UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, DC 20549

 

FORM 10-K

 

                For the fiscal year ended March 31, 2008

 

                For the Transition Period From ________ to _________

 

Commission File Number 001-33034

 

BMB MUNAI, INC.

(Exact name of registrant as specified in its charter)

 

 

+7 (7272) 375-125

(Registrant’s telephone number, including area code)

 

Securities registered under Section 12(b) of the Exchange Act:

 

 

 

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of

 

Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d)

of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the

 

 

 

 

 

 

As of September 30, 2007 the aggregate market value of the common voting stock held by non-affiliates of the issuer based upon the closing stock price of $5.63 per share was approximately $197,973,241.

 

As of June 10, 2008, the registrant had 44,784,134 shares of common stock, par value $0.001, issued and outstanding.

 

Documents Incorporated by Reference

Portions of the registrant's proxy statement for the 2008 annual meeting of stockholder are incorporated by reference in Part II, Item 5.

 

 

Table of Contents

 

 

 

BMB MUNAI, INC.

 

Unless otherwise indicated by the context, references herein to the “Company”, “BMB”, “we”, our” or “us” means BMB Munai, Inc, a Nevada corporation, and its corporate subsidiaries and predecessors.

 

Forward Looking Information

 

This report includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. Certain statements contained in all parts of this document including, but not limited to, those relating to our drilling plans, future expenses, changes in wells operated and reserves, future growth and expansion, future exploration, future seismic data, expansion of operations, our ability to generate new prospects, our ability to obtain a production license, review of outside generated prospects and acquisitions, additional reserves and reserve increases, managing our asset base, expansion and improvement of capabilities, integration of new technology into operations, credit facilities, new prospects and drilling locations, future capital expenditures and working capital, sufficiency of future working capital, borrowings, our ability to repay borrowings, capital resources and liquidity, projected cash flows from operations, future commodity price environment, expectations of timing, the outcome of legal proceedings, satisfaction of contingencies, the impact of any change in accounting policies on our financial statements, the number, timing or results of any wells, the plans for timing, interpretation and results of new or existing seismic surveys or seismic data, future production or reserves, future acquisitions of leases, lease options or other land rights, management’s assessment of internal control over financial reporting, financial results, opportunities, growth, business plans and strategy and other statements that are not historical facts contained in this report are forward-looking statements. When used in this document, words like “expect,” “project,” “estimate,” “believe,” “anticipate,” “intend,” “budget,” “plan,” “forecast,” “predict,” “may,” “should,” “could,” “will” and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, market factors, market prices (including regional basis differentials) of natural gas and oil, results for future drilling and marketing activity, future production and costs and other factors detailed herein and in our other Securities and Exchange Commission filings. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. These forward-looking statements speak only as of their dates and should not be unduly relied upon. We undertake no obligation to publicly update or revise any forward-looking statement, whether as a result of new information, future events or otherwise.

 

Throughout this annual report all references to dollar amounts ($) refers to U.S. dollars unless otherwise indicated.

 

 

PART I

 

Item 1. Business

 

Overview

 

     BMB Munai, Inc. is an independent oil and natural gas company engaged in the exploration, development, acquisition and production of crude oil and natural gas properties in the Republic of Kazakhstan (sometimes also referred to herein as the “ROK” or “Kazakhstan”). We hold an exploration contract that allows us to explore and develop approximately 460 square kilometers in western Kazakhstan located onshore in the Mangistau Oblast, approximately 50 kilometers from the Kazakhstan city of Aktau, a seaport on the Caspian Sea.

 

We generate revenue by producing and selling crude oil under our exploration contract. We make significant capital expenditures in our exploration and development activities as required by the exploration contract. Our drilling activities consist of drilling a combination of exploratory wells to delineate reservoir structures and development wells which provide significant revenue to the Company. Our operational focus is on increasing our oil reserves by transitioning resources to reserve categories and proved undeveloped reserves to proved developed reserves. These activities have allowed us to increase daily test production resulting substantial growth in revenue.

 

To date, we have relied primarily on funds raised through the sale of our equity securities, issuing convertible notes and internally generated income to fund our activities. Although presently the revenues derived from our properties are sufficient to meet our operating needs we anticipate that our drilling program will continue to incur capital expenses in excess of internally generated funds.

 

Industry and Economic Factors

 

In managing our business, we must deal with many factors inherent in our industry. First and foremost is the fluctuation of oil and gas prices. Historically, oil and gas markets have been cyclical and volatile, with future price movements that are difficult to predict. While our revenues are a function of both production and prices, wide swings in commodity prices will likely have a significant impact on our results of operations. We have not elected to engage in hedging transactions because the oil and gas industry is in a period of high commodity prices that has positively impacted our Company.

 

Our operations entail significant complexities. Advanced technologies requiring highly trained personnel are utilized in both exploration and development. Even when the technology is properly used, we still may not know conclusively whether hydrocarbons will be present nor the rate at which they may be produced when wells are in place. Despite our best efforts to limit risk, exploration is a high-risk activity, often times resulting in no discovery of commercially productive reserves.

 

Our business, as with other extractive industries, depletes our reserves and therefore oil and gas produced must be replaced for our Company to remain viable. During the past fiscal year we have realized a net increase in our reserves.

 

 

Strategy

 

Our goal is to increase stockholder value by investing in oil and natural gas projects with attractive rates of return on capital employed. We seek to achieve this goal by exploiting and developing our existing oil and gas properties and pursuing the acquisition of additional properties. We have and will continue to focus on the following:

 

Increasing our Production and Cash Flow. To sustain our operations we need capital. To date most of our operating capital has come from the sale of equity and debt securities. We believe that to increase shareholder value and economic stability, we must increase our revenues through increased production. For this reason, we have focused our efforts on drilling additional developmental wells strategically located within proved areas with the intent to drill wells with a high probability of success. We believe this strategy has and will allow us to increase our current production and correspondingly our cash flows.

 

Developing and Exploiting Existing Properties. We believe that there is significant value to be created by drilling the identified undeveloped opportunities on our properties. We own interest in 780 gross (780 net) proved developed producing acres, plus 660 gross (660 net) acres of proved undeveloped reserves. We also own interest in approximately 112,230 gross (112,230 net) unproved, undeveloped acres. We plan to continue exploration, development, test production and further infrastructure development during the 2009 fiscal year. We expect to fund our expenditures with future production revenues and commercial debt.

 

Pursuing Profitable Acquisitions. While our emphasis in fiscal 2009 is anticipated to focus on the further development of our existing properties, we will continue to look for properties with both existing cash flow from production and future development potential. We intend to pursue acquisitions of properties that we believe will provide attractive rates of return on capital invested. We work with consultants and our staff of experienced management professionals to identify and evaluate acquisition opportunities.

 

Oil and Natural Gas Reserves

 

The following table sets forth our estimated net proved oil and natural gas reserves and the standardized measure of discounted future net cash flows related to such reserves as of March 31, 2008. We engaged Chapman Petroleum Engineering, Ltd. (“Chapman”), to estimate our net proved reserves, projected future production and the standardized measure of discounted future net cash flows as of March 31, 2008. Chapman’s estimates are based upon a review of production histories and other geologic, economic, ownership and engineering data provided by us. Chapman has independently evaluated our reserves for the past several years. In estimating the reserve quantities that are economically recoverable, Chapman used oil and natural gas prices in effect as of March 31, 2008 without giving effect to hedging activities. In accordance with requirements of the Securities and Exchange Commission (the “SEC”) regulations, no price or cost escalation or reduction was considered by Chapman. The standardized measure of discounted future net cash flows is not intended to represent the current market value of our estimated oil and natural gas reserves. The oil and natural gas reserve data included in, or incorporated by reference in this document, are only estimates and may prove to be inaccurate.

 

 

 

   

 

The reserve data set forth herein represents estimates only. Reserve engineering is a subjective process of estimating underground accumulations of oil and natural gas that cannot be measured in an exact manner. The accuracy of any reserve estimate is a function of the quality of available data and of engineering and geological interpretation and judgment. As a result, estimates made by different engineers often vary. In addition, results of drilling, testing and production subsequent to the date of an estimate may justify revision of such estimates, and such revisions may be material. Accordingly, reserve estimates are generally different from the quantities of oil and natural gas that are ultimately recovered. Furthermore, the estimated future net revenue from proved reserves and the present value thereof are based upon certain assumptions, including current prices, production levels and costs that may vary from what is actually incurred or realized.

 

No estimates of proved reserves comparable to those included herein have been included in reports to any federal agency other than the SEC.

 

In accordance with SEC regulations, the Chapman Report used oil and natural gas prices in effect at March 31, 2008. The prices used in calculating the standardized measure of discounted future net cash flows attributable to proved reserves do not necessarily reflect market prices for oil and natural gas production subsequent to March 31, 2008. There can be no assurance that all of the proved reserves will be produced and sold within the periods indicated, that the assumed prices will actually be realized for such production or that existing contracts will be honored or judicially enforced.

 

 

Marketing and Sales to Major Customers

 

There are a variety of factors which affect the market for oil and natural gas, including the extent of domestic production and imports of oil and natural gas, the availability, proximity and capacity of natural gas pipelines and other transportation facilities, demand for oil and natural gas, the marketing of competitive fuels and the effects of state and federal regulations on oil and natural gas productions and sales.

 

In the exploration, development and production business, production is normally sold to relatively few customers. We are now exporting nearly all of our test production for sale in the world market. Currently, 91% of our production is being sold to one client, Euro-Asian Oil AG. Revenue from oil sold to Euro-Asian Oil made up 96% of our total revenue. However, based on the current demand for crude oil and the fact that alternate purchasers are readily available, we believe that the loss of Euro-Asian Oil AG would not have a long–term material adverse effect on our operations.

 

Since July 2007 our monthly production volumes have exceeded our export quotas. We have been selling this excess production to the domestic market in Kazakhstan. Oil prices in the domestic market are regulated by the government of Kazakhstan. Historic and current sales prices in the domestic market have and currently are significantly lower than the prevailing world market price.

 

Our crude oil exports are transported via the Aktau sea port to world markets. Sales prices at the port location are based on the average quoted Brent crude oil price from Platt's Crude Oil Marketwire for the three days following the bill of lading date less a discount for transportation expenses, freight charges and other expenses borne by the customer.

