burdened with the costs of development and operation of the property.
Disclosure Regarding Forward-Looking Statements: Included in this report are 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. All statements, other than statements of historical facts, included in this Form 10-KSB which address activities, events or developments which we expect or anticipate will or may occur in the future are forward-looking statements.
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Business Development During Last Three Years
General Overview
We are an independent oil and gas company engaged in the exploration, development, production and acquisition of natural gas and crude oil. We conduct our operations through subsidiary corporations. We currently lease approximately 4,211 acres of crude oil and natural gas properties in Victoria, DeWitt and Waller Counties, in Texas. We have entered into an agreement to acquire a 50% interest in approximately 30,000 acres in Saskatchewan Canada. We are focused on acquiring, developing and producing proven, developed and underdeveloped reserves, which offer long-term value for our company.
Corporate History
Our company, SNRG Corporation, was incorporated in the State of Nevada on September 2, 1999, under the name Palal Mining Corporation. We changed our name from Palal Mining Corporation to Texen Oil & Gas, Inc. on May 15, 2002 and changed its name again to SNRG Corporation on July 22, 2005 upon obtaining approval from its shareholders and filing an amendment to its articles of incorporation. We shall be referred to as "SNRG" or “SNRG Corporation” even though the events described may have occurred while our name was Palal Mining Corporation or Texen Oil & Gas, Inc. Our fiscal year end is December 31.
We received approval from our shareholders in June 2005 for an increase in the authorized common share capital from 100,000,000 million to 500,000,000 and for the authorization of 300,000,000 preferred shares.
Our authorized share capital consists of five hundred million (500,000,000) shares of common stock with a par value of $0.00001 and 300,000,000 preferred shares with no par value.
We have not been involved in any bankruptcy, receivership or similar proceeding.
Corporate Subsidiaries
Texas Brookshire Partners, Inc.
Texas Brookshire Partners, Inc., one of our wholly owned subsidiary corporations is engaged in the business of purchasing, developing and operating oil and gas leases in the Brookshire Dome of Waller County, Texas, and owns a 96.4% working interest ownership in and to approximately 24 gross leasehold acres and 16 net acres leasehold acres. The current working interest ownership position owns various interests in 18 wells which have been drilled to date and one salt water injection well. Current production from these properties over the last 12 months has averaged approximately 17 barrels of oil per day.
Texas Gohlke Partners, Inc.
Texas Gohlke Partners, Inc. is another of our wholly owned subsidiary corporations and is engaged in the business of purchasing, developing and operating oil and gas leases in the Helen Gohlke Field located in Victoria and DeWitt Counties, Texas and owns a 100% working interest ownership, 70% net revenue interest in and to approximately 4,346.7 gross leasehold acres. There are currently four producing wells on the property, twenty-two shut-in wells and two salt water disposal wells. Current production from these properties over the last 12 months has averaged approximately 6 barrels of oil per day and 85 mcf per day.
Inactive Subsidiaries: Brookshire Drilling Service, LLC, Yegua, Inc., BWC Minerals, L.L.C.
We own; 100% of the membership and management interests of Brookshire Drilling Service LLC, a Texas limited liability Company, 100% of the outstanding common stock of Yegua, Inc and 100% of the membership interests of BWC Minerals, L.L.C. These subsidiaries are all dormant and have no assets. We do not intend to reactivate or maintain corporate filings on these entities.
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Our Current Business
Pursuant to acquisitions made in 2002, our assets consist of a 77.75% working interest ownership in about 24 gross leasehold acres in the Brookshire Salt Dome in Warren County Texas and a 100% working interest ownership in approximately 4,187 gross leasehold acres in Dewitt and Victoria Counties, Texas. The current holdings have limited qualified reserves and require substantial maintenance and work-overs to increase production.
We have entered into an agreement to acquire a 50% interest in approximately 30,000 acres in Saskatchewan, Canada from Arapahoe Energy Corporation. We announced our intention to establish a Canadian subsidiary and to expand our holdings in the Western Canadian Basin.
Business Strategy
Our goal is to maximize share value through profitable operations and through growth in our oil and gas reserves. We believe this can be achieved through the exploration and development of our existing prospect inventory located in Texas and by acquisition of new oil and gas leasehold interests in other locations including Canada. We intend to supplement our exploration and development program with a well work-over program targeting certain of our existing properties that have potential for increased production. We intend to implement an acquisition program targeting properties that enhance our reserve and production positions. We plan for additional capital expenditures which are subject to our company being successful in raising additional capital.
We have conducted minimum operations on our existing properties during 2005 with an objective of maintaining our leases while developing a plan for the redevelopment of the properties. Exploration and development activities have higher associated risks than those associated with acquisitions of producing properties, however the acquisition of producing properties is cost prohibitive in the current marketplace and accordingly we will focus on early stage exploration and development properties.
Two of the largest risks associated with exploration and development activities are: geological risks (the subject property does not hold recoverable oil or natural gas); and the risk of project cost overruns.
We utilize available advanced technology, such as 3-dimensional seismic modeling to further reduce risk and enhance our success rates. We believe that the availability of economical 3-dimensional seismic surveys fundamentally changed the risk profile of oil and gas exploration. Recognizing this, we will aggressively seek to acquire significant acreage blocks in selected areas for targeted 3-dimensional seismic surveys.
Oil and Gas Estimates and Producing Activities
The following table sets forth information as to our net proved and proved developed reserves as of December 31, 2005 and as of December 31, 2004 and the present value as of such dates (based on an annual discount rate of 10%) of the estimated future net revenues from the production and sales of those reserves.
We do not currently believe that the calculation of estimated future net revenues using the assumptions prescribed by the Securities Exchange and Exchange Commission guidelines and generally described below is representative of the true value of future net revenues from our proved reserves. The future prices received by our company for the sales of our production may be higher or lower than the prices used in calculating the estimates of future net revenues, and the operating costs and other costs relating to such production may also increase or decrease from existing levels.
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Oil and Gas Estimates |
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As of December 31, 2005 |
As of December 31, 2004 |
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Total Proved Reserves |
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Oil, condensate and natural gas liquids (Bbls) |
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Located in Brookshire |
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37,943 |
41,506 | ||
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Located in Gohlke |
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19,733 |
21,957 | ||
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Total Company |
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57,676 |
63,463 | |
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Natural Gas (Mcf) |
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Located in Brookshire |
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0 |
0 | ||
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Located in Gohlke |
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538,254 |
560.056 | ||
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Total Company |
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538,254 |
209,800 | |
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Present Value of estimated future net revenues, before income taxes | ||||||
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Located in Brookshire |
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342,997 |
537,638 | ||
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Located in Gohlke |
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1,423,061 |
1,756,521 | ||
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Total Company |
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$1,766,058 |
$2,966,251 | |
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Total Proved Developed Reserves: |
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Oil, condensate and natural gas liquids (Bbls) |
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Located in Brookshire |
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11,469 |
15,032 | ||
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Located in Gohlke |
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0 |
0 | ||
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Total Company |
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11,469 |
15,032 | |
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Natural Gas (Mcf) |
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Located in Brookshire |
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0 |
0 | ||
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Located in Gohlke |
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399,742 |
421,544 | ||
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Total Company |
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399,742 |
421,544 | |
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Present Value of estimated future net revenues, before income taxes | ||||||
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Located in Brookshire |
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0 |
173,058 | ||
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Located in Gohlke |
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258,397 |
591,839 | ||
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Total Company |
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$258,397 |
$764,897 | |
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Expenditure Analysis |
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December 2005 |
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December 2004 | ||
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Undeveloped Leasehold Costs |
$ |
- |
$ |
147,108 | ||
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Producing Properties |
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26,862,514 |
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25,854,207 | ||
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Accumulated depreciation, depletion and amortization |
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(24,649,130) |
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(21,530,926) | ||
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Total capitalized costs |
$ |
2,213,384 |
$ |
4,470,389 | ||
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December 2005 |
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December 2004 | |
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Revenues |
$ |
484,480 |
$ |
329,077 | ||
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EXPENSES |
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Production costs |
419,926 |
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711,762 | ||
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Dry hole costs |
61,666 |
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262,002 | ||
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Depreciation, depletion and amortization |
186,391 |
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541,471 | ||
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Production taxes |
21,096 |
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20,697 | ||
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$ |
689,079 |
$ |
(1,112,163) | |
The standardized measure of discounted future net cash flows:
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December 2005 |
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December 2004 |
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Future cash flows |
$ |
4,880,619 |
$ |
5,365,099 |
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Future development and production costs |
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(2,064,721) |
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(2,484,647) |
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Future income tax expense |
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- |
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- |
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Future net cash flows |
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2,815,898 |
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2,880,452 |
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10% annual discount |
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(281,589) |
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239,118 |
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Standardized measure of discounted future net cash flows |
$ |
2,534,309 |
$ |
2,288,655 |
Future net cash flows were computed using year-end prices and gas to year-end quantities of proved reserves. Future price changes are considered only to the extent provided by contractual arrangements. Estimated future development and production costs are determined by estimating the expenditures to be incurred in developing and producing the proved oil and gas reserves at the end of the year, based on year-end costs and assuming continuation of existing economic conditions. Estimated future income tax expense is calculated by applying year-end statutory tax rates (adjusted for permanent differences and tax credits) to estimated future pretax net cash flows related to proved oil and gas reserves, less the tax basis of the properties involved.
These estimates are furnished and calculated in accordance with requirements of the Financial Accounting Standards Board and the Securities and Exchange Commission, and do not represent management’s assessment of future profitability or future cash flows to Texen. Management’s investments and operating decisions are based on reserves estimated that include proved reserves prescribed by the SEC as well as probable reserves, and on different price and cost assumptions from those used here.
Geological and Geophysical Techniques
Geological interpretation is based upon data recovered from existing oil and gas wells in an area and other sources. Such information is either purchased from the entity that drilled the wells or that becomes public knowledge information through filings required by state agencies. Through analysis of rock types, fossils and the electrical and chemical characteristics of rocks from existing wells, geologists engaged by our company can construct a picture of rock layers in the area and predict possible sites of hydrocarbon accumulation. Well logs available to us facilitate the calculation of an estimate of initial oil or gas volume in place while decline curves from recorded production history facilitate the calculation of remaining proved producing reserves.
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Market for Oil and Gas Production
The market for oil and gas production is regulated by both the state and federal governments. The overall market is mature and with the exception of gas, all producers in a producing region will receive the same price. Purchasers (or “Gatherers”) will typically purchase all crude oil offered for sale at posted field prices which are adjusted for quality difference from the “Benchmark”. Benchmark is the price of Saudi Arabian light crude oil employed as the standard on which OPEC price changes have been based. The purchaser normally picks up the oil at the well site but in some instances there may be deductions for transportation from the well head to the sales point. The purchaser will usually handle all payment disbursements to both the working interest owners and the royalty interest owners. We are a working interest owner and are therefore responsible with other working interest owners if any, for the payment of our proportionate share of the operating expenses of the well. Royalty owners and over-riding royalty owners receive a percentage of gross oil and gas production revenue for a particular lease and are not responsible for the costs of operating the lease. Working interest owners, such as our company, are typically responsible for all lease operating and production expenses.
Gas sales are by contract. Gas purchasers pay well operators 100% of the sale proceeds of gaseous hydrocarbons on or about the 25th of each month for the previous month’s sales. The operator is responsible for all distributions to the working interest and royalty owners. There is no standard price for gas and prices will fluctuate with the seasons and the general market conditions.
Competition
The oil and gas industry is highly competitive. Our competitors and potential competitors include major oil companies and independent producers of varying sizes of which are engaged in the acquisition of producing properties and the exploration and development of prospects. Most of our competitors have greater financial, personnel and other resources than we do and therefore have a greater leverage to use in acquiring prospects, hiring personnel and marketing oil and gas. Accordingly, a high degree of competition in these areas is expected to continue.
Governmental Regulation
The production and sale of oil and gas is subject to regulation by state, federal and local authorities. In most areas there are statutory provisions regulating the production of oil and natural gas under which administrative agencies may set allowable rates of production and promulgate rules in connection with the operation and production of such wells, ascertain and determine the reasonable market demand of oil and gas, and adjust allowable rates with respect thereto.
The sale of liquid hydrocarbons was subject to federal regulation under the Energy Policy and Conservation Act of 1975 which amended various acts, including the Emergency Petroleum Allocation Act of 1973. These regulations and controls included mandatory restrictions upon the prices at which most domestic crude oil and various petroleum products could be sold. All price controls and restrictions on the sale of crude oil at the wellhead have been withdrawn. It is possible, however, that such controls may be re-imposed in the future but when, if ever, such re-imposition might occur and the effect thereof on us cannot be predicted.
The sale of certain categories of natural gas in interstate commerce is subject to regulation under the Natural Gas Act and the Natural Gas Policy Act of 1978. Under the Natural Gas Act and the Natural Gas Policy Act of 1978, a comprehensive set of statutory ceiling prices applies to all first sales of natural gas unless the gas is specifically exempt from regulation (i.e., unless the gas is "deregulated"). Administration and enforcement of the Natural Gas Act and the Natural Gas Policy Act of 1978 ceiling prices are delegated to the Federal Energy Regulatory Commission. In June 1986, the Federal Energy Regulatory Commission issued Order No. 451, which, in general, is designed to provide a higher Natural Gas Act and the Natural Gas Policy Act of 1978 ceiling price for certain vintages of old gas. It is possible, though unlikely, that we may in the future acquire significant amounts of natural gas subject to Natural Gas Act and the Natural Gas Policy Act of 1978 price regulations and/or Federal Energy Regulatory Commission Order No. 451.
Our operations are subject to extensive and continually changing regulation because legislation affecting the oil and natural gas industry is under constant review for amendment and expansion. Many departments and agencies, both
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federal and state, are authorized by statute to issue and have issued rules and regulations binding on the oil and natural gas industry and its individual participants. The failure to comply with such rules and regulations can result in large penalties. The regulatory burden on this industry increases our cost of doing business and, therefore, affects our profitability. However, we do not believe that we are affected in a significantly different way by these regulations than our competitors are affected.