 

Competition

 

Competition in Kazakhstan and Central Asia includes other junior hydrocarbons exploration companies, mid-size producers and major exploration and production companies. We compete for additional exploration and production properties with these companies who in many cases have greater financial resources and larger technical staffs than we do.

 

We face significant competition for capital from other exploration and production companies and industry sectors. At times, other industry sectors may be more in favor with investors, limiting our ability to obtain necessary capital. However, we expect that our success and market exposure during the past several years has positioned us to seek financing to meet our business objectives.

 

We believe we have a competitive advantage in Kazakhstan in that our management team is comprised of Kazakh nationals who have developed trusted relationships with many of the departments and ministries within the government of Kazakhstan.

 

Government Regulation

 

Our operations are subject to various levels of government controls and regulations in both the United States and Kazakhstan.  We focus on compliance with all legal requirements in the conduct of our operations

 

 

and employ business practices that we consider to be prudent under the circumstances in which we operate.  It is not possible for us to separately calculate the costs of compliance with environmental and other governmental regulations as such costs are an integral part of our operations.

 

In Kazakhstan, legislation affecting the oil and gas industry is under constant review for amendment or expansion.  Pursuant to such legislation, various governmental departments and agencies have issued extensive rules and regulations which affect the oil and gas industry, some of which carry substantial penalties for failure to comply.  These laws and regulations can have a significant impact on the industry by increasing the cost of doing business by imposition of new taxes and duties that can adversely affect our profitability.  Inasmuch as new legislation affecting the industry is commonplace and existing laws and regulations are frequently amended or reinterpreted, we are unable to predict the future cost or impact of complying with such laws and regulations.

 

Employees

 

We have approximately 330 full-time employees. None of our employees are covered by collective bargaining agreements. From time to time we utilize the services of independent consultants and contractors to perform various professional services. Field and on-site production operation services, such as pumping, maintenance, dispatching, inspection and testing are generally provided by independent contractors.

 

Executive Offices

 

Our principal executive and corporate offices are located in an office building located at 202 Dostyk Avenue, in Almaty, Kakzakhstan. We lease this space and believe it is sufficient to meet our needs for the foreseeable future.

 

We also maintain an administrative office in Salt Lake City, Utah. The address is 324 South 400 West, Suite 225, Salt Lake City, Utah 84101, USA.

 

Reports to Security holders

 

We file Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and other items with the Securities and Exchange Commission (“SEC”). We provide free access to all of these SEC filings, as soon as reasonably practicable after filing, on our Internet web site located at www.bmbmunai.com. In addition, the public may read and copy any documents we file with the SEC at the SEC's Public Reference Room at 100 F Street N.E., Washington, DC 20549. The public may obtain information on the operation of the Public Reference Room by calling the SEC at 1-800-SEC-0330. The SEC maintains its Internet site www.sec.gov, which contains reports, proxy and information statements and other information regarding issuers like BMB Munai.

 

 

 

A substantial or extended decline in oil prices may adversely affect our business, financial condition, cash flow, liquidity or results of operations, our ability to meet our capital expenditure obligations and financial commitments or to implement our business strategy.

 

Our business is heavily dependent upon the price of and demand for oil production. The level of such production will be subject to wide fluctuations and depend on numerous factors beyond our control, including the following:

 

 

Any continued or extended decline in the price of crude oil or natural gas will adversely affect:

 

 

In December 2005 we were granted our first export quota from the Ministry of Energy and Mineral Resources of the Republic of Kazakhstan (“MEMR”), which allowed us to begin exporting oil for sale in the world market in January 2006. We have applied for and been granted an export quota each month since, with the exception of February 2006, when we did not apply for a quota. Prior to January 2006, we were limited to selling our test production to the domestic market in Kazakhstan. The price of oil in the domestic market in Kazakhstan is substantially lower than the price in the world market. There is no guarantee that the Republic of Kazakhstan will continue to grant us export quotas in the future. In the event we are not granted an export quota in the future, we will be limited to selling our production to the domestic Kazakhstan market, which would result in us realizing lower revenue per barrel of oil sold than we could realize in the world market.

 

We have not entered into crude oil hedging arrangements on any of our anticipated sales. However, in the future we may enter into such arrangements in order to reduce our exposure to price risks. Such arrangements may limit our ability to benefit from increases in oil prices.

 

Reserve estimates depend on many assumptions that may turn out to be inaccurate. Any material inaccuracies in these reserve estimates or underlying assumptions will materially affect the size and present value of our reserves.

 

The process of estimating oil and natural gas reserves is complex. It requires interpretations of available technical data and many assumptions, including assumptions relating to economic factors. Any significant inaccuracies in these interpretations or assumptions could materially affect the estimated quantities and present value of reserves shown in this report.

 

 

 

In order to prepare estimates, we must project production rates and timing of development expenditures. We must also analyze available geological, geophysical, production and engineering data. The extent, quality and reliability of this data can vary. The process also requires economic assumptions about matters such as oil and natural gas prices, drilling and operating expenses, capital expenditures, taxes and availability of funds. Therefore, estimates of oil and natural gas reserves are inherently imprecise.

 

Actual future production, oil and natural gas prices, revenues, taxes, development expenditures, operating expenses and quantities of recoverable oil and natural gas reserves most likely will vary from our estimates. Any significant variance could materially affect the estimated quantities and present value of reserves shown in this report. In addition, we may adjust estimates of proved reserves to reflect production history, results of exploration and development, prevailing oil and natural gas prices and other factors, many of which are beyond our control.

 

You should not assume that the present value of future net revenues from our proved reserves referred to in this report is the current market value of our estimated oil and natural gas reserves. In accordance with SEC requirements, we generally base the estimated discounted future net cash flows from our proved reserves on prices and costs on the date of the estimate. Actual future prices and costs may differ materially from those used in the present value estimate. If future values decline or costs increase, it could have a negative impact on our ability to finance operations; individual properties could cease being commercially viable; affecting our decision to continue operations on producing properties or to attempt to develop properties. All of these factors would have a negative impact on earnings and net income, and most likely the trading price of our securities.

 

Forty eight percent of our proven properties are undeveloped; therefore the risk associated with our success is greater than would be the case if all of our properties were categorized as “proved developed producing.”

 

Because a portion of our proved reserves (approximately 48%) are “Proved Undeveloped” additional capital for the drilling and completion of additional wells will be required before these reserves become productive. Further, because of the inherent uncertainties associated with drilling for oil and gas, additional wells may never be developed to the extent that they develop into positive cash flow. Even if we are successful in our development efforts, it could take several years to achieve positive cash flow from our proved undeveloped reserves.

 

We will be unable to produce up to 94% of our proved reserves if we are not able to obtain a commercial production contract or extend our current exploration contract, which would likely require us to terminate our operations.

 

Under our exploration contract on our properties we have the right to produce oil and gas only until July 2009, yet 94% of our proved reserves are scheduled to be produced after July 2009. We have the exclusive right to negotiate a commercial production contract as per the terms of our exploration contract. The MEMR does not make public its determinations on the granting of commercial production rights. Based on discussions

 

 

with the MEMR, we have learned that the primary factors used by the MEMR in determining whether to grant commercial production rights are whether the contract holder has fulfilled its minimum work program commitments, proof of commercial discovery and submission of an approved development plan by a third-party petroleum institute in Kazakhstan to exploit the established commercial reserves. Typically, if commercial production rights are not granted it is because the contract holder has failed to make a commercial discovery within their contract territory and had decided to abandon the contract territory or the contract holder has insufficient funds to complete its minimum work program requirement and was unable to complete the necessary work to substantiate the presence of commercially producible reserves to the MEMR. Our efforts are focused toward meeting our minimum work program requirements and making and substantiating commercial discoveries in as many of the identified structures as possible to support our application for commercial production rights. If we are not granted commercial production rights prior to the expiration of our exploration contract, we may lose our right to produce the reserves on our current properties. If we are unable to produce those reserves, we will be unable to realize revenues and earnings and to fund operations and we would most likely be unable to continue as a going concern.

 

Prospects that we decide to drill may not yield oil or natural gas in commercially viable quantities or quantities sufficient to meet our targeted rate of return.

 

A “prospect” is a property which, based on available seismic and geological data, we believe shows potential oil or natural gas. Our prospects are in various stages of evaluation and interpretation. There is no way to accurately predict in advance of incurring drilling and completion costs whether a prospect will be economically viable. Even with seismic data and other technologies and the study of producing fields in the same area, we cannot know conclusively prior to drilling whether oil or natural gas will be present or, if present, will be present in commercial quantities. The analysis that we perform using data from other wells, more fully explored prospects and/or producing fields may not be useful in predicting the characteristics and potential reserves associated with our drilling prospects. When we drill unsuccessful wells, our drilling success rate declines and we may not achieve our targeted rate of return.

 

We may incur substantial losses and be subject to substantial liability claims as a result of our operations.

 

We are not insured against all risks. Losses and liabilities arising from uninsured and underinsured events could materially and adversely affect our business, financial condition or results of operations. Our oil and natural gas exploration and production activities are subject to all of the operating risks associated with drilling for and producing oil and natural gas, including the possibility of:

 

 

 

 

Any of these risks could adversely affect our ability to conduct operations or result in substantial losses. In instances when we believe that the cost of available insurance is excessive relative to the risks presented we may elect not to obtain insurance. In addition, pollution and environmental risks generally are not fully insurable. If a significant accident or other event occurs that is not fully covered by insurance, it could adversely affect us.

 

We are subject to complex laws that can affect the cost, manner or feasibility of doing business.

 

Exploration, development, production and sale of oil and natural gas are subject to extensive governmental regulation. We may be required to make large expenditures to comply with these regulations. Matters subject to regulation include:

 

 

Under these laws, we could be liable for personal injuries, property damage and other damages. Failure to comply with these laws may also result in the suspension or termination of our licenses or operations and could subject us to administrative, civil and criminal penalties. Moreover, these laws could change in ways that substantially increase our costs. Any such liabilities, penalties, suspensions, terminations or regulatory changes could materially adversely affect our financial condition and results of operations.

 

We may incur substantial liabilities to comply with environmental laws and regulations.