Transportation and Production
Transportation and Sale of Oil and Natural Gas. We can make sales of oil, natural gas and condensate at market prices which are not subject to price controls at this time. Condensates are liquid hydrocarbons recovered at the surface that result from condensation due to reduced pressure or temperature of petroleum hydrocarbons existing initially in a gaseous phase in the reservoir. The price that we receive from the sale of these products is affected by our ability to transport and the cost of transporting these products to market. Under applicable laws, the Federal Energy Regulatory Commission regulates the construction of natural gas pipeline facilities, and the rates for transportation of these products in interstate commerce.
Our possible future sales of natural gas are affected by the availability, terms and cost of pipeline transportation. The price and terms for access to pipeline transportation remain subject to extensive federal and state regulation. Several major regulatory changes have been implemented by Congress and the Federal Energy Regulatory Commission from 1985 to the present. These changes affect the economics of natural gas production, transportation and sales. In addition, the Federal Energy Regulatory Commission is continually proposing and implementing new rules and regulations affecting these segments of the natural gas industry that remain subject to the Federal Energy Regulatory Commission’s jurisdiction. The most notable of these are natural gas transmission companies.
The Federal Energy Regulatory Commission’s more recent proposals may affect the availability of interruptible transportation service on interstate pipelines. These initiatives may also affect the intrastate transportation of gas in some cases. The stated purpose of many of these regulatory changes is to promote competition among the various sectors of the natural gas industry. These initiatives generally reflect more light-handed regulation of the natural gas industry. The ultimate impact of the complex rules and regulations issued by the Federal Energy Regulatory Commission since 1985 cannot be predicted. In addition, some aspects of these regulatory developments have not become final but are still pending judicial and Federal Energy Regulatory Commission final decisions. We cannot predict what further action the Federal Energy Regulatory Commission will take on these matters. However, we do not believe that any action taken will affect us much differently than it would affect other natural gas producers, gatherers and marketers with which we might compete against.
Effective as of January 1, 1995, the Federal Energy Regulatory Commission implemented regulations establishing an indexing system for transportation rates for oil. These regulations could increase the cost of transporting oil to the purchaser. We do not believe that these regulations will affect us any differently than other oil producers and marketers with which we compete with.
Regulation of Drilling and Production. Our proposed drilling and production operations are subject to regulation under a wide range of state and federal statutes, rules, orders and regulations. Among other matters, these statutes and regulations govern:
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* * |
the amounts and types of substances and materials that may be released into the environment, the discharge and disposition of waste materials, the reclamation and abandonment of wells and facility sites, and the remediation of contaminated sites, |
and require:
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* * * |
permits for drilling operations, drilling bonds, and reports concerning operations. |
Texas law contains:
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* * * |
provisions for the unitization or pooling of oil and natural gas properties, the establishment of maximum rates of production from oil and natural gas wells, and the regulation of the spacing, plugging and abandonment of wells. |
Environmental Regulations
General. Our operations are affected by the various state, local and federal environmental laws and regulations, including the:
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Clean Air Act, Oil Pollution Act of 1990, Federal Water Pollution Control Act, Resource Conservation and Recovery Act ("RCRA"), Toxic Substances Control Act, and Comprehensive Environmental Response, Compensation and Liability Act ("CERCLA"). |
these laws and regulations govern the discharge of materials into the environment or the disposal of waste materials, or otherwise relate to the protection of the environment. In particular, the following activities are subject to stringent environmental regulations:
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* * * * |
drilling, development and production operations, activities in connection with storage and transportation of oil and other liquid hydrocarbons, and use of facilities for treating, processing or otherwise handling hydrocarbons and wastes. |
Violations are subject to reporting requirements, civil penalties and criminal sanctions. As with the industry generally, compliance with existing regulations increases our overall cost of business. The increased costs cannot be easily determined. Such areas affected include:
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unit production expenses primarily related to the control and limitation of air emissions and the disposal of produced water, |
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capital costs to drill exploration and development wells resulting from expenses primarily related to the management and disposal of drilling fluids and other oil and natural gas exploration wastes, and |
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capital costs to construct, maintain and upgrade equipment and facilities and remediate, plug and abandon inactive well sites and pits. |
Environmental regulations historically have been subject to frequent change by regulatory authorities. Therefore, we are unable to predict the ongoing cost of compliance with these laws and regulations or the future impact of such regulations on its operations. However, we do not believe that changes to these regulations will have a significant negative affect on our operations.
A discharge of hydrocarbons or hazardous substances into the environment could subject us to substantial expense, including both the cost to comply with applicable regulations pertaining to the clean up of releases of hazardous substances into the environment and claims by neighboring landowners and other third parties for personal injury and property damage. We do not maintain insurance for protection against certain types of environmental liabilities.
The Clean Air Act requires or will require most industrial operations in the United States to incur capital expenditures in order to meet air emission control standards developed by the EPA and state environmental agencies. Although no assurances can be given, we believe the Clean Air Act requirements will not have a material adverse effect on our financial condition or results of operations.
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RCRA is the principal federal statute governing the treatment, storage and disposal of hazardous wastes. RCRA imposes stringent operating requirements, and liability for failure to meet such requirements, on a person who is either:
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a "generator" or "transporter" of hazardous waste, or an "owner" or "operator" of a hazardous waste treatment, storage or disposal facility. |
At present, RCRA includes a statutory exemption that allows oil and natural gas exploration and production wastes to be classified as non-hazardous waste. As a result, we will not be subject to many of RCRA's requirements because its operations will probably generate minimal quantities of hazardous wastes.
CERCLA, also known as “Superfund,” imposes liability, without regard to fault or the legality of the original act, on certain classes of persons that contributed to the release of a “hazardous substance” into the environment. These persons include:
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the “owner” or “operator” of the site where hazardous substances have been released, and companies that disposed or arranged for the disposal of the hazardous substances found at the site. |
CERCLA also authorizes the EPA and, in some instances, third parties to act in response to threats to the public health or the environment and to seek to recover from the responsible classes of persons the costs they incur. In the course of our ordinary operations, we could generate waste that may fall within CERCLA's definition of a “hazardous substance.” As a result, we may be liable under CERCLA or under analogous state laws for all or part of the costs required to clean up sites at which such wastes have been disposed.
Under such law we could be required to:
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remove or remediate previously disposed wastes, including wastes disposed of or released by prior owners or operators, clean up contaminated property, including contaminated groundwater, or perform remedial plugging operations to prevent future contamination. |
We could also be subject to other damage claims by governmental authorities or third parties related to such contamination. The foregoing regulations do not and will not have any material adverse affect upon us.
Research and Development
Our business plan is focused on a strategy for maximizing the long-term exploration and development of oil and gas properties located in the Western Canadian Basin and in the United States.
As of December 31, 2005 we have spent approximately $23,305,895 on our oil and gas properties.
Employees
Currently there are no full time employees and one part-time employee. We do not expect any material changes in the number of employees over the next 12 month period. We do and will continue to outsource contract employment as needed. However, if we are successful in our initial and any subsequent drilling programs we may retain additional employees.
RISK FACTORS
Much of the information included in this annual report includes or is based upon estimates, projections or other "forward-looking statements". Such forward-looking statements include any projections or estimates made by us and our management in connection with our business operations. While these forward-looking statements, and any
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assumptions upon which they are based, are made in good faith and reflect our current judgment regarding the direction of our business, actual results will almost always vary, sometimes materially, from any estimates, predictions, projections, assumptions, or other future performance suggested herein. We undertake no obligation to update forward-looking statements to reflect events or circumstances occurring after the date of such statements.
Such estimates, projections or other "forward-looking statements" involve various risks and uncertainties as outlined below. We caution readers of this annual report that important factors in some cases have affected and, in the future, could materially affect actual results and cause actual results to differ materially from the results expressed in any such estimates, projections or other "forward-looking statements". In evaluating us, our business and any investment in our business, readers should carefully consider the following factors.
We have had negative cash flows from operations.
To date we have had negative cash flows from operations and we have been dependent on sales of our equity securities and debt financing to meet our cash requirements and have incurred losses totalling approximately $31,310,020 as of December 31, 2005. As of December 31, 2005 we had working capital of $190,014. We may not have positive cash flow from operations in the near term. There is no assurance that actual cash requirements will not exceed our estimates. In particular, additional capital may be required in the event that:
- drilling and completion costs for further wells increase beyond our expectations; or
- we encounter greater costs associated with general and administrative expenses or offering costs.
The occurrence of any of the aforementioned events could adversely affect our ability to meet our business plans.
We will depend almost exclusively on outside capital to pay for the continued exploration and development of our properties. Such outside capital may include the sale of additional stock and/or commercial borrowing. Capital may not continue to be available if necessary to meet these continuing development costs or, if the capital is available, that it will be on terms acceptable to us. The issuance of additional equity securities by us would result in a significant dilution in the equity interests of our current stockholders. Obtaining commercial loans, assuming those loans would be available, will increase our liabilities and future cash commitments.
If we are unable to obtain financing in the amounts and on terms deemed acceptable to us, we may be unable to continue our business and as a result may be required to scale back or cease operations for our business, the result of which would be that our stockholders would lose some or all of their investment.
A decline in the price of our common stock could affect our ability to raise further working capital and adversely impact our operations.
A prolonged decline in the price of our common stock could result in a reduction in the liquidity of our common stock and a reduction in our ability to raise capital. Because our operations have been primarily financed through the sale of equity securities, a decline in the price of our common stock could be especially detrimental to our liquidity and our continued operations. Any reduction in our ability to raise equity capital in the future would force us to reallocate funds from other planned uses and would have a significant negative effect on our business plans and operations, including our ability to develop new products and continue our current operations. If our stock price declines, we may not be able to raise additional capital or generate funds from operations sufficient to meet our obligations.
If we issue additional shares in the future this may result in dilution to our existing stockholders.
Our Certificate of Incorporation as amended authorizes the issuance of 500,000,000 shares of common stock and 300,000,000 shares of preferred stock. Our board of directors have the authority to issue additional shares up to the authorized capital stated in the certificate of incorporation. Our board of directors may choose to issue some or all of such shares to acquire one or more businesses or to provide additional financing in the future. The issuance of any such shares may result in a reduction of the book value or market price of the outstanding shares of our common stock. If we do issue any such additional shares, such issuance also will cause a reduction in the proportionate ownership and voting power of all other stockholders. As a result of such dilution, if you acquire shares from the
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selling shareholders, your proportionate ownership interest and voting power will be decreased accordingly. Further, any such issuance may result in a change of control of our corporation.
We have a history of losses and fluctuating operating results.
Since inception through December 31, 2005, we have incurred aggregate losses of approximately $31,310,020. Our loss from operations for the fiscal year ended December 31, 2005 was $706,311. There is no assurance that we will operate profitably or will generate positive cash flow in the future. In addition, our operating results in the future may be subject to significant fluctuations due to many factors not within our control, such as the unpredictability of when customers will purchase our services, the size of customers’ purchases, the demand for our services, and the level of competition and general economic conditions. If we cannot generate positive cash flows in the future, or raise sufficient financing to continue our normal operations, then we may be forced to scale down or even close our operations. Until such time as we generate revenues, we expect an increase in development costs and operating costs. Consequently, we expect to incur operating losses and negative cash flow until our properties enter commercial production.
Our stock is a penny stock. Trading of our stock may be restricted by the SEC’s penny stock regulations which may limit a stockholder’s ability to buy and sell our stock.
Our stock is a penny stock. The Securities and Exchange Commission has adopted Rule 15g-9 which generally defines “penny stock” to be any equity security that has a market price (as defined) less than $5.00 per share or an exercise price of less than $5.00 per share, subject to certain exceptions. Our securities are covered by the penny stock rules, which impose additional sales practice requirements on broker-dealers who sell to persons other than established customers and “accredited investors”. The term “accredited investor” refers generally to institutions with assets in excess of $5,000,000 or individuals with a net worth in excess of $1,000,000 or annual income exceeding $200,000 or $300,000 jointly with their spouse. The penny stock rules require a broker-dealer, prior to a transaction in a penny stock not otherwise exempt from the rules, to deliver a standardized risk disclosure document in a form prepared by the SEC which provides information about penny stocks and the nature and level of risks in the penny stock market. The broker-dealer also must provide the customer with current bid and offer quotations for the penny stock, the compensation of the broker-dealer and its salesperson in the transaction and monthly account statements showing the market value of each penny stock held in the customer’s account. The bid and offer quotations, and the broker-dealer and salesperson compensation information, must be given to the customer orally or in writing prior to effecting the transaction and must be given to the customer in writing before or with the customer’s confirmation. In addition, the penny stock rules require that prior to a transaction in a penny stock not otherwise exempt from these rules, the broker-dealer must make a special written determination that the penny stock is a suitable investment for the purchaser and receive the purchaser’s written agreement to the transaction. These disclosure requirements may have the effect of reducing the level of trading activity in the secondary market for the stock that is subject to these penny stock rules. Consequently, these penny stock rules may affect the ability of broker-dealers to trade our securities. We believe that the penny stock rules discourage investor interest in and limit the marketability of our common stock.
NASD sales practice requirements may also limit a stockholder’s ability to buy and sell our stock.
In addition to the “penny stock” rules described above, the NASD has adopted rules that require that in recommending an investment to a customer, a broker-dealer must have reasonable grounds for believing that the investment is suitable for that customer. Prior to recommending speculative low priced securities to their non-institutional customers, broker-dealers must make reasonable efforts to obtain information about the customer’s financial status, tax status, investment objectives and other information. Under interpretations of these rules, the NASD believes that there is a high probability that speculative low priced securities will not be suitable for at least some customers. The NASD requirements make it more difficult for broker-dealers to recommend that their customers buy our common stock, which may limit your ability to buy and sell our stock and have an adverse effect on the market for our shares.
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Trading on the OTC Bulletin Board may be sporadic because it is not a stock exchange, and stockholders may have difficulty reselling their shares.
Our common stock is quoted on the OTC Bulletin Board. Trading in stock quoted on the OTC Bulletin Board is often thin and characterized by wide fluctuations in trading prices, due to many factors that may have little to do with our company’s operations or business prospects. Moreover, the OTC Bulletin Board is not a stock exchange, and trading of securities on the OTC Bulletin Board is often more sporadic than the trading of securities listed on a quotation system like Nasdaq or a stock exchange like Amex.
We have a limited operating history and if we are not successful in continuing to grow our business, then we may have to scale back or even cease our ongoing business operations.
We have no history of revenues from operations and have no significant tangible assets. We have yet to generate positive earnings and there can be no assurance that we will ever operate profitably. Our company has a limited operating history and must be considered in the development stage. The success of our company is significantly dependent on a successful acquisition, drilling, completion and production program. Our company’s operations will be subject to all the risks inherent in the establishment of a developing enterprise and the uncertainties arising from the absence of a significant operating history. We may be unable to locate recoverable reserves or operate on a profitable basis. We are in the development stage and potential investors should be aware of the difficulties normally encountered by enterprises in the development stage. If our business plan is not successful, and we are not able to operate profitably, investors may lose some or all of their investment in our company.
Because of the early stage of development and the nature of our business, our securities are considered highly speculative.
Our securities must be considered highly speculative, generally because of the nature of our business and the early stage of its development. We are engaged in the business of exploring and, if warranted, developing commercial reserves of oil and gas. Our properties are in the exploration stage only and are without known reserves of oil and gas. Accordingly, we have not generated any revenues nor have we realized a profit from our operations to date and there is little likelihood that we will generate any revenues or realize any profits in the short term. Any profitability in the future from our business will be dependent upon locating and developing economic reserves of oil and gas, which itself is subject to numerous risk factors as set forth herein. Since we have not generated any revenues, we will have to raise additional monies through the sale of our equity securities or debt in order to continue our business operations.
As our properties are in the exploration and development stage there can be no assurance that we will establish commercial discoveries on our properties.
Exploration for economic reserves of oil and gas is subject to a number of risk factors. Few properties that are explored are ultimately developed into producing oil and/or gas wells. Our properties are in the exploration and development stage only and are without proven reserves of oil and gas. We may not establish commercial discoveries on any of our properties.
The potential profitability of oil and gas ventures depends upon factors beyond the control of our company
The potential profitability of oil and gas properties is dependent upon many factors beyond our control. For instance, world prices and markets for oil and gas are unpredictable, highly volatile, potentially subject to governmental fixing, pegging, controls, or any combination of these and other factors, and respond to changes in domestic, international, political, social, and economic environments. Additionally, due to worldwide economic uncertainty, the availability and cost of funds for production and other expenses have become increasingly difficult, if not impossible, to project. These changes and events may materially affect our financial performance.
Adverse weather conditions can also hinder drilling operations. A productive well may become uneconomic in the event water or other deleterious substances are encountered which impair or prevent the production of oil and/or gas from the well. In addition, production from any well may be unmarketable if it is impregnated with water or other deleterious substances. The marketability of oil and gas which may be acquired or discovered will be affected by numerous factors beyond our control. These factors include the proximity and capacity of oil and gas pipelines and
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processing equipment, market fluctuations of prices, taxes, royalties, land tenure, allowable production and environmental protection. These factors cannot be accurately predicted and the combination of these factors may result in our company not receiving an adequate return on invested capital.
Competition in the oil and gas industry is highly competitive and there is no assurance that we will be successful in acquiring any further leases.
The oil and gas industry is intensely competitive. We compete with numerous individuals and companies, including many major oil and gas companies, which have substantially greater technical, financial and operational resources and staffs. Accordingly, there is a high degree of competition for desirable oil and gas leases, suitable properties for drilling operations and necessary drilling equipment, as well as for access to funds. We cannot predict if the necessary funds can be raised or that any projected work will be completed. Our budget anticipates our acquisition of additional acreage in Texas and Canada. This acreage may not become available or if it is available for leasing, that we may not be successful in acquiring any further leases. There are other competitors that have operations in Texas and the presence of these competitors could adversely affect our ability to acquire additional leases.
The marketability of natural resources will be affected by numerous factors beyond our control which may result in us not receiving an adequate return on invested capital to be profitable or viable.
The marketability of natural resources which may be acquired or discovered by us will be affected by numerous factors beyond our control. These factors include market fluctuations in oil and gas pricing and demand, the proximity and capacity of natural resource markets and processing equipment, governmental regulations, land tenure, land use, regulation concerning the importing and exporting of oil and gas and environmental protection regulations. The exact effect of these factors cannot be accurately predicted, but the combination of these factors may result in us not receiving an adequate return on invested capital to be profitable or viable.
Oil and gas operations are subject to comprehensive regulation which may cause substantial delays or require capital outlays in excess of those anticipated causing an adverse effect on our company.
Oil and gas operations are subject to federal, state, and local laws relating to the protection of the environment, including laws regulating removal of natural resources from the ground and the discharge of materials into the environment. Oil and gas operations are also subject to federal, state, and local laws and regulations which seek to maintain health and safety standards by regulating the design and use of drilling methods and equipment. Various permits from government bodies are required for drilling operations to be conducted; no assurance can be given that such permits will be received. Environmental standards imposed by federal, provincial, or local authorities may be changed and any such changes may have material adverse effects on our activities. Moreover, compliance with such laws may cause substantial delays or require capital outlays in excess of those anticipated, thus causing an adverse effect on us. Additionally, we may be subject to liability for pollution or other environmental damages which it may elect not to insure against due to prohibitive premium costs and other reasons. To date we have not been required to spend any material amount on compliance with environmental regulations. However, we may be required to do so in future and this may affect our ability to expand or maintain our operations.
Exploration and production activities are subject to certain environmental regulations which may prevent or delay the commencement or continuance of our operations.
In general, our exploration and production activities are subject to certain federal, state and local laws and regulations relating to environmental quality and pollution control. Such laws and regulations increase the costs of these activities and may prevent or delay the commencement or continuance of a given operation. Compliance with these laws and regulations has not had a material effect on our operations or financial condition to date. Specifically, we are subject to legislation regarding emissions into the environment, water discharges and storage and disposition of hazardous wastes. In addition, legislation has been enacted which requires well and facility sites to be abandoned and reclaimed to the satisfaction of state authorities. However, such laws and regulations are frequently changed and we are unable to predict the ultimate cost of compliance. Generally, environmental requirements do not appear to affect us any differently or to any greater or lesser extent than other companies in the industry.
We believe that our operations comply, in all material respects, with all applicable environmental regulations.
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We maintain insurance coverage customary to the industry; however, we are not fully insured against all possible environmental risks.
Exploratory drilling involves many risks and we may become liable for pollution or other liabilities which may have an adverse effect on our financial position.
Drilling operations generally involve a high degree of risk. Hazards such as unusual or unexpected geological formations, power outages, labor disruptions, blow-outs, sour gas leakage, fire, inability to obtain suitable or adequate machinery, equipment or labour, and other risks are involved. We may become subject to liability for pollution or hazards against which it cannot adequately insure or which it may elect not to insure. Incurring any such liability may have a material adverse effect on our financial position and operations.
Any change to government regulation/administrative practices may have a negative impact on our ability to operate and our profitability.
The laws, regulations, policies or current administrative practices of any government body, organization or regulatory agency in the United States or any other jurisdiction, may be changed, applied or interpreted in a manner which will fundamentally alter the ability of our company to carry on our business.
The actions, policies or regulations, or changes thereto, of any government body or regulatory agency, or other special interest groups, may have a detrimental effect on us. Any or all of these situations may have a negative impact on our ability to operate and/or our profitably.
The possibility of shut-in wells could curtail production and our revenues.
Production from gas wells in many geographic areas of the United States has been curtailed or shut-in for considerable periods of time due to a lack of market demand, and such curtailments may continue for a considerable period of time in the future. There may be an excess supply of gas in areas where our operations will be conducted. In such event, it is possible that there will be no market or a very limited market for our prospects. It is customary in many portions of Oklahoma and Texas to shut-in gas wells in the spring and summary when there is not sufficient demand for gas.
Item 2. Description of Property.
Our executive and head offices are located at Suite 227, 14300 N Northsight Blvd, Scottsdale, AZ, 85260.
We also lease office space at 2401 Fountain View Drive, Suite 1008, Houston, Texas 77057 pursuant to a month to month extension of a written lease agreement with Insite Realty. The offices are approximately 1,100 square feet in size and are leased at a monthly rate of $1,606.50. Management believes that additional office space will be required as our business grows.
Our principal properties consist of developed and undeveloped oil and gas leases and the reserves associated with these leases which are described in Item 1 of this report. Generally, developed oil and gas leases remain in force so long as production is maintained. Undeveloped oil and gas leaseholds are generally for a primary term of three to five years. In most cases, the term of our undeveloped leases can be extended by paying delay rentals or by producing reserves that are discovered under our leases.
Item 3. Legal Proceedings.
SNRG is currently involved in the following litigation:
Kuester Heirs litigation: On February 9, 2005 a group of mineral rights owners on the Charles Kuester Lease in Dewitt County, TX, (the “Kuester Heirs”) filed suit against our wholly owned subsidiary Texas Gohlke Partners, Inc. ( “Lessee”) alleging default by the lessee by reason of non-payment of royalties. The Kuester Heirs have obtained a declaration from the court that the lease has terminated, the effect of this declaration is insignificant as the lease term expired January 31, 2006. SNRG believes that it holds rights to most of the lease acreage through production.
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Vertical Financial Network, LLC litigation. On August 6, 2004 Vertical Financial Network, LLC filed suit against us alleging breach of an investment banking agreement dated June 30, 2004. Vertical is seeking 4,000,000 shares of registered common stock. We deny the allegations and are vigorously defending the complaint. The complaint was filed in the Supreme Court of New York, County of New York.
We have several additional minor litigation matters, all of which we expect to have favourable outcomes.
During 2005 we were involved in litigation with Coastline Operating Inc resulting in a consent judgment being registered against our company in the amount of $263,500. We paid the judgment in full in February 2006.
During December 2005 our company and Texen Holdings LLC, an entity controlled by our President Elroy Fimrite, entered into an Omnibus settlement agreement with Bay City Partners LLC and Crown Pacific Advisors LLC providing for the severance of interests in Port Asset LLC, an assignment of our residual 49% membership interest to Bay City Partners LLC and forgiveness by Bay City Partners LLC of promissory notes in the amounts of $525,000 and $900,000. Pursuant to the terms of the settlement agreement, our company was to provide warrants to Bay City Partners LLC to purchase 225,000 common shares of stock for a price of $0.10 with piggyback rights. We have not issued the warrants and has taken the position that the requirement is unenforceable due to a lack of sufficient definition of the terms of the warrant including in particular, the failure to specify a term of exercise for the warrants.
Item 4. Submissions of Matters to a Vote of Security Holders.
During the year ended December 31, 2005, we obtained Shareholder support by a consent resolution of a majority of the shareholders of our company for the change of our name and for the reorganization of our capital structure of our company. The resolution approved an increase in the authorized common shares from 100,000,000 to 500,000,000 and approved the authorization of 300,000,000 preferred shares.
PART II
Item 5. Market for Common Equity and Related Stockholder Matters.
Our common stock is traded on the National Association of Securities Dealers OTC Bulletin Board under the symbol "SNRG" Our shares began trading on April 11, 2001. The following quotations obtained from Yahoo reflect the high and low bids for our common stock based on inter-dealer prices, without retail mark-up, mark-down or commission an may not represent actual transactions.
The high and low bid prices of our common stock for the periods indicated below are as follows:
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OTC Bulletin Board (1) | ||
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Quarter Ended |
High |
Low |
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March 31, 2006 |
$0.17 |
$0.082 |
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December 31, 2005 |
$0.229 |
$0.061 |
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September 30, 2005 |
$0.16 |
$0.10 |
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June 30, 2005 |
$0.145 |
$0.065 |
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March 31, 2005 |
$0.19 |
$0.15 |
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December 31, 2004 |
$0.10 |
$0.09 |
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September 30, 2004 |
$0.19 |
$0.13 |
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June 30, 2004 |
$0.31 |
$0.12 |
(1) Over-the-counter market quotations reflect inter-dealer prices without retail mark-up, mark-down or commission, and may not represent actual transactions.
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Our common shares are issued in registered form. Pacific Stock Transfer Company of 500 E. Warm Springs Road, Suite 240, Las Vegas, NV 89119 (Telephone: 702.361.3033; Facsimile: 702.433.1979) is the registrar and transfer agent for our common shares.
On March 31, 2006, the shareholders’ list of our common shares showed 196 registered shareholders and 184,220,866 shares outstanding.
We have not declared any dividends since incorporation and do not anticipate that we will do so in the foreseeable future. Although there are no restrictions that limit the ability to pay dividends on our common shares, our intention is to retain future earnings for use in our operations and the expansion of our business.
Securities authorized for issuance under equity compensation plans
The 2003 Nonqualified Stock Option Plan, as amended, provides for the issuance of up to 10,000,000 stock options for services rendered to our company. As of December 31, 2005, 6,350,000 have been granted and have been exercised and 3,650,000 options are available for issuance.
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Plan category |
Number of securities to be issued upon exercise of outstanding options, warrants and rights (a) |
Weighted-average exercise price of outstanding options, warrants and rights (b) |
Number of securities remaining available for future issuance under equity compensation plans (excluding securities reflected in column (a)) (c) | |||
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Equity compensation plans approved by security holders |
0 |
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0 |
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0 |
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Equity compensation plans not approved by securities holders |
0 |
$ |
0 |
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3,650,000 |
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Total |
0 |
$ |
0 |
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3,650,000 |
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Recent Sales of Unregistered Securities
On March 18, 2005 we issued 750,000 shares of common stock to two parties upon exercise of stock options previously granted to them under the registered employee stock option plan.
On June 30 2005, we issued an aggregate of 61,180,000 shares of our common stock pursuant to a private placement for gross and net proceeds of $3,059,000. We issued the securities relying on Rule 506 of Regulation D and/or Section 4(2) of the Securities Act of 1933.
On December 30, 2005 we issued 23,000,000 shares of our common stock pursuant to a private placement for gross and net proceeds of $1,150,000 and we issued 925,000 shares of our common stock pursuant to a private placement resulting from debt settlements proceeds in the amount of $92,500. We issued the securities relying on Rule 506 of Regulation D and/or Section 4(2) of the Securities Act of 1933.
Item 6. Management's Discussion and Analysis or Plan of Operation.
The following discussion should be read in conjunction with our financial statements and the related notes that appear elsewhere in this annual report. The following discussion contains forward-looking statements that reflect our plans, estimates and beliefs. Our actual results could differ materially from those discussed in the forward looking statements. Factors that could cause or contribute to such differences include, but are not limited to, those discussed below and elsewhere in this annual report, particularly in the section entitled "Risk Factors" beginning on page 14 of this annual report.