 

Our oil and natural gas operations are subject to stringent governmental laws and regulations relating to the release or disposal of materials into the environment or otherwise relating to environmental protection. These laws and regulations may require the acquisition of permits before drilling commences, restrict the types, quantities and concentration of substances that can be released into the environment in connection with drilling and production activities, limit or prohibit drilling activities on certain lands lying within wilderness, wetlands and other protected areas, and impose substantial liabilities for pollution resulting from our operations. Failure to comply with these laws and regulations may result in the assessment of administrative, civil and criminal penalties, imposition of investigatory or remedial obligations or even injunctive relief. Changes in environmental laws and regulations occur frequently. Any changes that result in more stringent or costly waste handling, storage, transport, disposal or cleanup requirements could require us to make significant expenditures to maintain compliance, and may otherwise have a material adverse effect on our results of operations, competitive position or financial condition as well as on the industry in general. Under these environmental laws and regulations, we could be held strictly liable for the removal or remediation of previously released materials or property contamination regardless of whether we were responsible for the release or whether our operations were standard in the industry at the time they were performed.

 

 

Unless we replace our oil and natural gas reserves, our reserves and future production will decline, which would adversely affect our cash flows and income.

 

Unless we conduct successful development, exploration and exploitation activities or acquire properties containing proved reserves, our proved reserves will decline as those reserves are produced. Producing oil and natural gas reservoirs generally are characterized by declining production rates that vary depending upon reservoir characteristics and other factors. Our future oil and natural gas reserves and production, and, therefore our cash flow and income, are highly dependent upon our success in efficiently developing and exploiting our current reserves and economically finding or acquiring additional recoverable reserves. If we are unable to develop, exploit, find or acquire additional reserves to replace our current and future production, our cash flow and income will decline as production declines, until our existing properties would be incapable of sustaining commercial production.

 

The unavailability or high cost of drilling rigs, equipment, supplies, personnel and oil field services could adversely affect our ability to execute on a timely basis our exploration and development plans within our budget.

 

Shortages or the high cost of drilling rigs, equipment, supplies or personnel could delay or adversely affect our development and exploration operations. As the price of oil and natural gas has remained high, demand for production equipment and personnel has also remained high, resulting, in some cases, in shortages of equipment and skilled personnel. In addition, larger producers may be able to secure access to such equipment by offering drilling companies more lucrative terms. As demand for services and personnel increases, the cost also increases, which can delay our ability to convert our reserves into cash flow as well as significantly increasing the cost of producing those reserves, thereby having a negative impact on anticipated net income.

 

The unavailability or high price of transportation systems could adversely affect our ability to deliver our oil on terms that would allow us to operate profitably, or at all.

 

Because of the location of our properties, the crude oil we produce must be transported by truck or by rail. In the future it will likely also be transported by pipelines. These railways and pipelines are operated by state-owned entities or other third-parties, and there can be no assurance that these transportation systems will always be functioning and available, or that the transportation costs will not become cost prohibitive. In addition, any increase in the cost of transportation or reduction in its availability to us could have a material adverse effect on our results of operations. There is no assurance that we will be able to procure sufficient transportation capacity on economical terms, if at all.

 

Competition in the oil and natural gas industry is intense, which may adversely affect our ability to compete.

 

We operate in a highly competitive environment for acquiring properties, marketing oil and natural gas and securing trained personnel. Many of our competitors possess and employ financial, technical and personnel resources that are substantially greater than ours. Those companies may be able both to pay more for productive oil and natural gas properties and exploratory prospects and to evaluate, bid for and purchase a greater number of properties and prospects than our financial or personnel resources permit. Our ability to acquire additional prospects and to find and develop reserves in the future will depend on our ability to evaluate and select suitable properties and to consummate transactions in a highly competitive environment. There is substantial competition for capital available for investment in the oil and natural gas industry. We may not be able to compete successfully in the future in acquiring prospective reserves, developing reserves, marketing hydrocarbons, attracting and retaining quality personnel or raising additional capital.

 

 

 

Risks Relating to Our Business

 

If you purchase shares of our stock, your investment will be subject to the same risks inherent in international operations, including, but not limited to, adverse governmental actions, political risks, and expropriation of assets, loss of revenues and the risk of civil unrest or war.

 

While we have significant experience working in Kazakhstan, and feel we have good relationships with government agencies at many levels, we remain subject to all the risks inherent in international operations, including adverse governmental actions, uncertain legal and political systems, and expropriation of assets, loss of revenues and the risk of civil unrest or war.  Our primary oil and gas properties are located in Kazakhstan, which until 1990 was part of the Soviet Union.  Kazakhstan retains many of the laws and customs of the former Soviet Union, but has and is continuing to develop its own legal, regulatory and financial systems.  As the political and regulatory environment changes, we may face uncertainty about the interpretation of our agreements; in the event of dispute, we may have limited recourse within the legal and political system.

 

Prior to the expiration of our exploration rights, we plan to make application for commercial production rights to the extent we have established commercially producible reserves on our properties.  We have the exclusive right to negotiate a commercial production contract for the ADE Block and Extended Territory, and the government is required to conduct these negotiations under the “Law of Petroleum.”  The terms of the commercial production contract will establish the royalty and other payments due to the government in connection with commercial production. At the time the commercial production contract is issued, we will be required to begin repaying the government its historical investment costs of exploration and development of the ADE Block and the Extended Territory. Our obligation associated with the ADE Block is approximately $6 million. Our obligation associated with the Extended Territory is approximately $5.3 million. If satisfactory terms for commercial production rights cannot be negotiated, it could have a material adverse effect on our financial position.

Our ability to obtain additional financing or use our operating cash flow to fund operations may be adversely affected by our level of indebtedness.

 

Our level of indebtedness could have negative consequences, which include, but are not limited to, the following:

 

 

15

 

 

                If we do not generate sufficient cash flow from operations or obtain additional financing we may be unable to service our debts and other obligations

 

Our ability to repay our debt obligations will depend upon our future operating performance and/or our ability to obtain additional debt or equity financing. Prevailing economic conditions and financial, business and other factors, many of which are beyond our control, may affect our ability to make these payments. If in the future we do not generate sufficient cash flow from operations to meet our obligations, we may need to refinance our debt obligations, obtain additional financing or sell assets. We may not generate cash flow, or obtain funding sufficient to satisfy the repayment of the notes, in which event we would be found to be in default.

 

Item 1B. Unresolved Staff Comments

 

 

 

 

Item 2. Properties

 

 

 

 

Under the statutory scheme in the Republic of Kazakhstan prospective oil fields are developed in two stages. The first stage is an exploration and appraisal stage during which a private contractor is given a license to explore for oil and gas on a territory for a set term of years. During this stage the primary focus is on the search for a commercial discovery, i.e., a discovery of a sufficient quantity of oil and gas to make it commercially feasible to pursue execution of, or transition to, a commercial production contract with the government. Under the terms of an exploration contract the contract holder has the right to sell all oil and natural gas produced during the term of the exploration contract and may receive certain tax benefits.

 

We currently own a 100% interest in a license to use subsurface mineral resources and a hydrocarbon exploration contract issued by the ROK in 1999 and 2000, respectively (collectively referred to herein as the (“license” or the “exploration contract”). When initially granted, the exploration and development stage of our exploration contract had a five year term, with provision for two extensions for a period of two years each. The second extension will expire on July 9, 2009. We are exploring the possibility to obtain an amendment to our exploration contract to extend the term in order to allow us additional time to conduct exploration drilling on our properties. We have engaged the services of a consulting company to undertake a study and negotiate, if possible, an extension of our exploration contract. Because our current exploration contract does not provide for any additional extensions, we are unable to determine if our efforts will be successful and therefore, we are conducting our operations on the assumption that we will be required to pursue a production contract in July 2009.

 

Initially, the exploration contract granted us the right to engage in exploration and development activities in an area of approximately 200 square kilometers referred to herein as the ADE Block. The ADE Block is comprised of three fields, the Aksaz, Dolinnoe and Emir fields. During our 2006 fiscal year our exploration contract was expanded to include an additional 260 square kilometers of land adjacent to the ADE Block, which we refer to herein as the “Extended Territory.” The Extended Territory is governed by the terms of the exploration contract. The ADE Block and the Extended Territory are sometimes collectively referred to herein as “our properties.”

 

In order to be assured that adequate exploration activities are undertaken by the contractor, the MEMR establishes an annual mandatory minimum work program to be accomplished in each year of the exploration contract. Under the minimum work program the contractor is required to invest a minimum dollar amount in exploration activities on the contract territory, which may include geophysical studies, construction of field infrastructure or drilling activities. During the exploration stage, the contractor is also required to drill sufficient wells to establish the existence of commercially producible reserves in any structure for which the contractor intends to seek a commercial production license. Failure to complete the minimum work program during the term of an exploration contract, or any portion thereof, could preclude a contractor from receiving a longer-term commercial production contract, regardless the success of the contractor in proving commercial reserves during the partial fulfillment of the minimum work program. Therefore, completion of the exploration contract’s minimum work program is essential to the success of any oil company working in Kazakhstan.

 

Our exploration contract follows the above format. The exploration contract sets the minimum dollar amount we must expend during each year of our work program. Under our exploration license our work program

 

 

year ends on July 9 each year. As a result of timing differences between the exploration contract year and our fiscal year, the amounts reflected in this table as “Actually Made” may differ from amounts disclosed elsewhere in our Management’s Discussion and Analysis or Consolidated Financial Statements, which present figures based on our fiscal year end rather than our work program year end.

 

 

* Investment as of March 31, 2008.

 

Under the rules of the MEMR there is an option for expenditures above the minimum requirements in one period to be carried over to meet minimum obligations in future periods. As the above chart shows we have significantly exceeded the minimum expenditure requirement in each period of the exploration contract and have nearly quadrupled the total minimum capital expenditure requirement during the exploration stage. Moreover, we expect our planned drilling activities through 2009 to exceed the amounts required during the rest of 2008 and 2009. Therefore, we are confident we have already satisfied the minimum capital expenditure requirements of our exploration contract.

 

The second aspect of the mandatory minimum work program is the requirement to drill a sufficient number of wells on any field for which we plan to seek commercial production rights to support our claim of a commercial discovery within the field. In Kazakhstan, typically, one exploratory well and two appraisal wells are sufficient to support a claim of commercially producible reserves in a particular field, although in some cases, commercial reserves have been demonstrated with fewer wells.