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Our consolidated audited financial statements are stated in United States Dollars and are prepared in accordance with United States Generally Accepted Accounting Principles.
Overview
We are an oil and gas exploration and development company and carry out our operations through our wholly owned subsidiaries. We are currently engaged in the exploration for and development of oil and gas in our properties located in Victoria, DeWitt and Waller Counties, Texas. Our revenue comes from the sale of oil and gas.. Our subsidiaries lease approximately 4,211 acres of crude oil and natural gas production properties in Texas. We have entered into an agreement with Arapahoe Energy Corporation to acquire a 50% interest in approximately 30,000 acres in Saskatchewan in the Western Canadian Basin.
Our Texas holdings are mature properties that are producing from the minimum number of locations to preserve our leasehold interests. Many of our wells require maintenance to increase their potential. We believe that we have additional development prospects within our leases and we hope to develop these prospects in the upcoming year. As a development stage company, we have opportunities to increase revenues from well development and rework projects, but will require additional capital to do so. There is no assurance that we will have the resources to pursue these projects in our properties. We may decide to dispose of the properties in Texas in order to focus on the Western Canadian Basin
We are actively seeking additional capital with which to invest in our current properties, as well as provide resources with which we may be able to pursue new opportunities in the future. Our plans include seeking financing from private investors, as well as entering into working relationships with external oil and gas funds that may be attracted to direct investment in our properties or other properties we may identify. We have announced our intention to structure special purpose income funds for access to funds for acquisition, and development of new prospects. We intend to participate in the fund entities as the managing member and will participate in the net revenue earned, but we disavow ownership of the funds.
We are also making strategic plans to improve our ability to attract and identify low risk oil and gas projects. These plans include joint ventures with companies that have analytical technologies with which oil and gas property owners can select drilling locations with an improved probability of economic viability. We hope to use this technology to identify high probability drilling sites in our properties as well as in other properties that may be presented to us.
Results of Operations for the fiscal year ended December 31, 2005.
We increased revenues from oil and gas production marginally in 2005 but did not generate a material amount of revenue. We did not conduct significant field operations during 2005. Our primary operational focus was concentrated on resolving legal issues with respect to the leases and our previous lease operator. As a result of the uncertainty we did not proceed with the previously announced comprehensive field study of the leases located in Victoria and Dewitt counties, Texas.
Our initiatives to control compensation produced a 75% savings. We do not expect to achieve similar compensation levels in the future as the 2005 savings resulted from not engaging management personnel while we were restructuring our company.
Production expenses were reduced from 142% of sales revenue in 2004 to 87% of sales revenue in 2005. These high levels of operating expenses have been a result of the previous operating contract and the requirement of maintaining field personnel even while production was deferred pending the development of a sound production plan for our existing assets. Such a plan may determine that further expenditures on our current assets are not warranted and if warranted, we may not have the capital to implement the plan.
General and administrative expenses were comparable to the prior year. Legal and accounting expense increased by 280% reflecting the one time cost of litigating and resolving corporate issues as part of the restructuring of our company.
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- 22 - |
We participated in drilling one new well in 2005 and that well was a dry hole resulting in a write off of our investment.
Depreciation and depletion expenses were reduced by 58% as a result of recognition of an additional impairment in 2004 and as a result of higher hydro-carbon prices which resulted in increased revenue from a smaller amount of production.
In August of 2005 we purchased a dormant facility in Bay City Texas, by acquiring the management interests of Port Assets, LLC. for $3,000,000 cash, 3,000,000 warrants to purchase common stock at $0.50 per share and a ongoing royalty on production from the facility. Subsequent to our acquisition we sold a 51% interest in the facility with an option to reacquire the 51% when our facility financing was complete. In the period from August through November 2005 we received bridge funding and incurred initial evaluation and maintenance expenses, but were unsuccessful in obtaining sufficient funding to exercise our option or to commence operations. In December we negotiated an omnibus settlement agreement with our co-owner of the facility to sell our remaining 49% and receive debt forgiveness for the bridge financing that had been provided. This disposal resulted in a net gain on disposal of $969,127. In conjunction with the intended operation of the Bay City facility we purchased certain rubber recycling equipment for $2,000,000, for which we have a residual debt obligation of $500,000. We intend to sell this equipment and intend to use the net proceeds of such a sale for debt reduction and general corporate purposes.
Liquidity and Capital Resources
We were very successful in 2005 in improving the liquidity and capital resources of our company. The working capital position was improved by approximately $2.2 million. We completed debt settlements and private placements totalling approximately $4.3 million and ended the year with $780,000 of cash on hand.
On June 30 2005, we issued an aggregate of 61,170,000 shares of our common stock in private placements for proceeds of $3,059,000.
On December 30, 2005, we issued an aggregate of 23,000,000 of our shares of our common stock in private placements for proceeds of $1,150,000 and we issued 925,000 shares of our common stock in private placements resulting from debt settlements of $92,500.
Our net cash provided by financing activities during the year ended December 31, 2005 was $ 4,209,000.
On March 31, 2006 we announced a letter of intent to acquire a 50% interest in approximately 30,000 acres of oil and gas leases in Saskatchewan, Canada. On April 21 2006 we completed our first capital obligation under the terms of the agreement and we expect to complete the balance of our obligations as scheduled. We intend to expand our holdings in the Western Canada Basin. Our ability to complete our obligations under the agreement and to fund additional acquisitions and development is dependant on our ability to raise adequate capital. There is no assurance that such capital can be raised, and if offered, the terms of the offer may be unacceptable.
Estimated Funding Required During the Next Twelve Months
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General and Administrative |
$1,000,000 | |
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Acreage |
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Poundmaker and Freemont |
3,750,000 |
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Additional acreage |
10,000,000 |
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Operations |
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Poundmaker and Freemont Seismic |
2,000,000 |
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Poundmaker and Freemont Test Wells |
3,000,000 |
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Additional Acreage Seismic and Test Wells |
15,000,000 |
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Drilling Programs |
15,000,000 |
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Work-over and Operations |
5,000,000 |
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Working Capital |
3,000,000 | |
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Total |
$57,750,000 | |
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As at December 31, 2005, we had $1,722,530 in current liabilities. Our financial statements report a net profit of $34,449 for the year ended December 31, 2005 compared to a net loss of $3,965,814 for the year ended December 31, 2004. Our accumulated loss decreased to $31,310,020 during the period from inception to December 31, 2005 as we reported a net profit for the year ended December 31 2005 of $34,449. Our total liabilities as of December 31, 2005 were $1,722,530, as compared to total liabilities of $2,693,740 as of December 31, 2004.
We have suffered recurring losses from operations. The continuation of our company is dependent upon our company attaining and maintaining profitable operations and raising additional capital. In this regard we have raised additional capital through the equity offerings noted above.
The continuation of our business is dependent upon obtaining further financing, a successful program of acquisition and exploration, and, finally, achieving a profitable level of operations. The issuance of additional equity securities by us could result in a significant dilution in the equity interests of our current stockholders. Obtaining commercial loans, assuming those loans would be available, will increase our liabilities and future cash commitments.
There are no assurances that we will be able to obtain further funds required for our continued operations. As noted herein, we are pursuing various financing alternatives to meet our immediate and long-term financial requirements. There can be no assurance that additional financing will be available to us when needed or, if available, that it can be obtained on commercially reasonable terms. If we are not able to obtain the additional financing on a timely basis, we will be unable to conduct our operations as planned, and we will not be able to meet our other obligations as they become due. In such event, we will be forced to scale down or perhaps even cease our operations.
Presentation of Financial Information
In 2004 we changed our year end from June 30 to December 31. Our comparative financial statements for the period ended December 31, 2004 reflect financial information for the period from January 1, 2004 to December 31, 2004 as restated in our December 31, 2004 financial statements.
New Accounting Pronouncements
Significant accounting pronouncements are detailed in Note 2 to the financial statements.
Application of Critical Accounting Policies
Our financial statements and accompanying notes are prepared in accordance with generally accepted accounting principles in the United States. Preparing financial statements requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenue, and expenses. These estimates and assumptions are affected by management’s application of accounting policies. We believe that understanding the basis and nature of the estimates and assumptions involved with the following aspects of our consolidated financial statements is critical to an understanding of our financials. We consider all highly liquid investments with an original maturity of three months or less to be cash equivalents.
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ITEM 7. |
FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA. |
Our financial statements are stated in United States Dollars (US$) and are prepared in accordance with United States Generally Accepted Accounting Principles.
Table of Contents
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INDEPENDENT AUDITOR REPORTS |
F-1, F-2 |
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CONSOLIDATED FINANCIAL STATEMENTS |
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Consolidated Balance Sheets |
F-3 |
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Consolidated Statements of Operations |
F-4 |
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Consolidated Statements of Stockholders’ Equity (Deficit) |
F-5 |
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Consolidated Statements of Cash Flows |
F-6, F-7 |
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NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS |
F-8 – F-20 |
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Board of Directors
SNRG Corporation
Scottsdale, Arizona
USA
Report of Independent Registered Public Accounting Firm
We have audited the accompanying consolidated balance sheet of SNRG Corporation. as of December 31, 2005 and the related consolidated statements of operations, stockholders’ equity (deficit) and cash flows for the year then ended. These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audit.
We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audit provides a reasonable basis for our opinion.
In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the consolidated financial position of SNRG Corporation as of December 31, 2005 and the related consolidated results of operations, stockholders’ equity (deficit) and cash flows for the year then ended, in conformity with accounting principles generally accepted in the United States of America.
The accompanying consolidated financial statements have been prepared assuming that the Company will continue as a going concern. As discussed in Note 2, the Company’s operating losses and cash flow deficiencies from operations raise substantial doubt about its ability to continue as a going concern. Management’s plans regarding those matters also are described in Note 2. The consolidated financial statements do not include any adjustments that might result from the outcome of this uncertainty.
/s/Epstein Weber & Conover, PLC
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Scottsdale, Arizona | ||
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May 1, 2006 |
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F-1
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Board of Directors
SNRG Corporation
(fka Texen Oil & Gas, Inc.)
Scottsdale, Arizona
USA
Report of Independent Registered Public Accounting Firm
We have audited the accompanying consolidated balance sheet of SNRG Corporation (fka TexEn Oil & Gas, Inc.) as of December 31, 2004 and the related consolidated statements of operations, stockholders’ equity (deficit) and cash flows for the period ended December 31, 2004. These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.
We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audit provide a reasonable basis for our opinion.
In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the consolidated financial position of SNRG Corporation (fka TexEn Oil & Gas, Inc.) as of December 31, 2004 and the related consolidated results of operations, stockholders’ equity (deficit) and cash flows for the period ended December 31, 2004, in conformity with accounting principles generally accepted in the United States of America.
The accompanying consolidated financial statements have been prepared assuming that the Company will continue as a going concern. As discussed in Note 2, the Company’s operating losses and significant impairment of oil and gas properties raise substantial doubt about its ability to continue as a going concern. Management’s plans regarding those matters also are described in Note 2. The consolidated financial statements do not include any adjustments that might result from the outcome of this uncertainty.
/s/ Williams & Webster, P.S.
Williams & Webster, P.S.
Certified Public Accountants
Spokane, Washington
May 16, 2005
F-2
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The accompanying notes are an integral part of these financial statements.
F-3
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The accompanying notes are an integral part of these financial statements.
F-4
The accompanying notes are an integral part of these financial statements.
F-5
The accompanying notes are an integral part of these financial statements.
F-6
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F-7
SNRG Corporation
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(Formerly Texen Oil & Gas, Inc.)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
December 31, 2005
NOTE 1 – ORGANIZATION AND DESCRIPTION OF BUSINESS
SNRG Corporation (formerly Texen Oil & Gas, Inc, formerly Palal Mining Corporation) (hereinafter “SNRG” or “the Company”) filed for incorporation on September 2, 1999 under the laws of the State of Nevada. On July 1, 2002, the Company developed a plan for acquisition, development, production, exploration for, and the sale of, oil, gas and natural gas liquids. During 2002 and 2003 the Company acquired oil and gas leasehold interests located in Victoria, Dewitt and Warren Counties, Texas, through the acquisition of wholly owned subsidiaries Texas Brookshire Partners, Inc., Texas Gohlke Partners, Inc., Yegua, Inc. and BWC Minerals, LLC. These acquisitions were accounted for using the purchase method. The Company sells its oil and gas products to domestic customers.
The Company’s wholly owned subsidiaries consist of Texas Brookshire Partners, Inc. (“Brookshire”), Texas Gohlke Partners, Inc, (“Gohlke”), Brookshire Drilling Services, Inc. (“Drilling”), Yegua, Inc. (“Yegua”) and BWC Minerals, LLC (“BWC”).
The Company’s fiscal year end is December 31. The Company changed its year end effective December 31, 2004 from June 30, an 8-K was filed on February 15, 2005 advising as to the year end change.
NOTE 2 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
This summary of significant accounting policies is presented to assist in understanding the financial statements. The financial statements and notes are representations of the Company’s management, which is responsible for their integrity and objectivity. These accounting policies conform to accounting principles generally accepted in the United States of America, and have been consistently applied in the preparation of the financial statements.
Use of Estimates
The process of preparing financial statements in conformity with accounting principles generally accepted in the United States of America requires the use of estimates and assumptions regarding certain types of assets, liabilities, revenues, and expenses. Such estimates primarily relate to unsettled transactions and events as of the date of the financial statements. Accordingly, upon settlement, actual results may differ from estimated amounts.
Cash and Cash Equivalents
For purposes of its statement of cash flows, the Company considers all short-term debt securities purchased with a maturity of three months or less to be cash equivalents.
Fair Value of Financial Instruments
The carrying amounts for cash, accounts receivable, accrued oil and gas runs, accounts payable, accrued liabilities and loans and notes payable approximate their fair value.
Compensated Absences
The Company’s policy is to recognize the cost of compensated absences when earned by employees. If the amount was able to be estimated, it would not be currently recognized as the amount would be deemed immaterial.
Basic and Diluted Loss Per Share
Net loss per share was computed by dividing the net loss by the weighted average number of shares outstanding during the period. The weighted average number of shares was calculated by taking the number of shares outstanding and weighting them by the amount of time that they were outstanding. Diluted earnings per share reflect the potential dilution of securities that could share in the earnings of an entity similar to fully diluted earnings per share. Outstanding options were not included in the computation of net loss per share because they would be antidilutive.
F-8
SNRG Corporation
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(Formerly Texen Oil & Gas, Inc.)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
December 31, 2005
NOTE 2 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued)
Property and Equipment
Wells and related equipment and facilities, support equipment and facilities and other property and equipment are carried at cost. Oil and gas assets are subject to depreciation, depletion and amortization utilizing a unit of production method. Depreciation for drilling equipment and other assets are subject to the straight-line method over the estimated useful lives of the related assets, which range from five to ten years. The Company purchased rubber recycling equipment for usage in conjunction with the Port Assets facility. The Company will dispose of the equipment in 2006. No depreciation has been recorded as the equipment has not operated. The total other property and equipment as of December 31, 2005 and 2004 were $2,013,439, and $178,564, respectively, and the corresponding accumulated depreciation was $5,155 and $98,532.
In connection with the Port Assets transaction described in Note 14, the Company acquired rubber recycling equipment for $2,000,000. Due to the Company not pursuing the operation of the gasification facility, the equipment was not installed. The Company intends to sell the equipment and believes that the proceeds of such a disposal will exceed the carrying cost at December 31, 2005.
Future Development and Abandonment Costs
In June 2001, FASB issued SFAS No. 143, Accounting for Asset Retirement Obligations. SFAS No. 143 requires entities to record the fair value of a liability for an asset retirement obligation in the period in which it is incurred and a corresponding increase in the carrying amount of the related long-lived asset. Subsequently, the asset retirement cost is allocated to expense using a systematic and rational method. The provisions of SFAS No. 143 were effective for fiscal years beginning after June 15, 2002.
Future development costs include costs incurred to obtain access to proved reserves such as drilling costs and the installation of production equipment. Future abandonment costs include costs to dismantle and relocate or dispose of our production platforms, gathering systems and related structures and restoration costs of land. The Company estimates that the future abandonment and related costs will be approximately $8,000 per well for a current total of 43 well bores resulting in a total cost of $344,000. The Company estimates a recovery of salvage steel and equipment will exceed $350,000.
Derivative Instruments
The Financial Accounting Standards Board issued Statement of Financial Accounting Standards (“SFAS”) No. 133, “Accounting for Derivative Instruments and Hedging Activities,” as amended by SFAS No. 137, “Accounting for Derivative Instruments and Hedging Activities – Deferral of the Effective Date of FASB No. 133”, and SFAS No. 138, “Accounting for Certain Derivative Instruments and Certain Hedging Activities” and SFAS No. 149 “Amendment of Statement 133 on Derivative Instruments and Hedging Activities”. These standards establish accounting and reporting standards for derivative instruments, including certain derivative instruments embedded in other contracts, and for hedging activities. They require that an entity recognize all derivatives as either assets or liabilities in the consolidated balance sheet and measure those instruments at fair value.
If certain conditions are met, a derivative may be specifically designated as a hedge, the objective of which is to match the timing of gain or loss recognition on the hedging derivative with the recognition of (i) the changes in the fair value of the hedged asset or liability that are attributable to the hedged risk or (ii) the earnings effect of the hedged forecasted transaction. For a derivative not designated as a hedging instrument, the gain or loss is recognized in income in the period of change.
Historically, the Company has not entered into derivatives contracts to hedge existing risks or for speculative purposes. At December 31, 2005, the Company has not engaged in any transactions that would be considered derivative instruments or hedging activities.
F-9
SNRG Corporation
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(Formerly Texen Oil & Gas, Inc.)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
December 31, 2005
NOTE 2 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued)
Successful Efforts Accounting
The company accounts for its oil and gas exploration and development activities utilizing the successful efforts method of accounting. Under this method, cost of productive exploratory wells, developmental dry hole and productive wells and undeveloped leases are capitalized. Oil and gas acquisition costs are also capitalized. Exploration costs, including personnel costs, certain geological and geophysical expenses and delay rentals for oil and gas leases, are charged to expense as incurred. Exploratory drilling costs are initially capitalized, but such costs are charged to expense if and when the well is determined not to have found reserves in commercial quantities.
Unproved oil and gas properties that are individually significant are periodically assessed for impairment of value and a loss is recognized at the time of impairment by providing an impairment allowance. Other unproved properties are amortized based on the Company’s experience of successful drilling and average holding period. Capitalized costs of producing oil and gas properties, after considering estimated dismantlement and abandonment costs and estimated salvage values, are depreciated and depleted by the units-of-production method. Support equipment and other property and equipment are depreciated over their estimated useful lives.
On the sale or retirement of a complete unit of a proved property, the cost and related accumulated depreciation, depletion, and amortization are eliminated from the property accounts, and the resultant gain or loss is recognized. On the retirement or sale of a partial unit of proved property, the cost and related accumulated depreciation, depletion, and amortization of this partial unit are eliminated from the property account and the resulting gain or loss is recognized in income.
On the sale of an entire interest in an unproved property, gain or loss on the sale is recorded, with recognition given to the amount of any recorded impairment if the property has been assessed individually. If a partial interest in an unproved property is sold, the amount received is treated as a reduction of the cost of the interest retained.
Capitalized Interest
The Company capitalizes interest on expenditures for significant exploration and development projects while activities are in progress to bring the assets to their intended use. No amounts of interest were capitalized in the years ended December 31, 2005 and 2004.
Provision for Taxes
Income taxes are provided based upon the liability method of accounting pursuant to SFAS No. 109 “Accounting for Income Taxes.” Under this approach, deferred income taxes are recorded to reflect the tax consequences on future years of differences between the tax basis of assets and liabilities and their financial reporting amounts at each year end. A valuation allowance is recorded against deferred tax assets if management does not believe the Company has met the “more likely than not” standard imposed by SFAS No.109 to allow recognition of such an asset. (Note 16).
Going Concern
The accompanying financial statements have been prepared assuming that the Company will continue as a going concern. As shown in the accompanying financial statements, the Company has incurred an accumulated deficit in the amount of $31,310,020 for the period of September 2, 1999 (inception) to December 31, 2005 and a net profit in the amount of $34,449 during the year ended December 31, 2005. The future of the Company is dependent upon its ability to obtain financing and upon future successful explorations for and profitable operations from the development of oil and gas properties.
Management has plans to seek additional capital through a private placement at market value and public offering of its common stock as well as obtaining additional financing in the form of loans. The financial statements do not include any adjustments relating to the recoverability and classification of recorded assets, or the amounts and classification of liabilities that might be necessary in the event the Company cannot continue in existence.
F-10
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SNRG Corporation
(Formerly Texen Oil & Gas, Inc.)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
December 31, 2005
NOTE 2 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued)
Environmental Remediation and Compliance
Expenditures for ongoing compliance with environmental regulations that relate to current operations are expensed or capitalized as appropriate. Expenditures resulting from the remediation of existing conditions caused by past operations that do not contribute to future revenue generations are expensed. Liabilities are recognized when environmental assessments indicate that remediation efforts are probable and the costs can be reasonably estimated.
Estimates of such liabilities are based upon currently available facts, existing technology and presently enacted laws and regulations taking into consideration the likely effects of inflation and other societal and economic factors, and include estimates of associated legal costs. These amounts also reflect other companies’ clean-up experience and data released by the Environmental Protection Agency (EPA) or other organizations. Such estimates are by their nature imprecise and can be expected to be revised over time because of changes in government regulations, operations, technology and inflation. As of December 31, 2005 the company is not aware of any outstanding compliance issues or obligations.
Principles of Consolidation
The financial statements include those of SNRG Corporation., Texas Brookshire Partners, Inc., Texas Gohlke Partners, Inc., Brookshire Drilling Services, L.L.C., Yegua, Inc., and BWC Minerals, L.L.C. All significant inter-company accounts and transactions have been eliminated
Recent Accounting Pronouncements
In December 2004, the Financial Accounting Standards Board issued Statement of Financial Accounting Standards No. 153. This statement addresses the measurement of exchanges of nonmonetary assets. The guidance in APB Opinion No. 29, “Accounting for Nonmonetary Transactions,” is based on the principle that exchanges of nonmonetary assets should be measured based on the fair value of the assets exchanged. The guidance in that opinion, however, included certain exceptions to that principle. This statement amends Opinion 29 to eliminate the exception for nonmonetary exchanges of similar productive assets and replaces it with a general exception for exchanges of nonmonetary assets that do not have commercial substance. A nonmonetary exchange has commercial substance if the future cash flows of the entity are expected to change significantly as a result of the exchange. This statement is effective for financial statements for fiscal years beginning after June 15, 2005. Earlier application is permitted for nonmonetary asset exchanges incurred during fiscal years beginning after the date of this statement is issued. Management believes the adoption of this statement will have no impact on the financial statements of the Company.
In December 2004, the Financial Accounting Standards Board issued Statement of Financial Accounting Standards No. 152, which amends FASB statement No. 66, “Accounting for Sales of Real Estate,” to reference the financial accounting and reporting guidance for real estate time-sharing transactions that is provided in AICPA Statement of Position (SOP) 04-2, “Accounting for Real Estate Time-Sharing Transactions.” This statement also amends FASB Statement No. 67, “Accounting for Costs and Initial Rental Operations of Real Estate Projects,” to state that the guidance for (a) incidental operations and (b) costs incurred to sell real estate projects does not apply to real estate time-sharing transactions. The accounting for those operations and costs is subject to the guidance in SOP 04-2. This statement is effective for financial statements for fiscal years beginning after June 15, 2005. Management believes the adoption of this statement will have no impact on the financial statements of the Company.
F-11
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SNRG Corporation
(Formerly Texen Oil & Gas, Inc.)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
December 31, 2005
NOTE 2 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued)
Recent Accounting Pronouncements (continued)
In December 2004, the Financial Accounting Standards Board issued a revision to Statement of Financial Accounting Standards No. 123R, “Accounting for Stock Based Compensation.” This statement supersedes APB Opinion No. 25, “Accounting for Stock Issued to Employees,” and its related implementation guidance. This statement establishes standards for the accounting for transactions in which an entity exchanges its equity instruments for goods or services. It also addresses transactions in which an entity incurs liabilities in exchange for goods or services that are based on the fair value of the entity’s equity instruments or that may be settled by the issuance of those equity instruments. This statement focuses primarily on accounting for transactions in which an entity obtains employee services in share-based payment transactions. This statement does not change the accounting guidance for share based payment transactions with parties other than employees provided in Statement of Financial Accounting Standards No. 123. This statement does not address the accounting for employee share ownership plans, which are subject to AICPA Statement of Position 93-6, “Employers’ Accounting for Employee Stock Ownership Plans.” The Company already complies with SFAS 123 and believes that the changes in SFAS 123R will have no material additional effect on the Company.
In November 2004, the Financial Accounting Standards Board (FASB) issued Statement of Financial Accounting Standards No. 151, “Inventory Costs— an amendment of ARB No. 43, Chapter 4”. This statement amends the guidance in ARB No. 43, Chapter 4, “Inventory Pricing,” to clarify the accounting for abnormal amounts of idle facility expense, freight, handling costs, and wasted material (spoilage). Paragraph 5 of ARB 43, Chapter 4, previously stated that “. . . under some circumstances, items such as idle facility expense, excessive spoilage, double freight, and remanding costs may be so abnormal as to require treatment as current period charges. . . .” This statement requires that those items be recognized as current-period charges regardless of whether they meet the criterion of “so abnormal.” In addition, this statement requires that allocation of fixed production overheads to the costs of conversion be based on the normal capacity of the production facilities. This statement is effective for inventory costs incurred during fiscal years beginning after June 15, 2005. Management does not believe the adoption of this statement will have any immediate material impact on the Company.
In May 2003, the Financial Accounting Standards Board issued Statement of Financial Accounting Standards No. 150, “Accounting for Certain Financial Instruments with Characteristics of Both Liabilities and Equity” (hereinafter “SFAS No. 150”). SFAS No. 150 establishes standards for classifying and measuring certain financial instruments with characteristics of both liabilities and equity and requires that those instruments be classified as liabilities in statements of financial position. Previously, many of those instruments were classified as equity. SFAS No. 150 is effective for financial instruments entered into or modified after May 31, 2003 and otherwise is effective at the beginning of the first interim period beginning after June 15, 2003. The adoption of SFAS No. 150 is not expected to have a material impact on the financial position or results of operations of the Company
In April 2003, the Financial Accounting Standards Board issued Statement of Financial Accounting Standards No. 149, “Amendment of Statement 133 on Derivative Instruments and Hedging Activities” (hereinafter “SFAS No. 149”). SFAS No. 149 amends and clarifies the accounting for derivative instruments, including certain derivative instruments embedded in other contracts and for hedging activities under SFAS No. 133, “Accounting for Derivative Instruments and Hedging Activities”. This statement is effective for contracts entered into or modified after December 31, 2004 and for hedging relationships designated after December 31, 2004. The adoption of SFAS No. 149 is not expected to have a material impact on the financial position or results of operations of the Company as the Company has not issued any derivative instruments or engaged in any hedging activities as of December 31, 2005.
F-12
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SNRG Corporation
(Formerly Texen Oil & Gas, Inc.)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
December 31, 2005
NOTE 2 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued)
Revenue Recognition
The Company utilizes the accrual method of accounting for crude oil revenues whereby revenues are recognized as the Company's entitlement share of the oil that is produced and delivered to a purchaser based upon its working interest in the properties. The Company records a receivable (payable) to the extent that it receives less (more) than its proportionate share of the gas revenues. There are no significant gas imbalances at December 31, 2005.
Accounts Receivable
The Company carries its accounts receivable at cost. On a periodic basis, the Company evaluates its accounts receivable and writes off receivables that are considered non-collectible. The Company’s policy is to accrue interest on trade receivables 30 days after invoice date. A receivable is considered past due if payments have not been received by the Company within 90 days of invoicing. At that time, the Company will discontinue accruing interest and pursue collection. If a payment is made after pursuing collection, the Company will apply the payment to the outstanding principal first and resume accruing interest. Accounts are written off as non-collectible if no payments are received within 90 days after initiating collection efforts.