 

The total number of wells the MEMR will require during exploration stage is generally determined by the number of fields or structures identified by the seismic studies done on a territory. The 3D seismic studies of our contract territory, have identified six potential fields or structures. Therefore, if we wish to apply for commercial production rights on all six fields we anticipate the need to drill three wells in each field during the exploration phase of our exploration contract, as reflected on the top half of the following chart:

 

 

 

 

The bottom half of the above chart shows our current progress on drilling of exploratory and appraisal wells, the second aspect of our mandatory minimum work program. As the chart shows, for purposes of meeting the minimum work program requirements, we have eighteen wells completed and four wells in progress.

 

To date we have been conservative in our approach to exploration. It has been our practice to drill our first few wells serially. Our first well was the Dolinnoe-2 well drilled in 2004. This was followed by the Dolinnoe-3 well, and then the Aksaz-4 and Kariman-1 wells. While we have verified the presence of oil and gas in all our wells thus far, not all our wells produce oil at commercial levels. We have expended substantial time and money to study our wells.

 

The purpose of the exploration stage is to study the geology and geophysical characteristics of each field and individual well, with a view to qualifying for a longer-term production contract. Once drilling of a well is completed, our emphasis focuses on an extended period of testing a well’s production characteristics and capacities to determine the best method for producing oil from that well and to gain insight into the further development of the entire field. During exploration, oil production is subject to wide fluctuations caused by varying pressures commonly experienced in new wells and by significant periods of well closure to accommodate mandatory testing. Maximizing oil production only becomes the central focus during the post-exploration phase when exploiting the commercial discovery commences under a production contract.

 

In addition to the wells currently in progress, if we intend to qualify for a commercial production contract that covers each of the six structures we have identified within our contract territory, we will be required to drill at least three wells in each of our Borly and Yessen fields and establish commercially producible reserves in each structure within our contract territory. This will require that we continue to accelerate our drilling activities during the next year..

 

Under our exploration contract, we have the exclusive right to apply for and negotiate a commercial production contract. The government is required to negotiate the terms of these rights in good faith in accordance with the Law of Petroleum of Kazakhstan. Based on discussions with the MEMR, the primary factors used by the MEMR in determining whether to grant commercial production rights are whether the contract holder has fulfilled the minimum work program commitments, proved the existence of a commercial discovery and submitted and received approval of a development plan prepared by a third-party petroleum institute in Kazakhstan for the exploitation of the established commercial reserves. All our efforts during exploration stage have and will continue to focus on meeting these criteria.

 

The terms of our commercial production rights and royalty rates will be negotiated at the time we apply to transition to commercial production. During exploration and development stage, we have the right to produce and sell oil and natural gas at a royalty rate of 2%. During commercial production, the negotiated royalty rates may change depending on reserves and production rates. Royalty rates are established by the taxing authorities of the ROK and are based on production rates. The rate increases on a sliding scale. Current royalty rates range from 2% to 6%. We also anticipate that we will be required to pay rent export tax when we move to commercial production. The current rent export tax rate is tied to the Brent oil price; the rate increases on a sliding scale, at the present time it is 33%. Under our exploration contract during exploration stage we are not required to pay rent export tax on the oil we sell to the world markets. We anticipate that at the time we move to commercial production, the government will impose the rent export tax on all oil and natural gas we sell outside the domestic market in Kazakhstan.

 

 

 

Drilling Operations

 

During fiscal 2008 we had drilling rigs under contract from Great Wall (“Great Wall”) a Chinese drilling company,  Oil and Gas Exploration Crakow (“OGEC”), a Polish drilling company, and from KandyagashBurService (“KBS”), a Kazakh drilling company.

 

The first wells completed during fiscal 2008 were commenced in 2007. These wells were designated as the  Kariman-3 and Kariman-4. Kariman-3 was drilled with Great Wall and Kariman-4 was drilled with OGEC. Both wells were drilled to a depth of 3,675 meters. Upon completion of drilling we engaged in geological and geophysical survey activities and testing on both wells. The Kariman-4 well has been steadily performing since completion, production rates for the well are set forth in the table below.

 

Testing of various intervals on the Kariman-3 well has allowed us to collect valuable geological information regarding the structure and potential of the Kariman oil field. We have installed a downhole pump onto Kariman-3 due to the lack of a primary depletion mechanism in the well. We plan to continue conducting various studies on Kariman-3 with the aim of achieving commercial production from the well.

 

The OGEC drilling rig was then moved to a new location in the Kariman field designated Kariman-5. The well was drilled to a total depth of 3,696 meters. Drilling operations were completed in January 2007.

 

Upon completion of drilling, we have engaged in geological and geophysical survey activities and testing on Kariman-5. Similar to Kariman-3, the location of Kariman-5 was selected to delineate the boundaries of the Kariman field. We have perforated several oil-bearing intervals and conducted a number of geological tests. We engaged Schlumberger to conduct coil tubing acid stimulation activities on the well. Current production rates are set forth in the table below.

 

Following completion operations on the Kariman-5 well, the OGEC drilling rig began drilling the Kariman-8 well in January 2008 with completion and testing scheduled to begin during the summer of 2008.

 

After completion of Kariman-3, the Great Wall rig was moved to the Dolinnoe field to begin drilling the Dolinnoe-5 well. The well was drilled to the total depth of 3,780. Drilling operations were completed on March 5, 2008. Upon completion of drilling, we engaged in geological and geophysical survey activities and testing and perforated several discovered oil-bearing intervals. It does not appear that Dolinnoe-5 will be a commercially successful well at present.

 

Upon completion of drilling operations on the Dolinnoe-5 well, the Great Wall rig moved to the Aksaz field to begin drilling Aksaz-2. Drilling operations are in progress with a target depth of 4,350 meters. The Aksaz-2 well is scheduled for completion in September of 2008.

 

 

We commenced re-entry operations on the Aksaz-3 well utilizing Great Wall. Aksaz-3 well was initially drilled by Mangistaumunaygas in 1996 to a depth of 3,728 meters and cased to 3,067 meters. We completed re-entry operations in October 2007, at a depth of 4,270 meters. Upon completion of drilling we engaged in extensive geological and geophysical survey activities and testing of various discovered intervals within the well. Aksaz-3 has been steadily producing since finishing completion and testing activities, production rates are set forth in the table below.

 

The Great Wall rig was then moved to the Kariman field to begin drilling of the Kariman-6 well, which was completed in February 2008 at a total depth of 3,590 meters. Upon completion of drilling we engaged in geological and geophysical survey activities and testing of various discovered intervals within the well. The well has been steadily producing since completion and testing activities ended. Production rates are set forth in the table below.

 

Following completion operations on Kariman-6, Great Wall began drilling the Kariman-10 well. This well is scheduled for completion and testing in the summer of 2008.

 

We engaged a third drilling rig from Great Wall in November 2007 to drill the Kariman-7 well. The well was completed in March 2008 at a total depth of 3,610 meters. Upon completion of drilling we were engaged in extensive geological and geophysical survey activities and testing of various discovered intervals within these wells. The well has been steadily producing since completion and testing activities ended. Production rates are set forth in the table below.

 

Upon completion of Kariman-7 the Great Wall rig began drilling the Dolinnoe-7 well. The total projected depth is 3,800 meters with the drilling operations scheduled for completion and testing in the fall of 2008.

 

We retained the services of KBS for drilling operations on the Emir oil field. The KBS drilling rig was contracted on a turn-key basis to drill Emir-6 and Emir-2. The Emir-6 well was completed in June 2007. The primary depletion mechanism of the well is not suitable for commercial production, and therefore, we installed a downhole pump on the well.

 

The Emir-2 well was completed in March 2008 at a depth of 3,165 meters. Emir-2 has not been perforated because the completion/workover rigs we use have been engaged in testing of new wells and workover/stimulation activities on existing wells. We expect to conduct perforation and testing activities on the Emir-2 well as soon as the workover rig becomes available.

 

Well Performance and Production

 

The following table sets forth the number of oil and natural gas wells in which we owned an interest as of March 31, 2008.

 

 

 

As of March 31, 2008 we had eighteen wells in test production, testing or workover. According to the laws of the Republic of Kazakhstan, we are required to test every prospective object on our properties separately, this includes the completion of well surveys on different modes with various choke sizes on each horizon.

 

In the course of well testing and transferring between intervals a well is shut in and oil production ceases for the period of mobilization/ demobilization of the workover rig, pull out of the hole, run in the hole, perforation and packer installation, etc. This has the effect of temporarily diminishing production rates averaged during testing.

 

Following is a brief description of the current production status of each of our eighteen wells.

 

 

   

 

 

   

 

Cost Information

 

 

Capitalized costs and accumulated depletion, depreciation and amortization relating to our oil and natural gas producing activities, all of which are conducted in the Republic of Kazakhstan, are summarized below:

 

 

Exploration, Development and Acquisition Capital Expenditures

 

The following table sets forth certain information regarding the total costs incurred associated with exploration, development and acquisition activities.

 

 

Oil and Natural Gas Volumes, Prices and Operating Expense

 

The following table sets forth certain information regarding production volumes, average sales price and average operating expense associated with our sale of oil and natural gas for the periods indicated.

 

 

 

(1)   During the years ended March 31, 2008, 2007 and 2006, the Company has not engaged in any hedging activities, including derivatives.

 

 

 

In December 2003, a complaint was filed in the 15th Judicial Court in and for Palm Beach County, Florida, naming, among others, the Company and former directors, Georges Benarroch and Alexandre Agaian, as defendants. The plaintiffs, Brian Savage, Thomas Sinclair and Sokol Holdings, Inc. allege claims of breach of contract, unjust enrichment, breach of fiduciary duty, conversion and violation of a Florida trade secret statute in connection with a business plan for the development of the Aksaz, Dolinnoe and Emir oil and gas fields owned by Emir Oil, LLP. The parties mutually agreed to dismiss this lawsuit without prejudice.

 

In April 2005, Sokol Holdings, Inc., also filed a complaint in United States District Court, Southern District of New York alleging that BMB Munai, Inc., Boris Cherdabayev, and former Company directors Alexandre Agaian, Bakhytbek Baiseitov, Mirgali Kunayev and Georges Benarroch wrongfully induced Toleush Tolmakov to breach a contract under which Mr. Tolmakov had agreed to sell to Sokol 70% of his 90% interest in Emir Oil LLP.