NOTE 3 – COMMON STOCK
During the year ended June 2004, the Company issued 47,333,333 shares of its common stock as follows: 40,000,000 shares issued to Tatiana Golovina for conversion of debt; 1,333,333 shares issued to Crescent Fund for public relations consulting (subsequently suspended); 2,500,000 shares issued to non-associated financing parties for additional compensation on financing; 500,000 shares issued to Pinnacle Research for consulting services; 1,250,000 to Woodburn Holdings for consulting services; 1,500,000 shares issued to associated consultants for consulting services; 250,000 shares issued to MJB Limited for consulting services. During the year ended December 31, 2004, the Company issued a total of 5,848,223 shares of its common stock as follows 1,000,000 shares issued to The Sterling Group for consulting services; 1,000,000 shares issued to Ceekore International, LLC for consulting services; 2,500,000 shares issued to LSG Financial, Inc. for consulting services, and 600,000 shares issued to Frank Khadivi for consulting services. In addition, the company accepted a subscription for 748,223 with the share issuance in transit as at December 31, 2004. As of December 31, 2004, the company had 98,361,866 shares issued and outstanding.
During the year ended December 31, 2005, the Company issued a total of 750,000 shares of its common stock to two parties for accrued services at a price of $0.13. The Company issued a total of 925,000 of its common stock pursuant to debt settlement agreements at a price of $0.10 per share. These transactions were valued at the trading price of the shares on the date of the agreements. In addition, the Company issued 84,180,000 shares of its common stock pursuant to private placements at a price of $0.05 per share. As of December 31, 2005, the company had 184,220,866 shares issued and outstanding.
NOTE 4 – RELATED PARTIES
On May 17, 2005, Texen Holdings LLC, an entity controlled by the President, Mr. Fimrite acquired 100% on the control position from Tatiana Golovina for consideration of $3,500,000 paid by promissory note. An 8-k advising of the change of control was filed on May 19, 2005.
In 2004 Tatiana Golovina, a Director, a shareholder of the company and previous President and CEO lent us approximately $1,338,890 for our operations. During 2005 we purchased the A207 well for $700,000 from Texas Columbia Energy Management, a company controlled by Tatiana Golovina. In 2005, the loans payable to Tatiana Golovina, Michael Sims, Texas Columbia Energy Management and associated entities in the aggregate amount of $2,020,141 were assigned to Texen Holdings LLC., a company controlled by Elroy Fimrite our President. These loans were paid in June 2005 by the proceeds of private placements resulting in the issuance of 40,000,000 shares at a price of $0.05. F-13
|
|
SNRG Corporation
(Formerly Texen Oil & Gas, Inc.)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
December 31, 2005
NOTE 4 – RELATED PARTIES (continued)
During 2005 Texen Holdings provided a loan facility to the company advancing $1,175,072 of which the company repaid $702,633 leaving a balance owing to Texen Holdings LLC of $472,439 on December 31, 2005. During the period August 2005 to December 2005, Texen Holdings assisted the company with the acquisition and financing of the Port Assets facility by providing cash advances from time to time and with the provision of guarantees on bridge loan facilities. Texen Holdings has not received any compensation pursuant to the loaning of funds or the provision of guarantees for and on behalf of the company. On December 30, 2005 Texen Holdings LLC purchased 14,000,000 shares of common stock of the company for proceeds of $700,000 at a price of $0.05.
NOTE 5 – COMMITMENTS AND CONTINGENCIES
Regulatory Issues
The oil and gas exploration and development industry is inherently speculative and subject to complex environmental regulations. The Company is unaware of any pending litigation or of past or prospective environmental matters which could impair the value of its properties.
Farmout Agreements
No farmout agreements entered into during the year ending December 31, 2005.
Consulting Agreements
During the year ending December 31, 2004, the Company entered into a consulting agreement with Pinnacle Research and Consulting Group Ltd. ("Pinnacle") to provide consulting services for oil and gas operations. This agreement became effective as of December 18, 2003 and options to acquire 500,000 shares of common stock were given as compensation and exercised.
During the year ending December 31, 2004, the Company entered into consulting agreements with Woodburn Holdings Ltd. ("Woodburn") to provide consulting services for oil and gas operations. Stock options to acquire 1,250,000 shares of common stock were given as compensation and exercised.
During the year ending December 31, 2004, the Company entered into a consulting agreement with Crescent Fund, Inc. to provide public relations consulting services. 1,333,333 shares of common stock were issued under the SEC Rule 144. Subsequently, the company has rescinded and canceled the agreement between the company and Crescent Fund, Inc. and has issued an administrative order to cancel the 1,333,333 shares and demanded the return of said stock certificate. The outcome of this situation has yet to be determined.
In addition, during the year ending December 31, 2004, the Company entered into various consulting agreements and issued 6,000,000 shares for administrative, advisory, operations management and accounting services.
During the year ending December 31, 2005, the Company entered into various per diem and month to month consulting agreements for administrative, advisory, operations management and accounting services. All contracts were with unrelated parties.
Leases
The Company has a month to month lease on office space requiring payments of $1,607 per month.
F-14
|
|
SNRG Corporation
(Formerly Texen Oil & Gas, Inc.)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
December 31, 2005
NOTE 5– COMMITMENTS AND CONTINGENCIES (continued)
Legal Proceedings
The Company is currently involved in the following litigation:
Kuester Heirs litigation: On February 9, 2005 a group of mineral rights owners on the Charles Kuester Lease in Dewitt County, TX, (the “Kuester Heirs”) filed suit against our wholly owned subsidiary Texas Gohlke Partners, Inc. ( “Lessee”) alleging default by the lessee by reason of non-payment of royalties. The Kuester Heirs have obtained a declaration from the court that the lease has terminated, however the lease term had already expired January 31, 2005. SNRG believes that it holds rights to most of the lease acreage through production.
Vertical Financial Network, LLC litigation. On August 6, 2004 Vertical Financial Network, LLC filed suit against us alleging breach of an investment banking agreement dated June 30, 2004. Vertical is seeking 4,000,000 shares of registered common stock. We deny the allegations and are vigorously defending the complaint. The complaint was filed in the Supreme Court of New York, County of New York.
The Company cannot assign any value to the above described legal proceedings at the present time.
During 2005 the company was involved in litigation with Coastline Operating Inc resulting in a consent judgment being registered against the company in the amount of $263,500. The company paid the judgment in full in February 2006.
During December 2005 the company and Texen Holdings LLC, an entity controlled by our President Elroy Fimrite, entered into an Omnibus settlement agreement with Bay City Partners LLC and Crown Pacific Advisors LLC providing for the severance of interests in Port Asset LLC, an assignment of our residual 49% membership interest to Bay City Partners LLC and forgiveness by Bay City Partners LLC of promissory notes in the amounts of $525,000 and $900,000. Pursuant to the terms of the settlement agreement, the company was to provide warrants to Bay City Partners LLC to purchase 225,000 common shares of stock for a price of $0.10. The company has not issued the warrants and has taken the position that the requirement is unenforceable due to a lack of sufficient definition of the terms of the warrant including in particular, the failure to specify a term of exercise for the warrants.
We have several additional parties suing us for alleged breach of contract and a variety of alleged losses, all of which we consider frivolous lawsuits and without merit or significant liability.
NOTE 6 – NOTES PAYABLE
At December 31, 2005 and 2004, the Company’s notes payable consisted of the following:
|
|
|
December 31 |
|
December 31 |
|
|
|
2005 |
|
2004 |
|
RMS Rubber Machinery Systems AG dated October 4, 2005, unsecured, interest accruing at 6% commencing Jan 1 2006, original amount $1,000,000, outstanding $500,000, matures June 30, 2006. |
$ |
500,000 |
$ |
- |
|
Subscribers to a private placement convertible to common shares at $0.05 upon the Company completing an increase in authorized capital. Converted to common stock Sep 28, 2005. |
|
|
|
375,000 |
|
Robert Haveman, unsecured, interest at 12 %, dated November 22, 2004, converted to common shares June 30, 2005 |
|
- |
|
100,000 |
|
Total |
|
500,000 |
|
475,000 |
|
Less current portion of notes payable |
|
500,000 |
|
475,000 |
|
Total long term portion |
$ |
- |
$ |
- |
F-15
|
|
SNRG Corporation
(Formerly Texen Oil & Gas, Inc.)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
December 31, 2005
NOTE 7 – OIL AND GAS PROPERTIES
The Company’s oil and gas producing activities are subject to laws and regulations controlling not only their exploration and development, but also the effect of such activities on the environment. Compliance with such laws and regulations may necessitate additional capital outlays, affect the economics of a project, and cause changes or delays in the Company’s activities. The Company’s oil and gas properties are valued at the lower of cost or net realizable value.
Brookshire Dome Field
As of December 31, 2005, the Company owns a 96.4% working interest ownership in approximately 24 gross leasehold acres and 16 net leasehold acres located in the Brookshire Dome Field of Waller County, Texas. This working interest ownership position consists of 14 wells drilled to date and one water injection well. As of December 31, 2005, 4 wells were producing or capable of producing oil.
Helen Gohlke Field
The Company owns a 100% working interest and a 70% net revenue interest in approximately 4,346.7 gross leasehold acres which are located under nine different oil, gas and mineral leases in Victoria and DeWitt Counties, Texas. Over 60 wells have been drilled in this field, with 18 wells currently producing or capable of production.
NOTE 8 – OIL AND GAS PRODUCING ACTIVITIES
The Securities and Exchange Commission defines proved oil and gas reserves as those estimated quantities of crude oil, natural gas, and natural gas liquids which geological and engineering data demonstrate with reasonable certainty to be recovered in future years from known reservoirs under existing economic and operating conditions. Proved developed oil and gas reserves are reserves that can be expected to be recovered through existing wells with existing equipment and operating methods. Natural gas reserves and petroleum reserves are estimates. The estimates include reserves in which SNRG and its wholly owned subsidiaries hold an economic interest under lease and operating agreements.
Reserves attributable to certain oil and gas discoveries are not considered proved as of December 31, 2005 due to geological, technical or economic uncertainties. Proved reserves do not include amounts that may result from extensions of currently proved areas or from application of enhanced recovery processes not yet determined to be commercial in specific reservoirs. SNRG and its subsidiaries have no supply contracts to purchase petroleum or natural gas from foreign governments.
The aggregate amounts of capitalized costs relating to oil and gas producing activities and the related accumulated depreciation, depletion and amortization as of December 31, 2005 and 2004 were as follows:
|
|
|
December 31, 2005 |
|
December 31, 2004 |
|
|
|
|
|
|
|
Producing Properties |
$ |
26,667,994 |
$ |
26,162,406 |
|
Accumulated depreciation, depletion and amortization and impairments |
|
(24,454,610) |
|
(24,466,051) |
|
Total capitalized costs |
$ |
2,213,384 |
$ |
1,696,463 |
F-16
|
|
SNRG Corporation
(Formerly Texen Oil & Gas, Inc.)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
December 31, 2005
NOTE 8 – OIL AND GAS PRODUCING ACTIVITIES (continued)
The Company does not currently believe that the calculation of estimated future net revenues and associated reserves using the assumptions prescribed by the Commission guidelines and generally described below is representative of the true value of future net revenues from the Company’s proved reserves. The future prices received by the Company for the sales of its production may be higher or lower than the prices used in calculating the estimates of future net revenues, and the operating costs and other costs relating to such production may also increase or decrease from existing levels.
During the year ending December 31, 2005, the Company purchased the A-207 well on the Charles Kuester lease for a total purchase price of $700,000.
NOTE 9 – CONCENTRATION OF RISK
The Company derives its sales and accounts receivable from primarily three customers and these receivables are not collateralized. At December 31, 2005, the Company’s accounts receivable from these customers totals $230,145 and revenue from the three customers totals $484,000.
NOTE 10 – STOCK OPTIONS
In April 2003, the Company adopted the 2003 Nonqualified Stock Option Plan of SNRG Corporation (formerly Texen Oil & Gas, Inc.) under which 5,000,000 shares of common stock were registered for issuance with respect to awards granted to officers, directors, management, employees and other consultants of the Company and/or its subsidiaries. During 2004 the Company registered a further 5,000,000 shares and a total of 6,350,000 were granted to consultants and 5,600,000 were exercised as of December 31, 2004. No stock options were granted to employees during 2005.
The Company estimates the fair value of each stock option at the grant date by using the Black-Scholes option-pricing model with the following weighted-average assumptions used during the year ended December 31, 2005: dividend yield of zero percent; expected volatility of one hundred and fifty eight percent; risk-free interest rate of four percent. During the year ending December 2005, 750,000 options were granted and exercised in settlement of obligations to consultants in the amount of $97,500.
Following is a summary of the status of these performance-based options during the years ended December 31, 2005 and 2004:
|
|
Number of Shares |
|
Weighted Average Exercise Price per share |
|
Balances June 30, 2004 |
|
|
|
|
Approved and unallocated at June 30, 2004 |
3,500,000 |
|
|
|
Granted and Unexercised June 30, 2004 |
250,000 |
|
0.12 |
|
Approved November 17, 2004 |
5,000,000 |
|
|
|
Granted in period July 1 to December 31, 2004 |
5,100,000 |
|
|
|
Exercised or forfeited in period July 1 to Dec 31, 2004 |
5,350,000 |
|
|
|
Granted and Unexercised Dec 31, 2004 |
- |
|
|
|
Activity during 2005 |
|
|
|
|
Granted and exercised during 2005 |
750,000 |
$ |
0.13 |
|
Granted and Unexercised December 31, 2005 |
- |
|
|
The Company had no outstanding exercisable stock options as of December 31, 2005.
F-17
|
|
SNRG Corporation
(Formerly Texen Oil & Gas, Inc.)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
December 31, 2005
During the period ended December 31, 2004, the Company granted 750,000 options as consideration for services rendered in that period. The options had an exercise price of $0.001 and an estimated fair value of $97,000. Those options ha not been issued at December 31, 2004. The Company made an accrual for this transaction of $97,000 at December 31, 2004. In the year ended December 31, 2005, the options were issued and execised for $750.
NOTE 11 – WARRANTS:
On August 17, 2005 as part of the consideration for the purchase of the membership interests of Port Assets LLC, the company issued 3,000,000 warrants entitling the holders to purchase common shares of the company at a strike price of $0.50 for five years. On November 1, 2005 pursuant to a commitment outstanding relating to a private placement in a prior period, the company issued 500,000 warrants to JPC Capital Partners Inc. entitling the holders to purchase common shares of the company at a strike price of $0.20 for four years.