 

 

In October and November 2005, Sokol Holdings filed amendments to its complaint in the U.S. District Court in New York to add Brian Savage and Thomas Sinclair as plaintiffs and to add Credifinance Capital, Inc., and Credifinance Securities, Ltd., (collectively “Credifinance”) as defendants in the matter. The amended complaints alleged: i) tortious interference with contract, specific performance, breach of contract, unjust enrichment, unfair competition-misappropriation of labors and expenditures against all defendants; ii) breach of fiduciary duty, tortious interference with fiduciary duty and aiding and abetting breach of fiduciary duty by Mr. Agaian, Mr. Benarroch and Credifinance; and iii) breach of fiduciary duty by Mr. Cherdabayev, Mr. Kunayev and Mr. Baiseitov, in connection with a business plan for the development of the Aksaz, Dolinnoe and Emir oil and gas fields owned by Emir Oil, LLP. The plaintiffs have not named Toleush Tolmakov as a defendant in the action nor have the plaintiffs ever brought claims against Mr. Tolmakov to establish the existence or breach of any legally binding agreement between the plaintiffs and Mr. Tolmakov. The plaintiffs seek damages in an amount to be determined at trial, punitive damages, specific performance and such other relief as the Court finds just and reasonable.

 

The defendants have retained the law firm of Bracewell & Giuliani LLP in New York, New York to represent it in the lawsuit. The defendants moved for dismissal of the amended complaint or for a stay pending arbitration in Kazakhstan. That motion was denied, without prejudice to renewing it, to enable defendants to produce documents to plaintiffs relating to the issues raised in the motion. Following completion of document production, the motion was renewed. Briefing on the motion was completed on August 24, 2006. On June 14, 2007, the court ruled on our motion. The court (a) denied the motion to dismiss on the ground that Kazakhstan is a more convenient forum; (b) denied the motion to dismiss in favor of litigation in New York state court; (c) denied the motion to stay pending arbitration in Kazakhstan; and (d) denied the motion to dismiss on the ground that Mr. Tolmakov is an indispensable party. The court also (a) denied the motion (by defendants other than the Company) to dismiss for lack of personal jurisdiction and (b) granted the motion (by defendants other than the Company) to dismiss several claims for relief alleging breach of fiduciary duty, tortious interference with fiduciary duty and aiding and abetting breach of fiduciary duty. The court dismissed as moot the Company’s cross-motion to stay discovery and instructed the parties to comply with the Magistrate Judge’s discovery schedule.

 

The defendants have appealed the court’s refusal to stay the litigation pending arbitration in Kazakhstan. The defendants moved for an order to stay all proceedings in the lower court while the aforementioned appeal is pending. This motion was denied by the lower court and we have made a similar motion before the Court of Appeals. Oral argument on the appeal was held on October 26, 2007. The Court of Appeals has not yet rendered a decision on the appeal or the ancillary motion to stay all proceedings pending a decision on the appeal. Therefore, discovery in the case is ongoing. No trial date has been set by the court.

 

Other than the foregoing, to the knowledge of management, there is no other material litigation or governmental agency proceeding pending or threatened against the Company or our management.

 

 

No matters were submitted to a vote of security holders and there were no changes in our board of directors during the quarter ended March 31, 2008.      

 

 

PART II

 

 

 

Our common stock is traded on the American Stock Exchange under the symbol “KAZ.” Our shares are also traded on XETRA , the Deutsche Borse electronic trading system under SE code DL-,001 DMW US09656A1051.

 

The following table presents the high and low sales price for the fiscal year ended March 31, 2008, third and fourth quarters of the fiscal year ended March 31, 2007, as reported by the American Stock Exchange, and the high and low bid prices for the first and second quarters of the fiscal year ended March 31, 2007 when our shares were quoted on the OTC Bulletin Board. The published high and low bid quotations for the first and second quarter of 2007, were furnished to us by Pink Sheets, LLC. These quotations represent prices between dealers and do not include retail markup, markdown or commissions and may not represent actual transactions.

 

 

Stock Performance Graph

 

The required information is incorporated herein by reference to the disclosure included under the heading "Stock Performace Graph" contained in the Company's proxy statement for the 2008 annual meeting of stockholder.

 

Record Holders

 

As of June 10, 2008, we had approximately 367 shareholders of record holding 44,784,134 shares of our common stock. The number of record holders was determined from the records of our transfer agent and does not include beneficial owners of common stock whose shares are held in the names of various security brokers, dealers, and registered clearing agencies.

 

Dividend Policy

 

We have not declared or paid a cash dividend on our common stock during the past two fiscal years. Our ability to pay dividends is subject to limitations imposed by Nevada law. Under Nevada law, dividends may be paid to the extent that a corporation’s assets exceed it liabilities and it is able to pay its debts as they become due in the usual course of business. At the present time, our board of directors does not anticipate paying any dividends in the foreseeable future; rather, the board of directors intends to retain earnings that could be distributed, if any, to fund operations and to expand and develop our business.

 

 

Securities for Issuance Under Equity Compensation Plans

 

As of March 31, 2008, shares of our common stock were subject to issuance upon the exercise of outstanding options or warrants as set forth below.

 

 

On November 19, 2003 we granted an option to Credifinance Securities Limited for services rendered by Credifinance as our agent in connection with private placements made by us in November 2003. The option grants Credifinance the right to purchase up to 142,857 shares of our common stock at an exercise price of $3.50 per share. The option expires on November 26, 2008. The option provides for adjustments to the number of shares and/or the price per share to protect the holder against dilution and in the event of mergers, reorganizations and similar events. The option also requires that in the event we determine to make a registered public offering during the term of the option, we shall use our best efforts to include the common shares underlying the options in the registration statement. 90,477 of these options were exercised in March 2008.

 

In November 2004 we agreed to grant stock options under our 2004 Stock Incentive Plan to Gary Lerner, our former corporate secretary, to purchase 60,000 shares of our common stock. The options have an exercise price of $4.00 per share and expire in October 2009. Mr. Lerner exercised options to purchase 7,200 common shares in April 2006 and options to purchase an additional 3,000 common shares in January 2008.

 

On July 18, 2005 our Board of Directors approved stock option grants and restricted stock awards under our 2004 Stock Incentive Plan. The total number of options and restricted stock grants was 820,783 and 469,217, respectively. The options are exercisable at a price of $4.75, the closing price of our common stock on the OTCBB on July 18, 2005. The options expire five years from the grant date. Of the restricted stock grants, 389,217 vested immediately. The remaining shares were granted to three individuals and vested over three years. Among the parties receiving stock options and restricted stock grants were the following executive officers and directors:

 

 

                

In January 2006, we entered into a separation agreement with our former CFO, Anuar Kulmagambetov, to issue Mr. Kulmagambetov 50,000 restricted common shares and an option to purchase up to 100,000 shares of restricted common stock of the Company at $7.40 per share expiring five years from the date of grant.

 

On June 20, 2006 our Board of Directors approved stock option grants and restricted stock awards to our officers and directors and certain employees and consultants of the Company under our 2004 Stock Incentive Plan. The total number of options and restricted stock grants was 200,000 and 495,000 respectively. The options are exercisable at a price of $7.00 per share, which was the closing price of our common stock on the OTCBB on June 20, 2006. The restricted stock grants were also valued at $7.00 per share. The options will expire three years from the grant date. All of the options and restricted stock grants have vested. Among the parties receiving restricted stock grants were the following executive officers and directors:

 

 

On March 30, 2007 we made restricted stock grants under the Plan to certain officers, employees and outside consultants under the Plan. The total number of restricted common shares granted was 950,000. The restricted stock grants were valued at $5.38 per share. The restricted stock grants were awarded on the same terms and subject to same vesting requirements. The restricted stock grants will vest to the grantees at such time as either of the following events occurs (the “Vesting Events”):

 

29

 

 

                  The grantees have the right to vote the shares, receive dividends and enjoy all other rights of ownership over the entire grant amount from the grant date, except for the right to transfer, assign, pledge, encumber, dispose of or otherwise directly or indirectly profit or share in any profit derived from a transaction in the shares prior to the occurrence of a Vesting Event. Shares will only vest to the grantee if the grantee is employed by the Company at the time a Vesting Event occurs. If a Vesting Event has not occurred at the time a grantee's employment with the Company ceases, for any reason, the entire grant amount shall be forfeited back to the Company. Among the parties receiving restricted stock grants were the following executive officers and directors:

 

 

Recent Sales of Unregistered Securities.

 

In March 2008, Credifinance exercised options to purchase 90,477 shares of our restricted common stock at a price of $3.50 per share. The shares were issued without registration under the Securities Act of 1933 in reliance upon Section 4(2) of the Securities Act of 1933.

 

During January 2008, Mr. Lerner exercised options to purchase 3,000 shares of our common stock at a price of $4.00 per share. The shares were issued without registration under the Securities Act of 1933 in reliance upon Section 4(2) of the Securities Act of 1933.

 

Issuer Repurchases

 

We did not make any repurchases of our equity securities during the year ended March 31, 2008.

 

Item 6. Selected Financial Data

 

The selected consolidated financial information set forth below is derived from our consolidated balance sheets and statements of operations as of and for the years ended March 31, 2008, 2007, 2006 and 2005 and for the period from inception (May 6, 2003) through March 31, 2004. The data set forth below should be read in conjunction with “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and the consolidated financial statements and related notes thereto included in this Annual Report.

 

 

 

 

 

This discussion summarizes the significant factors affecting our consolidated operating results, financial condition, liquidity and capital resources during the fiscal years ended March 31, 2008, 2007 and 2006. This discussion should be read in conjunction with the consolidated financial statements and footnotes to the consolidated financial statements included in this annual report.

 

Results of Operations

 

This section includes a discussion of our results of operations for the fiscal years ended March 31, 2008, 2007 and 2006. The following table sets forth selected operating data for the fiscal years indicated:

 

 

 

Year ended March 31, 2008, compared to the year ended March 31, 2007.

 

Revenue and Production

 

The following table summarizes production volumes, average sales prices and operating revenue for our oil and natural gas operations for the year ended March 31, 2008 and the year ended March 31, 2007.

 

 

 

 

Revenues. We generate revenue under our exploration contract from the sale of oil recovered during test production. During the year ended March 31, 2008 our oil production increased 182% compared to the year ended March 31, 2007. This significant increase in production is primarily attributable to the fact that we had sixteen wells in testing or test production during all or some portion of the year ended March 31, 2008 compared to eight wells during all or some portion of the year ended March 31, 2007.