NOTE 12 – IMPAIRMENT OF LONG-LIVED ASSETS
In accordance with SFAS No. 144, “Accounting for the Impairment or Disposal of Long-Lived Assets,” the Corporation recorded an impairment loss on its oil and gas proved and unproved properties and its leasehold costs of oil and gas producing properties. The engineering reports on the oil and gas properties indicated that the undiscounted future cash flows from these properties would be less than the carrying value of the long-lived assets. The engineer reports also indicated that net leasehold acreage did not support the value carried by the Company. Accordingly, on December 31, 2003, the Company recognized an asset impairment loss of $20,407,559 ($0.46 per share). This loss is the difference between the carrying value of the oil and gas properties and the fair value of these properties based on discounted estimated future cash flows.
The Company engaged an independent consultant to conduct a reserve analysis as of December 31, 2004. Based on the resulting analysis the company recorded a further impairment loss on its oil and gas proved and unproved properties and its leasehold costs of oil and gas producing properties in the amount of $2,505,138 ($.014 per share).
NOTE 13 –PREPAID EXPENSES AND DEPOSITS
The Company has prepaid for a comprehensive, one year term, investor relations contract with WallSt.net in the amount of $250,000. The company has supplied a cash deposit of $50,000 to the Railroad Commission in Texas as a deposit on an operating bond. The company expects to replace the deposit with a bond in 2006. The company has paid a deposit of $100,000 pursuant to oil and gas lease acquisitions in Texas.
NOTE 14 –EXTRAORDINARY ITEM
On August 17, 2005, the Company purchased 100% of the membership interests of Port Assets LLC, the owner of a gasification facility in Bay City TX. Bay City Partners, LLC loaned $2,850,000 of the $3,000,000 purchase price to the company. On August 31, 2005, the company sold 51% of the membership interests in Port Assets LLC to Bay City Partners LLC for the assumption of $2,850,000 of the debt and the company was granted an option to repurchase the 51% interests at a price of $4,415,000 if exercised on or before September 30, 2005, a price of $4,715,000 if exercised thereafter but on or before October 31, 2005 and at a price of $5,015,000 if exercised thereafter but on or before November 30, 2005. During the option period Bay City Partners LLC advanced additional funds for and on behalf of the company and were secured by promissory notes in the amounts of $525,000 and $900,000. The company was not able to secure sufficient financing on terms and conditions acceptable to the company and did not exercise its option to reacquire the 51% membership interest by the expiry date of November 30, 2005.
Texen Holdings LLC, a company controlled by our President, Elroy Fimrite, assisted the company by providing guarantees on the bridge financing provided by Bay City Partners LLC without compensation. Our President, Elroy Fimrite assisted the company by providing personal guarantees on the bridge financing provided by Bay City Partners LLC without compensation.
F-18
|
|
SNRG Corporation
(Formerly Texen Oil & Gas, Inc.)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
December 31, 2005
NOTE 14 –EXTRAORDINARY ITEM (continued)
In December 2005 the company and Texen Holdings LLC, entered into an Omnibus settlement agreement with Bay City Partners LLC and Crown Pacific Advisors LLC providing for the severance of interests in Port Asset LLC, an assignment of our residual 49% membership interest to Bay City Partners LLC and forgiveness by Bay City Partners LLC of promissory notes in the amounts of $525,000 and $900,000. Pursuant to the terms of the settlement agreement, the company was to provide warrants to Bay City Partners LLC to purchase 225,000 common shares of stock for a price of $0.10. The company has taken the position that the requirement is unenforceable due to a lack of sufficient definition of the terms of the warrant including in particular, the failure to specify a term of exercise for the warrants.
The company realized a net gain on settlement and debt forgiveness of $969,147which includes the debt forgiveness of $1,425,000 less the net cost of the Company’s interest in Port Assets, consisting of $150,000 in cash, value of warrants of $235,00 and legal and other acquisition costs of $70,853.
NOTE 15 – INCOME TAXES
The Company recognizes deferred income taxes for the differences between financial accounting and tax bases of assets and liabilities. Income taxes for the year ended December 31, 2005 consisted of the following:
Net deferred tax assets of $11,205,000 were fully offset by a valuation allowance of $11,200,000 and a $5,000 deferred tax liability at December 31, 2005. The deferred income tax assets relate primarily to net operating loss carryforwards and differences in book and tax bases of stock based compensation, impairment reserve and certain accruals. The net deferred income tax asset at December 31, 2005 is comprised of:
F-19
|
|
SNRG Corporation
(Formerly Texen Oil & Gas, Inc.)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
December 31, 2005
NOTE 15 – INCOME TAXES (continued)
Federal net operating loss carryforwards of $3,678,000 expire from 2020 to 2025. Due to the conditions discussed in Note 2, future utilization of the net operating losses is uncertain. The valuation allowance on the deferred income tax asset was decreased by $10,000 in the year ended December 31, 2005.
|
The differences between the statutory and effective tax rates is as follows for the year ended December 31, 2005: |
|
Federal statutory rates |
$ 11,560 |
34% |
|
State income taxes |
2,300 |
6) |
|
Valuation allowance |
(10,000) |
(36)% |
|
Other |
(3,860) |
-% |
|
Effective rate |
$ ( - 0 -) |
0% |
NOTE 16 – SUBSEQUENT EVENTS
On March 31, 2006 we entered into a joint venture letter of intent with Arapahoe Energy Corporation to jointly explore and develop the oil and gas potential on approximately 30,000 acres of land in central Saskatchewan, Canada. Under the terms of the agreement, SNRG will be purchase a 50% interest in the lease for $3,750,000, will fund 50% of a 3-D seismic shoot, and will at our expense drill five exploratory wells.
F-20
|
|
- 25 - |
Item 8. Changes In and Disagreements With Accountants on Accounting and Financial Disclosure
Not applicable.
Item 8A. Controls and Procedures
As required by Rule 13a-15 under the Exchange Act, we have carried out an evaluation of the effectiveness of the design and operation of our company's disclosure controls and procedures as of the end of the period covered by this annual report, being December 31, 2005. This evaluation was carried out under the supervision and with the participation of our company's management, including our company's president and chief executive officer. Based upon that evaluation, our company's president and chief executive officer concluded that our company's disclosure controls and procedures are effective. There have been no changes in our internal controls over financial reporting that occurred during the period covered by this report that have materially affected, or are reasonably likely to materially affect our internal controls over financial reporting.
Disclosure controls and procedures are controls and other procedures that are designed to ensure that information required to be disclosed in our company's reports filed or submitted 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. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed in our company's reports filed under the Exchange Act is accumulated and communicated to management, including our company's president and chief executive officer as appropriate, to allow timely decisions regarding required disclosure.
PART III
Item 9. Directors, Executive Officers, Promoters and Control Persons; Compliance With Section 16(a) of the Exchange Act.
All directors of our company hold office until the next annual general meeting of the shareholders or until their successors are elected and qualified. The officers of our company are appointed by our board of directors and hold office until their earlier death, retirement, resignation or removal.
Our directors, executive officers and other significant employees, their ages, positions held and duration each person has held that position, are as follows:
|
Name |
Position Held with the |
Age |
Date First Elected |
|
D. Elroy Fimrite |
President, Chief Executive Officer, Secretary, Treasurer and Director |
57 |
November 17, 2004 |
|
Carl Buccellato |
Director |
64 |
March 29, 2006 |
|
Douglas Blackman |
Director |
55 |
March 29, 2006 |
Business Experience
The following is a brief account of the education and business experience of each director, executive officer and key employee during at least the past five years, indicating each person’s principal occupation during the period, and the name and principal business of the organization by which he or she was employed.
D. Elroy Fimrite, President, Chief Executive Officer, Secretary, Treasurer and Director
Mr. Fimrite has been the President, Chief Executive Officer, Secretary, Treasurer and a director of our company since November 17, 2004. He also currently serves as the President, Chief Executive Officer and Chairman of the
|
|
- 26 - |
Board of Directors of Landstar, Inc. a position he has held since January 1999. Mr. Fimrite is a professional accountant with over 30 years of diverse business experience including auditing, controllership, treasury, finance, operations management, systems design and development, commercial real estate development and general management. Mr. Fimrite has specialized in work-outs and special situations. During the past ten years he has focused on the troubled rubber recycling industry including the successful liquidation of the world’s largest recycled rubber processor through a series of Chapter eleven and Chapter seven bankruptcy administrations. He is the President and a Director of Rebound Rubber Corp. and serves as an officer and Director of United Trans-Western, Inc., a Delaware public company (under reorganization).
Carl Buccellato, Director
Carl Buccellato of Hollywood FL is a retired senior executive with thirty years of experience in marketing and upper management. Carl has extensive experience in public company governance including co-founding of Ellie Mae, Inc. in 1997 and continuing to serve as a member of the board of directors to the present time. Carl is a successful entrepreneur having founded three start-up companies, developed the business’s to maximize value, sold two and took the third company public. Co-founded, developed and served as Chairman, President and CEO of Homeowners Group, the largest Member Association in the Real Estate Industry with 27,000 realty firms and 247,000 sales agents who were collectively responsible for one in every four resale homes sold in America. Carl also created an innovative insurance product that gained number one market status and served as CEO of the multi national company marketing the product. Carl founded and served as President and CEO of two offshore captive insurance companies, and a publicly traded UK marketing firm.
Douglas Blackman- Director
Doug Blackman, of Vancouver B.C., has over 20 years experience serving the oil and gas industry in legal and business capacities. This experience includes senior positions and/or consulting services with Esso Canada resources, Suncor Inc and BP Resources Canada. Doug has been responsible at a senior level for oil and gas lease and contract negotiation and administration. Doug has also been involved in the industry internationally including negotiating contracts with the Japanese (LPG Contracts) and with the Koreans (Coal contracts) and negotiating oil and gas leases and offshore agreements in New Zealand.
Significant Employees
D. Elroy Fimrite is a significant employee and the loss of this employee would have an adverse impact on our future developments and could impair our ability to succeed.
Family Relationships
There are no family relationships among our directors or officers.
Involvement in Certain Legal Proceedings
Our directors, executive officers and control persons have been involved in the following events during the past five years:
|
|
1. |
Mr. Fimrite has been an Officer and Director of numerous entities that have filed various bankruptcy petitions principally related to involvement in corporate restructuring and involvement in the troubled rubber recycling industry; |
|
|
2. |
Mr. Fimrite has been an Officer and Director of various entities that have been subject to foreclosure actions principally related to involvement in distressed real estate properties, corporate restructuring and involvement in the troubled rubber recycling industry; |
Our directors, executive officers and control persons have not been involved in any of the following events during the past five years:
1. any conviction in a criminal proceeding or being subject to a pending criminal proceeding (excluding traffic violations and other minor offenses);
|
|
- 27 - |
2. being subject to any order, judgment, or decree, not subsequently reversed, suspended or vacated, of any court of competent jurisdiction, permanently or temporarily enjoining, barring, suspending or otherwise limiting his involvement in any type of business, securities or banking activities; or
3. being found by a court of competent jurisdiction (in a civil action), the Commission or the Commodity Futures Trading Commission to have violated a federal or state securities or commodities law, and the judgment has not been reversed, suspended, or vacated.
Audit Committee Financial Expert
Our Board of Directors has determined that it does not have a member of its audit committee that qualifies as an “audit committee financial expert” as defined in Item 401(e) of Regulation S-B, and is “independent” as the term is used in Item 7(d)(3)(iv) of Schedule 14A under the Securities Exchange Act of 1934, as amended.
We believe that the members of our Board of Directors are collectively capable of analyzing and evaluating our financial statements and understanding internal controls and procedures for financial reporting. In addition, we believe that retaining an independent director who would qualify as an “audit committee financial expert” would be overly costly and burdensome and is not warranted in our circumstances given the early stages of our development and the fact that we have only recently began to generate revenues.
Compliance with Section 16(a) of the Securities Exchange Act of 1934
Section 16(a) of the Securities Exchange Act of 1934, as amended, requires our executive officers and directors and persons who own more than 10% of a registered class of our equity securities to file with the Securities and Exchange Commission initial statements of beneficial ownership, reports of changes in ownership and annual reports concerning their ownership of our common stock and other equity securities, on Forms 3, 4 and 5 respectively. Executive officers, directors and greater than 10% shareholders are required by the Securities and Exchange Commission regulations to furnish our company with copies of all Section 16(a) reports they file.
To the best of our knowledge, all executive officers, directors and greater than 10% shareholders filed the required reports in a timely manner.
Code of Ethics
Effective November 12, 2003, our company's board of directors adopted a Code of Business Conduct and Ethics that applies to, among other persons, our company's president (being our principal executive officer) and our company's secretary (being our principal financial and accounting officer and controller), as well as persons performing similar functions. As adopted, our Code of Business Conduct and Ethics sets forth written standards that are designed to deter wrongdoing and to promote:
(1) honest and ethical conduct, including the ethical handling of actual or apparent conflicts of interest between personal and professional relationships;
(2) full, fair, accurate, timely, and understandable disclosure in reports and documents that we file with, or submit to, the Securities and Exchange Commission and in other public communications made by us;
(3) compliance with applicable governmental laws, rules and regulations;
(4) the prompt internal reporting of violations of the Code of Business Conduct and Ethics to an appropriate person or persons identified in the Code of Business Conduct and Ethics; and
(5) accountability for adherence to the Code of Business Conduct and Ethics.
Our Code of Business Conduct and Ethics requires, among other things, that all of our company's personnel shall be accorded full access to our president and secretary with respect to any matter which may arise relating to the Code of Business Conduct and Ethics. Further, all of our company's personnel are to be accorded full access to our company's board of directors if any such matter involves an alleged breach of the Code of Business Conduct and Ethics by our president or secretary.
|
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- 28 - |
In addition, our Code of Business Conduct and Ethics emphasizes that all employees, and particularly managers and/or supervisors, have a responsibility for maintaining financial integrity within our company, consistent with generally accepted accounting principles, and federal , provincial and state securities laws. Any employee who becomes aware of any incidents involving financial or accounting manipulation or other irregularities, whether by witnessing the incident or being told of it, must report it to his or her immediate supervisor or to our company's president or secretary. If the incident involves an alleged breach of the Code of Business Conduct and Ethics by the president or secretary, the incident must be reported to any member of our board of directors. Any failure to report such inappropriate or irregular conduct of others is to be treated as a severe disciplinary matter. It is against our company policy to retaliate against any individual who reports in good faith the violation or potential violation of our company's Code of Business Conduct and Ethics by another.