 

During the year ended March 31, 2008 we realized revenue from oil sales of $60,196,626 compared to $15,785,784 during the year ended March 31, 2007. The largest contributing factor to the 281% increase in revenue was a 184% increase in sales volume. Another factor contributing to the increase in revenues was a 34% increase in the price per barrel we received for oil sales during the year ended March 31, 2008 compared to the fiscal year ended March 31, 2007. During the fiscal years ended March 31, 2008 and 2007 we exported 91% and 100% of our oil, respectively to the world markets and realized the world market price for those sales. Revenue from oil sold to the world markets made up 96% and 100% of total revenue, respectively, during the years ended March 31, 2008 and 2007. We anticipate production to remain fairly constant until we complete the new wells that are currently being drilled and begin test production at those wells.

 

 

As discussed above, our revenue is sensitive to changes in prices received for our oil. Most of our production is currently being sold at the prevailing world market price, which fluctuates in response to many factors that are outside our control. Imbalances in the supply and demand for oil can have a dramatic effect on the price we receive for our production. Similarly, if we were denied an export quota, our export quota were reduced or we were otherwise forced to sell all, or a significant portion, of our production to the domestic market in Kazakhstan, we anticipate the price we would receive per barrel of oil would be much lower than the price we currently realize which would lead to a significant decrease in revenues. Political instability, the economy, weather and other factors outside our control could have an impact on both supply and demand.

 

Costs and Operating Expenses

 

The following table presents details of our expenses for the years ended March 31, 2008 and 2007:

 

 

Oil and Gas Operating Expenses. During the year ended March 31, 2008 we incurred $5,515,403 in oil and gas operating expenses compared to $2,272,251 during the year ended March 31, 2007. This significant increase is primarily the result of several factors, including increased royalty, salary and transportation expenses and increased repair costs.

 

During the year ended March 31, 2008 royalty paid to the Government increased by $1,214,029 or 354% compared to the year ended March 31, 2007. The primary reason for the increase in royalty is two-fold. During the 2007 fiscal year, oil production increased 182% and our average sales price per barrel increased 34% as a result of exporting nearly all of our oil to the world markets during fiscal 2008. While royalty expenses increased significantly, as a percentage of total revenue royalty expense remained nearly unchanged. We anticipate that royalty expenses will continue to fluctuate in proportion to production volume and realized sales price.

 

 

During the year ended March 31, 2008 payroll and related payments to production personnel increased $142,418 or 28% compared to the year ended March 31, 2007. As production volume increased we retained additional production personnel during the year ended March 31, 2008.

 

Transportation expenses increased $1,886,705 or 133% as a result of the increased volume of oil we produced and transported. We anticipate transportation expenses will continue to increase with increases in production.

 

We calculate oil and gas operating expense per BOE based on the volume of oil actually sold rather than production volume because not all volume produced during the period is sold during the period. The related production costs are expensed only for the units sold, not produced.

 

While oil and gas operating expenses increased 143% during the year ended March 31, 2008 compared to the year ended March 31, 2007, expense per BOE decreased from $7.20 per BOE during the year ended March 31, 2007 to $6.15 during the year ended March 31, 2008. The reason expense per BOE decreased is due to the fact that we increased our sales volume during the year ended March 31, 2008. During the year ended March 31, 2007 we sold 315,540 barrels of oil, during the year ended March 31, 2008 we sold 896,256 barrels of oil. As expense per BOE is a function of total expense divided by the number of barrels of oil sold, the 184% increase in sales volume more than offset the 143% increase in expenses resulting in the 15% decrease in oil and gas operating expense per BOE.

 

On April 18, 2008 the government of the Republic of Kazakhstan introduced an export duty on several products (including crude oil). We will be subject to the duty beginning in June 2008. The formula for determining the amount of the crude oil export duty is based on a sliding scale that is tied to several factors, including the world market price for oil. Based on current world oil prices, we estimate the export duty will be approximately 15 to 20%. As noted above, this can change with fluctuations in world oil prices. This export duty will be recorded as part of our oil and gas operating expenses. We anticipate this will lead to a significant increase in oil and gas operating expenses in future quarters.

 

General and Administrative Expenses. General and administrative expenses during the year ended March 31, 2008 were $14,747,754 compared to $10,757,727 during the year ended March 31, 2007. This represents a 37% increase in general and administrative expenses. This increase in general and administrative expenses was the result of several factors such as increased payroll and related costs, rent expense, taxes and professional services.

 

We recognized compensation expense of $2,303,078 during the year ended March 31, 2008 resulting from restricted stock grants made to employees and outside consultants. By comparison, during the year ended March 31, 2007 we recognized the compensation expense in the amount of $4,134,823 for restricted stock grants and issued to employees and outside consultants.

 

The increase in general and administrative expense during the 2008 year was primarily the result of:

 

 

 

 

 

These increases more than offset the 44% decrease in compensation expense realized during the year ended March 31, 2008.

 

Depletion. Depletion expense for the year ended March 31, 2008 increased by $7,412,821 compared to the year ended March 31, 2007. The major reason for this increase in depletion expense was a 184% increase in sales volume in fiscal 2008 compared to fiscal 2007. The increase in depletion expense was also attributable to the fact that we drilled additional wells, continued workover on existing wells and developed additional infrastructure during fiscal 2008.

 

Depreciation and Amortization. Depreciation and amortization expense for the year ended March 31, 2008 increased 40% compared to the year ended March 31, 2007. The increase resulted from purchases of fixed assets during the year.

 

Income from Operations. During the year ended March 31, 2008 we realized income from operations of $30,020,087 compared to an income from operations of $404,843 during the year ended March 31, 2007. This increase in income from operations during fiscal 2008 is the result of the 281% increase in revenue during fiscal 2008, which increase was only partially offset by a 96% increase in total expenses.

 

Other Income. During the fiscal year ended March 31, 2008 we realized total other income of $1,186,895 compared to $1,487,928 during the fiscal year ended March 31, 2007. This 20% decrease is largely attributable to $232,715 decrease in interest income and a $65,796 decrease in exchange gain resulting from fluctuations of foreign currency rates against the U.S. Dollar.

 

Net Income. For all of the foregoing reasons, during the year ended March 31, 2008 we realized net income of $31,610,563 or $0.71 per share compared to a net income of $1,039,491 or $0.02 for the year ended March 31, 2007.

 

Year ended March 31, 2007 compared to the year ended March 31, 2006.

 

Revenue and Production

 

The following table summarizes production volumes, average sales prices and operating revenue for our oil and natural gas operations for the year ended March 31, 2007 and the year ended March 31, 2006.

 

 

 

 

Revenues. During the year ended March 31, 2007 our oil production increased 33% compared to the year ended March 31, 2006. This increase in production was primarily attributable the fact that we had two additional wells in testing or test production during the 2007 fiscal year compared to the 2006 fiscal year.

 

During the year ended March 31, 2007 we realized revenue from oil sales of $15,785,784 compared to $5,956,731 during the year ended March 31, 2006. The largest contributing factor to the 165% increase in revenue was a 91% increase in the price per barrel we received for oil sales and a 33% increase in production during the year ended March 31, 2007 compared to the fiscal year ended March 31, 2006. During the fiscal year ended March 31, 2007 we exported 100% of our oil to the world markets and realized the world market price for those sales. By comparison, during the fiscal year ended March 31, 2006 73% of oil sales were to the domestic market in Kazakhstan, where the price per barrel of oil was significantly lower than the world market price.

 

 

Costs and Operating Expenses

 

The following table presents details of our expenses for the year ended March 31, 2007 and 2006:

 

(1) Includes transportation cost, production cost and ad valorem taxes.

(2) Represents depletion of oil and gas properties only.

 

Oil and Gas Operating Expenses. During the year ended March 31, 2007 we incurred $2,272,251 in oil and gas operating expenses compared to $875,319 during the year ended March 31, 2006. This significant increase was primarily the result of several factors, including increased royalty, salary and transportation expenses and increased repair costs.

 

During the year ended March 31, 2007 royalty paid to the Government increased by $192,133 or 127% compared to the year ended March 31, 2006. The primary reason for the increase in royalty was two-fold. During the 2007 fiscal year, oil production increased 33% and our average sales price per barrel increased 91% as a result of exporting all of our oil to the world markets during fiscal 2007. While royalty expenses increased significantly, as a percentage of total revenue royalty expense remained nearly unchanged.

 

We calculate oil and gas operating expense per BOE based on the volume of oil actually sold rather than production volume because not all volume produced during the period is sold during the period. The related production costs are expensed only for the units sold, not produced.      

 

Oil and gas operating expense per BOE increased at a smaller rate because our sales volume increased in fiscal 2007. While oil and gas operating expenses increased 160% during fiscal 2007 compared to fiscal 2006, expense per BOE increased only 88% from $3.84 per BOE in fiscal year 2006 to $7.20 in fiscal year 2007. The reason expense per BOE increased at a lower rate than total operating expenses is due to the fact that we increased our sales volume in fiscal 2007. In fiscal 2006, we sold 227,976 barrels of oil in fiscal 2007 we sold 315,540 barrels of oil. As expense per BOE is a function of total expense divided by the number of barrels of oil sold, the 38% increase in sales volume partially offset the 160% increase in expenses resulting in the 88% increase in oil and gas operating expense per BOE.

 

 

Salary expenses increased by 306,406 or 152% in fiscal 2007 compared to fiscal 2006. Salary expenses increased as a result of increased payroll for Emir Oil employees, the hiring of more production and well maintenance personnel resulting from the two additional wells we had in testing or test production during fiscal 2007.

 

Transportation expenses increased $775,505 or 162%. Transportation expense increased because of increased production volume and as a result of production at the Kariman-1 and Kariman-2 wells, which are located farther away from the oil base than our other existing wells.

 

During fiscal 2007, we incurred $168,693 in repair expenses at the oil storage facility. By comparison, during fiscal 2006 we incurred $45,805 in repairs.

 

General and Administrative Expenses. General and administrative expenses during the year ended March 31, 2007 were $10,757,727 compared to $9,724,597 during the year ended March 31, 2006. This represents an 11% increase in general and administrative expenses. Factors contributing to the increase in general and administrative expense were:

 

 

Also, during the year ended March 31, 2007 we granted restricted stock and stock options to our directors, officers and key employees. The fair value of these restricted stock and stock option grants was recognized in our consolidated financial statements as compensation expense. The total amount of compensation expense recognized as a result of the stock and option grants was $4,134,823. During the year ended March 31, 2006 we also granted restricted stock and stock options to our directors, officers and key employees. The total amount of compensation expense recognized as a result of the restricted stock and option grants was $4,800,954.