Our Code of Business Conduct and Ethics was filed with the Securities and Exchange Commission on November 12, 2003 as Exhibit 14.1 to our annual report for the year ended June 30, 2003 . We will provide a copy of the Code of Business Conduct and Ethics to any person without charge, upon request. Requests can be sent to: SNRG Corporation, 14300 N Northsight Blvd, Ste 227, Scottsdale, AZ 85260.
Item 10. Executive Compensation.
Particulars of compensation awarded to, earned by or paid to:
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(a) |
our chief executive officer; |
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(b) |
each of our four most highly compensated executive officers who were serving as executive officers at the end of the most recently completed fiscal year and whose total salary and bonus exceeds $100,000 per year, or |
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(c) |
any additional individuals for whom disclosure would have been provided under (b) but for the fact that the individual was not serving as an executive officer of our company at the end of the most recently completed fiscal year; |
(the "Named Executive Officers") are set out in the summary compensation table below.
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SUMMARY COMPENSATION TABLE | ||||||||
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Annual Compensation |
Long Term Compensation (1) |
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Awards |
Payouts |
| |
|
Name and Principal |
Year |
Salary |
Bonus |
Other |
Securities |
Restricted |
LTIP |
All Other |
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D. Elroy Fimrite |
2005 |
Nil |
Nil |
Nil |
Nil |
Nil |
Nil |
Nil |
|
David Michael Sims |
2005 |
Nil |
Nil |
Nil |
Nil |
Nil |
Nil |
Nil |
|
Tatiana Golovina |
2005 |
Nil |
Nil |
Nil |
Nil |
Nil |
Nil |
Nil |
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|
Robert M. Baker |
2005 |
Nil |
Nil |
Nil |
Nil |
Nil |
Nil |
Nil |
(1) The value of perquisites and other personal benefits, securities and property for the Named Executive Officers that do not exceed the lesser of $50,000 or 10% of the total of the annual salary and bonus is not reported herein.
(2) Mr. Fimrite has served as our President, CEO, Secretary and Treasurer since November 17, 2004.
(3) Mr. Sims resigned as the President, CEO, Secretary and Treasurer on November 17, 2004 and was appointed as the Chairman of the Board on November 17, 2004. Mr Sims resigned as Director and Chairman of the Board on May 18, 2005
(4) Ms. Golovina resigned as our President, CEO, Secretary and Treasurer On July 21, 2004. Ms. Golovina resigned as Director on May 18, 2005
The following table sets forth for each of the Named Executive Officers certain information concerning stock options granted to them during fiscal 2005. We have never issued stock appreciation rights.
OPTION/SAR GRANTS IN THE LAST FISCAL YEAR
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Number of |
% of Total |
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None |
- |
100% |
N/A |
- |
The following table sets forth for each Named Executive Officer certain information concerning the number of shares subject to both exercisable and unexercisable stock options as of December 31, 2005.
AGGREGATED OPTION/SAR EXERCISES IN LAST FISCAL YEAR AND FY-END OPTION/SAR VALUES
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Exercisable |
Unexercisable |
Exercisable |
Unexercisable |
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None |
Nil |
N/A |
0 |
0 |
$0 |
$0 |
(1) The values for “in-the-money” options are calculated by determining the difference between the fair market value of the securities underlying the options as of December 31, 2005 ($0.12 per share on NASD OTCBB) and the exercise price of the individual’s options.
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EMPLOYMENT CONTRACTS AND TERMINATION OF EMPLOYMENT AND CHANGE IN CONTROL ARRANGEMENTS
There are no employment agreements between us and the Named Executive Officers.
Our company has no plans or arrangements in respect of remuneration received or that may be received by Named Executive Officers of our company in fiscal 2005 to compensate such officers in the event of termination of employment (as a result of resignation, retirement, change of control) or a change of responsibilities following a change of control, where the value of such compensation exceeds $100,000 per Named Executive Officer.
COMPENSATION OF DIRECTORS AND EXECUTIVE OFFICERS
Our Directors do not receive salaries or fees for serving as directors, nor do they receive any compensation for attending meetings of the Board of Directors or serving on committees of the Board of Directors. We may, however, determine to compensate our directors in the future. Directors are entitled to reimbursement of expenses incurred in attending meetings. In addition, our directors are entitled to participate in our stock option plan.
During the year ended December 31, 2005 we paid $Nil to D Elroy Fimrite for the services he provided to our company in his capacity as President, CEO, Secretary, Treasurer and a director of our company.
There are no arrangements or plans in which we provide pension, retirement or similar benefits for directors or executive officers.
During the year ended December 31, 2003 we established a stock option plan pursuant to which 5,000,000 common shares were reserved for issuance. On November 16, 2004 we amended our stock option plan to increase the number of shares reserved for issuance to 10,000,000 common shares.
Stock options become exercisable at dates determined by the Board of Directors at the time of granting the option and have initial terms of ten years.
We have no plans or arrangements in respect of remuneration received or that may be received by our executive officers to compensate such officers in the event of termination of employment (as a result of resignation, retirement, change of control) or a change of responsibilities following a change of control, where the value of such compensation exceeds $60,000 per executive officer.
There are no arrangements or plans in which we provide pension, retirement or similar benefits for directors or executive officers. We have no material bonus or profit sharing plans pursuant to which cash or non-cash compensation is or may be paid to our directors or executive officers, except that stock options may be granted at the discretion of the Board of Directors or a committee thereof.
Item 11. Security Ownership of Certain Beneficial Owners and Management.
The following table sets forth, as of March 31, 2006, certain information with respect to the beneficial ownership of our common shares by each shareholder known to us to be the beneficial owner of 5% of our common shares, and by each of our officers and directors. Each person has sole voting and investment power with respect to the common shares, except as otherwise indicated. Beneficial ownership consists of a direct interest in the common shares, except as otherwise indicated.
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Name and Address of Beneficial Owner |
Amount and Nature of |
Percentage |
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D. Elroy Fimrite (2) |
61,165,664 |
33% |
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Texen Holdings LLC |
61,165,664 |
33% |
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Robert Haveman |
16,850,000 |
9% |
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Carl Buccellato |
2,000,000 |
1% |
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Directors and Executive Officers as a Group |
63,165,664 |
34 % |
(1) Based on 184,220,866 shares of common stock issued and outstanding as of March 31, 2006. Beneficial ownership is determined in accordance with the rules of the SEC and generally includes voting or investment power with respect to securities. Except as otherwise indicated, we believe that the beneficial owners of the common stock listed above, based on information furnished by such owners, have sole investment and voting power with respect to such shares, subject to community property laws where applicable.
(2) Includes 61,165,664 shares of common stock held of record by Texen Holdings LLC., a Limited Liability Company and for which Mr. Fimrite serves as managing member; Mr. Fimrite disclaims beneficial ownership over all of such shares except to the extent of his pecuniary interest therein.
Equity Compensation Plan Information
As at December 31, 2005 we have one compensation plan in place, entitled 2003 Nonqualified Stock Option Plan. This plan has not been approved by our security holders.
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Number of Securities to be issued upon exercise of outstanding options |
Weighted-Average exercise price of outstanding options |
Number of securities remaining available for further issuance |
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Nil |
$N/A |
3,650,000 |
Changes in Control
We are unaware of any contract or other arrangement the operation of which may at a subsequent date result in a change in control of our company.
Item 12. Certain Relationships and Related Transactions.
Other than as disclosed below, there have been no transactions, or proposed transactions, which have materially affected or will materially affect us in which any director, executive officer or beneficial holder of more than 10% of the outstanding common stock, or any of their respective relatives, spouses, associates or affiliates, has had or will have any direct or material indirect interest.
During 2005 Texen Holdings LLC, of which Mr. Fimrite is Managing Member, provided capital from time to time to our company resulting in a net loan to our company on December 31, 2005 of $472,439. On December 30, 2005 Texen Holdings LLC purchased 14,000,000 shares of common stock of our company for a purchase price of $700,000.
Item 13. Exhibits
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Exhibit |
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3.1 |
Articles of Incorporation (1) |
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3.2 |
Bylaws (1) |
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3.3 |
Amendment to the Articles of Corporation (2) |
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3.4 |
Articles of Incorporation of Texas Brookshire Partners, Inc.(6) |
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3.5 |
Bylaws of Texas Brookshire Partners (6) |
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3.6 |
Articles of Incorporation of Texas Gholke Partners, Inc. (6) |
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3.7 |
Bylaws of Texas Gohlke Partners, Inc. (6) |
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4.1 |
Specimen Stock Certificate (1) |
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10.1 |
Stock Purchase Agreement (2) |
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10.2 |
Share Exchange Agreement (4) |
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10.3 |
Stock Purchase Agreement and Assignment of Interest from Sanka, LTD. (Trull Heirs #1 Well) (5) |
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10.4 |
Stock Subscription Agreement from Yegua, Inc. (5) |
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10.5 |
Stock Subscription Agreement – Brookshire Drilling Service LLC (5) |
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10.6 |
Share Exchange Agreement – Texas Gohlke Partners, Inc. (5) |
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10.7 |
Stock Subscription Agreement – Sanka LLC (5) |
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10.8 |
Assignment of Oil – Sanka Exploration Company (5) |
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10.9 |
Stock Subscription Agreement – Sanka Ltd. (6) |
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10.10 |
Assignment of Oil – Sank Exploration Company (6) |
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10.11 |
2003 Nonqualified Stock Option Plan (7) |
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10.12 |
Marketing Contract (8) |
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10.13 |
Lease Agreement with Insite Realty for office space (10) |
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10.15 |
Stock Purchase Agreement (10) |
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14.1 |
Code of Business Conduct and Ethics (9) |
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21.1 |
We have the following subsidiaries: |
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31.1* |
Section 302 Certification under Sarbanes-Oxley Act of 2002 for D. Elroy Fimrite |
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32.1* |
Section 906 Certification under Sarbanes-Oxley Act of 2002 for D. Elroy Fimrite |
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*Filed herewith.
(1) Incorporated by reference to our Form SB-2 Registration Statement filed with the Securities and Exchange Commission on January 13, 2000.
(2) Incorporated by reference to our Form 8-K filed with the Securities and Exchange Commission on February 22, 2002.
(3) Incorporated by reference to our Form 8-K filed with the Securities and Exchange Commission on May 17, 2002.
(4) Incorporated by reference to our Form 8-K filed with the Securities and Exchange Commission on July 26, 2002.
(5) Incorporated by reference to our Form 8-K filed with the Securities and Exchange Commission on September 17, 2002.
(6) Incorporated by reference to our Form 8-K filed with the Securities and Exchange Commission on October 4, 2002.
(7) Incorporated by reference to our Form S-8 filed with the Securities and Exchange Commission on April 11, 2003.
(8) Incorporated by reference to our Form 8-K Registration Statement filed with the Securities and Exchange Commission on July 9, 2003, as amended.
(9) Incorporated by reference to our Form 10-KSB Annual Report filed with the Securities and Exchange Commission on November 12, 2003.
(10) Incorporated by reference to our Form 10-KSB Annual Report filed with the Securities and Exchange Commission on November 30, 2004.
(11) Incorporated by reference to our Form 10-KSB Annual Report filed with the Securities and Exchange Commission on May 20, 2005.
Item 14. Principal Accountant Fees and Services
Audit Fees
Our board of directors has appointed Epstein Weber & Conover, PLC, Certified Public Accountants, as independent auditors to audit our financial statements for the current fiscal year. The aggregate fees billed by Epstein Weber & Conover, PLC for professional services rendered for the audit of our annual financial statements included in this Annual Report on Form 10-KSB for the fiscal years ended December 31, 2005 are $22,885.
The aggregate fees billed by Williams & Webster, our previous auditors, for professional services rendered for the audit of our annual financial statements included in this Annual Report on Form 10-KSB for the fiscal years ended December 31, 2004 are $23,242.
Audit Related Fees
For the fiscal year ended December 31, 2005, the aggregate fees billed for assurance and related services by Epstein Weber & Conover, PLC relating to our quarterly financial statements which are not reported under the caption "Audit Fees" above, were $2,800.00.
For the fiscal year ended December 31, 2005, the aggregate fees billed for assurance and related services by Williams & Webster, our previous auditor, relating to our quarterly financial statements for March 31,2005 and June 30, 2005, which are not reported under the caption "Audit Fees" above, were $10,871.
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Tax Fees
For the fiscal year ended December 31, 2005, the aggregate fees billed for tax compliance, by Epstein Weber & Conover, PLC were $Nil.
All Other Fees
For the fiscal year ended December 31, 2005 the aggregate fees billed by Epstein Weber & Conover, PLC for other non-audit professional services, other than those services listed above, totaled $ Nil.
Effective May 6, 2003, the Securities and Exchange Commission adopted rules that require that before Epstein Weber & Conover, PLC is engaged by us or our subsidiaries to render any auditing or permitted non-audit related service, the engagement be:
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• |
approved by our audit committee; or |
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• |
entered into pursuant to pre-approval policies and procedures established by the audit committee, provided the policies and procedures are detailed as to the particular service, the audit committee is informed of each service, and such policies and procedures do not include delegation of the audit committee's responsibilities to management. |
The audit committee pre-approves all services provided by our independent auditors. The pre-approval process has just been implemented in response to the new rules. Therefore, the audit committee does not have records of what percentage of the above fees were pre-approved. However, all of the above services and fees were reviewed and approved by the audit committee either before or after the respective services were rendered.
The audit committee has considered the nature and amount of the fees billed by Epstein Weber & Conover, PLC, and believes that the provision of the services for activities unrelated to the audit is compatible with maintaining Epstein Weber & Conover, PLC independence.
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SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) 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.
SNRG CORPORATION
/s/ D. Elroy Fimrite
By: D. Elroy Fimrite, President, Chief Executive
Officer, Secretary, Treasurer and Director
(Principal Executive Officer and Principal Financial Officer and Principal Accounting Officer)
May 3, 2006
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.
/s/ D. Elroy Fimrite
D. Elroy Fimrite, President, Chief Executive
Officer, Secretary, Treasurer and Director
(Principal Executive Officer and Principal Financial Officer and Principal Accounting Officer)
May 3, 2006