 

Depletion. Depletion expense for the year ended March 31, 2007 increased by $839,599 compared to depletion expenses for the year ended March 31, 2006. The major reason for this increase in depletion expense was a 38% increase in sales volume in fiscal 2007 compared to fiscal 2006. The increase in depletion expense was also attributable to the fact that we drilled additional wells, continued workover on existing wells and developed additional infrastructure during fiscal 2007.

 

Depreciation and Amortization. Depreciation and amortization expense for the year ended March 31, 2007 increased 28% compared to the year ended March 31, 2006. The increase resulted from purchases of fixed assets during the year.

 

Income from Operations. During the year ended March 31, 2007 we realized income from operations of $404,843 compared to a loss from operations of $5,949,170 during the year ended March 31, 2006. This change to income from operations during fiscal 2007 was the result of the 165% increase in revenue during fiscal 2007, which increase was only partially offset by a 29% increase in total expenses.

 

 

 

Other Income. During the fiscal year ended March 31, 2007 we realized total other income of $1,487,928 compared to $639,880 during the fiscal year ended March 31, 2006. This 133% increase is largely attributable to $818,844 increase in interest income we realized from funds we received from a private placement we completed in December 2005 and a $126,705 increase in exchange gain resulting from fluctuations of foreign currency rates against the U.S. Dollar. This income is partially offset by a $97,501 increase in other expenses. We anticipate the funds held in deposits and marketable securities will be used to fund our operations.

 

Net Income. For all of the foregoing reasons, during the year ended March 31, 2007 we realized net income of $1,039,491 or $0.02 per share compared to a net loss of $5,344,333 or $0.15 for the year ended March 31, 2006.

 

Liquidity and Capital Resources

 

Funding for our activities has historically been provided by funds raised through equity and debt financing. From inception on May 6, 2003 through March 31, 2008 we have raised approximately $94.6 million through the sale of our common stock. Additionally during the quarter ended September 30, 2007 we completed the placement of $60 million in principal amount of 5.0% convertible senior notes due in 2012.

 

Our need for capital is primarily to fund our ongoing operations to meet the drilling requirements of our minimum work program. For the period from inception through March 31, 2008, we have incurred capital expenditures of $183,042,971 for exploration, development and acquisition activities.

 

We continually evaluate our capital needs and compare them to our capital resources. We project we will need up to an additional $20 million to continue our planned exploration activities for the next twelve months. We anticipate that required financial resources will be derived from our current and future production revenues and commercial debt.

 

As noted above, on July 16, 2007 we completed the private placement of US$60 million in principal amount of 5.0% convertible senior notes due 2012 to non-U.S. persons outside of the United States in accordance with Regulation S under the Securities Act and in compliance with the laws and regulations applicable in each country where the placement took place. The Notes carry a 5% coupon and have a yield to maturity of 6.25%. Interest is paid at a rate of 5.0% per annum on the principal amount, payable semiannually in arrears on January 13 and July 13 of each year. The first interest payment was made on January 13, 2008.

 

The Notes are convertible into shares of our common stock. The initial conversion price was set at US$ 7.2094 per share, subject to customary adjustments in certain circumstances, including but not limited to, changes of control and certain future equity financings, but shall not be adjusted below U.S. $6.95.

 

The Notes are callable after three years at a price equal to 104% of the principal amount thereof plus any accrued and unpaid interest to the date fixed for redemption, subject to the share price trading at least 30% above the conversion price. Holders of the Notes will have the right to require us to redeem all or a portion of their Notes on July 13, 2010 at a price equal to 104% of the principal amount thereof plus any accrued and unpaid interest to the date fixed for redemption. Unless previously redeemed, converted or purchased and cancelled, the Notes will be redeemed by us at a price equal to 107.2% of the principal amount thereof on July 13, 2012. The Notes constitute direct, unsubordinated and unsecured, interest bearing obligations of the Company.

 

 

 

We granted a registration right to the Noteholders to register the Notes and the underlying shares of common stock issuable upon the conversion of the Notes (collectively, the “Covered Securities”) for resale pursuant to the Securities Act. On January 25, 2008 the SEC declared effective the shelf registration statement filed by the Company on behalf of the Noteholders registering the resale of the Covered Securities.

 

For additional detail regarding the Notes, including adjustments to the initial conversion price and the registration right of the Noteholders and see Note 11 to the Notes to the Consolidated Financial Statements, March 31, 2008.

 

The net proceeds from the Note issuance of approximately $56.2 million are being used to continue our drilling program. We anticipate that even with these funds and anticipated revenue from operations we will need to obtain additional funding to finance our operations through the end of our exploration activities in July 2009. We are currently negotiating an unsecured revolving credit facility, which we believe, when coupled with anticipated revenue from operations, will provide us sufficient capital to complete our planned exploration activities through July 2009.

 

In the event we are unable to obtain sufficient funding to fully explore our entire contract territory, we will forego exploration of one or more of the potential fields within the Extended Territory. The failure to explore a particular field by the end of our exploration contract would terminate our rights to explore that field in the future and would preclude us from making application for a commercial production contract for that field.

 

Cash Flows

 

During the year ended March 31, 2008 cash was primarily used to fund exploration and development expenditures. See below for additional discussion and analysis of cash flow.

 

Our principal source of liquidity during the year ended March 31, 2008 was cash and cash equivalents. At March 31, 2007 cash and cash equivalents totaled approximately $12.2 million. At March 31, 2008 cash and cash equivalents had increased to approximately $17.2 million. During the year ended March 31, 2008 we spent approximately $83.6 million to fund our drilling and development activities and we received approximately $56.2 million as net proceeds from the issuance of the Notes.

 

 

While we anticipate revenue to increase in upcoming quarters as new wells are completed and put into test production, at this time we cannot predict how much our production, and correspondingly, our revenue might increase. At current production rates, we expect that we will need to seek additional debt financing if we are to drill the additional wells we need to support our claims of commercially producible reserves in each field within our contract territory by the end of the term of our exploration contract. While we are in negotiations with a party to provide us a revolving credit facility, we have not at this time executed any definitive agreements. There is no guarantee that we will be able to secure additional funding on acceptable terms, or at all.

 

Certain operating cash flows are denominated in local currency and are translated into U.S. dollars at the exchange rate in effect at the time of the transaction. Because of the potential for civil unrest, war and asset expropriation, some or all of these matters, which impact operating cash flow, may affect our ability to meet our short-term cash needs.

 

Contractual Obligations and Contingencies

 

The following table lists our significant commitments at March 31, 2008, excluding current liabilities as listed on our consolidated balance sheet:

 

 

 

Off-Balance Sheet Financing Arrangements

 

As of March 31, 2008, we had no off-balance sheet financing arrangements.

 

Critical Accounting Policies

 

We have identified the accounting policies below as critical to our business operations and the understanding of our financial statements. The impact of these policies and associated risks are discussed throughout Management’s Discussion and Analysis and Plan of Operations where such policies affect our reported and expected financial results. A complete discussion of our accounting policies is included in Note 2 of the Notes to Consolidated Financial Statements.

 

 

 

Foreign Exchange Transactions

 

Transactions denominated in foreign currencies are reported at the rates of exchange prevailing at the date of the transaction. Monetary assets and liabilities denominated in foreign currencies are translated to U.S. dollar at the rates of exchange prevailing at the balance sheet dates. Any gains or losses arising from a change in exchange rates subsequent to the date of the transaction are included as an exchange gain or loss in the Consolidated Statements of Operations.

 

Share-Based Compensation

 

We account for options granted to non-employees at their fair value in accordance with SFAS No. 123R, Share Based Payment and EITF Abstracts Issue 96-18, Accounting for Equity Instruments That Are Issued to Other Than Employees for Acquiring, or in Conjunction with Selling, Goods or Services. Under SFAS No. 123R, share-based compensation is determined as the fair value of the equity instruments issued. The measurement date for these issuances is the earlier of the date at which a commitment for performance by the recipient to earn the equity instruments is reached or the date at which the recipient's performance is complete. Stock options granted to the “selling agents” in the private equity placement transactions have been offset to the proceeds as a cost of capital. Stock options and stocks granted to other non-employees are recognized in the Consolidated Statements of Operations.

 

We have a stock option plan as described in Note 13. Compensation expense for options and stocks granted to employees is determined based on their fair values at the time of grant, the cost of which is recognized in the Consolidated Statements of Operations over the vesting periods of the respective options.

 

Full Cost Method of Accounting

 

We follow the full cost method of accounting for our costs of acquisition, exploration and development of oil and gas properties.

 

Under full cost accounting rules, the net capitalized costs of evaluated oil and gas properties shall not exceed an amount equal to the present value of future net cash flows from estimated production of proved oil and gas reserves, based on current economic and operating conditions, including the use of oil and gas prices as of the end of the period.

 

Given the volatility of oil and gas prices, it is reasonably possible that the estimate of discounted future net cash flows from proved oil and gas reserves could change. If oil and gas prices decline, even if only for a short period of time, it is possible that impairments of oil and gas properties could occur. In addition, it is reasonably possible that impairments could occur if costs are incurred in excess of any increases in the cost ceiling, revisions to proved oil and gas reserves occur, or if properties are sold for proceeds less than the discounted present value of the related proved oil and gas reserves.

 

All geological and geophysical studies, with respect to our licensed territory have been capitalized as part of the oil and gas properties.

 

 

Our oil and gas properties primarily include the value of the license and other capitalized costs.

 

Depletion of producing properties is computed using the unit-of-production method based on estimated proved reserves.

 

Ceiling test

 

Capitalized oil and gas properties are subject to a “ceiling test.” The full cost ceiling test is an impairment test prescribed by SEC Regulation S-X Rule 4-10. The test determines a limit, or ceiling, on the book value of oil and gas properties. That limit is basically the after tax present value of the future net cash flows from proved crude oil and natural gas reserves. This ceiling is compared to the net book value of the oil and gas properties reduced by any related deferred income tax liability. If the net book value reduced by the related deferred income taxes exceeds the ceiling, impairment or non-cash write down is required. Ceiling test impairment can give us a significant loss for a particular period; however, future depletion expense would be reduced.

 

Recently Issued Accounting Pronouncements

 

In March 2008, the FASB issued Statement No. 161, “Disclosures about Derivative Instruments and Hedging Activities – an amendment of FASB Statements No. 133”. This Statement requires that objectives for using derivative instruments be disclosed in terms of underlying risk and accounting designation. This disclosure better conveys the purpose of derivative use in terms of the risks that the entity is intending to manage. Disclosing the fair values of derivative instruments and their gains and losses in a tabular format should provide a more complete picture of the location in an entity’s financial statements of both the derivative positions existing at period end and the effect of using derivatives during the reporting period. Disclosing information about credit-risk-related contingent features should provide information on the potential effect on an entity’s liquidity from using derivatives. This Statement requires cross-referencing within the footnotes, which should help users of financial statements locate important information about derivative instruments. This Statement is effective for financial statements issued for the fiscal years and interim periods beginning after November 15, 2008. We do not anticipate this Statement will impact our consolidated financial position or consolidated results of operations and cash flows.

 

In December 2007, the FASB issued Statement No. 160, “Noncontrolling Interests in Consolidated Financial Statements.” This Statement requires the ownership interests in subsidiaries held by parties other than the parent be clearly identified, labeled, and presented in the consolidated statement of financial position within equity, but separate from the parent’s equity; the amount of consolidated net income attributable to the parent and to the non-controlling interest be clearly identified and presented on the face of the consolidated statement of income; changes in a parent’s ownership interest while the parent retains its controlling financial interest in its subsidiary be accounted for consistently; when a subsidiary is deconsolidated, any retained non-controlling equity investment in the former subsidiary be initially measured at fair value; entities provide sufficient disclosures that clearly identify and distinguish between the interests of the parent and the interests of the noncontrolling owners. This Statement is effective for financial statements issued for the fiscal years beginning after December 15, 2008. We do not anticipate this Statement will impact our consolidated financial position or consolidated results of operations and cash flows.

 

 

In December 2007, the FASB issued a revision of Statement No. 141, “Business Combinations.” This Statement establishes principles and requirements for how the acquirer recognizes and measures in its financial statements the identifiable assets acquired, the liabilities assumed, and any non-controlling interest in the acquiree; recognizes and measures the goodwill acquired in the business combination or a gain from a bargain purchase; determines what information to disclose to enable users of the financial statements to evaluate the nature and financial effects of the business combination. This Statement applies prospectively to business combinations for which the acquisition date is after the beginning of the first annual reporting period beginning after December 15, 2008. We do not anticipate this Statement will impact our consolidated financial position or consolidated results of operations and cash flows.

 

In February 2007, the FASB issued Statement No. 159, “The Fair Value Option for Financial Assets and Financial Liabilities—Including an amendment of FASB Statement No. 115”. This Statement permits entities to choose to measure many financial instruments and certain other items at fair value. The objective is to improve financial reporting by providing entities with the opportunity to mitigate volatility in reported earnings caused by measuring related assets and liabilities differently without having to apply complex hedge accounting provisions. This Statement is expected to expand the use of fair value measurement, which is consistent with the Board’s long-term measurement objectives for accounting for financial instruments. This Statement is effective for financial statements issued for the fiscal years beginning after November 15, 2007. We do not anticipate this Statement will impact the our consolidated financial position or consolidated results of operations and cash flows.

 

In September 2006, the Financial Accounting Standards Board (FASB) issued SFAS No. 157, Fair Value Measurements, which defines fair value, establishes a framework for measuring fair value in generally accepted accounting principles and expands disclosures about fair value measurements. SFAS No. 157 is effective for fiscal years beginning after November 15, 2007, and interim periods within those fiscal years. In February 2008, the FASB issued FASB Staff Position (FSP FIN) No. 157-2 which extended the effective date for certain nonfinancial assets and nonfinancial liabilities to fiscal years beginning after November 15, 2008. The Company does not expect the adoption of SFAS No. 157 to have a material impact on the consolidated financial statements.

 

Effects of Inflation and Pricing

 

The oil and natural gas industry is very cyclical and the demand for goods and services of oil field companies, suppliers and others associated with the industry puts extreme pressure on the economic stability and pricing structure within the industry. Typically, as prices for oil and natural gas increase, so do all associated costs. Material changes in prices have an impact on the current revenue stream, estimates of future reserves, borrowing base calculations of bank loans and value of properties in purchase and sale transactions. Material changes in prices can impact the value of oil and natural gas companies and their ability to raise capital, borrow money and retain personnel. While we do not currently expect business costs to materially increase, continued high prices for oil and natural gas could result in increases in the cost of material, services and personnel.

 

 

Item 7A. Qualitative and Quantitative Disclosures About Market Risk

 

Our primary market risks are fluctuations in commodity prices and foreign currency exchange rates. We do not currently use derivative commodity instruments or similar financial instruments to attempt to hedge commodity price risks associated with future crude oil production.

 

Commodity Price Risk

 

Our revenues, profitability and future growth depend substantially on prevailing prices for crude oil. Prices also affect the amount of cash flow available for capital expenditures and our ability to either borrow or raise additional capital. Price affects our ability to produce crude oil economically and to transport and market our production either through export to international markets or within Kazakhstan. Our fiscal year 2008 crude oil sales in the international export market were based on prevailing market prices at the time of sale less applicable discounts due to transportation.

 

Historically, crude oil prices have been subject to significant volatility in response to changes in supply, market uncertainty and a variety of other factors beyond our control. Crude oil prices are likely to continue to be volatile and this volatility makes it difficult to predict future oil price movements with any certainty. Any declines in oil prices would reduce our revenues, and could also reduce the amount of oil that we can produce economically. As a result, this could have a material adverse effect on our business, financial condition and results of operations.

 

Foreign Currency Risk

 

Our functional currency is the U.S. dollar. Emir Oil, LLP, our Kazakhstani subsidiary, also uses the U.S. dollar as its functional currency. To the extent that business transactions in Kazakhstan are denominated in the Kazakh Tenge we are exposed to transaction gains and losses that could result from fluctuations in the U.S. Dollar—Kazakh Tenge exchange rate. We do not engage in hedging transactions to protect us from such risk.

 

Item 8. Financial Statements and Supplementary Data

 

The consolidated financial statements and supplementary data required by this item are included at page F-1 herein.

 

Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure

 

During the fiscal year ended March 31, 2008 there were no changes in and disagreements with our independent registered public accounting firm on accounting and financial disclosure.

 

 

Item 9A. Controls and Procedures

 

Evaluation of Disclosure Controls and Procedures

 

We maintain disclosure controls and procedures, as such term is defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), that are designed to provide reasonable assurance that information required to be disclosed by us in the reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC rules and forms, and that such information is accumulated and communicated to our management, including our principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required financial disclosures. Because of inherent limitations, our disclosure controls and procedures, no matter how well designed and operated, can provide only reasonable, and not absolute, assurance that the objectives of such disclosure controls and procedures are met.

 

As of the end of the period covered by this Report we conducted an evaluation, under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, of the effectiveness of the design and operation of our disclosure controls and procedures pursuant to Exchange Act Rules 13a-15(b) and 15d-15(b). Based on this evaluation, our principal executive officer and principal financial officer concluded that our disclosure controls and procedures were effective as of March 31, 2008.

 

Management’s Report on Internal Control Over Financial Reporting

 

Our management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rules 13a-15(f) and 15d-15(f). Our internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of the financial statements for external purposes in accordance with generally accepted accounting principles. Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that internal controls may become inadequate because of changes in conditions, or that the degree of compliance with policies and procedures may deteriorate.

 

Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we conducted an evaluation of the effectiveness of our internal control over financial reporting based on the framework set forth in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on our evaluation under the framework in Internal Control — Integrated Framework, our management concluded that our internal control over financial reporting was effective as of March 31, 2008.

 

Hansen, Barnett & Maxwell, P.C. the independent registered public accounting firm that audited the consolidated financial statements included in this Annual Report on Form 10-K, has also audited management’s assessment of our internal control over financial reporting and the effectiveness of our internal control over financial reporting as of March 31, 2008, as stated in their report which is included herein.

 

Changes in Internal Control over Financial Reporting

 

There were no changes in our internal controls over financial reporting during the quarter ended March 31, 2008 that materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

 

 

HANSEN, BARNETT & MAXWELL, P.C.

 

 

 

 

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

 

To the Board of Directors and Stockholders

BMB Munai, Inc.

We have audited BMB Munai, Inc. and subsidiary’s effectiveness of  internal control over financial reporting as of March 31, 2008, based on criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). BMB Munai, Inc.’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting. Our responsibility is to express an opinion on the company’s internal control over financial reporting 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 effective internal control over financial reporting was maintained in all material respects. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audit also included performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

 

 

In our opinion, BMB Munai, Inc. and subsidiary maintained, in all material respects, effective internal control over financial reporting as of March 31, 2008, based on criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the balance sheets and the related statements of operations, stockholders’ equity, and cash flows of BMB Munai, Inc. and Subsidiary, and our report dated June 11, 2008 expressed an unqualified opinion.

 

 

HANSEN, BARNETT & MAXWELL, P.C.

Salt Lake City, Utah

June 11, 2008

 

 

Item 9B. Other Information

 

 

PART III

 

Item 10. Directors, Executive Officers and Corporate Governance

 

The following table sets forth certain information as of June 10, 2008 regarding the members of our board of directors and executive officers, including their ages, and all offices and positions held within the Company. Directors are elected for a period of three years and thereafter serve until their successor is duly elected by the stockholders and qualified. Officers and other employees serve at the will of the Board of Directors.

 

 

 

 

A brief description of the background and business experience of each of the above listed individuals follows:

 

Boris Cherdabayev. Mr. Cherdabayev joined BMB Holding, Inc., and assumed his current position in May 2003. From May 2000 to May 2003, Mr. Cherdabayev served as Director at LLP TengizChevroil, LLP a multinational oil and gas company owned by Chevron, ExxonMobil, KazMunayGas and LukOil. From 1998 to May 2000, Mr. Cherdabayev served as a member of the Board of Directors, Vice-President of Exploration and Production and Executive Director on Services Projects Development for NOC “Kazakhoil”, an oil and gas exploration and production company. From 1983 to 1988, and from 1994 to 1998 he served as a people’s representative at Novouzen City Council (Kazakhstan); he served as a people’s representative at Mangistau Oblast Maslikhat (regional level legislative structure) and a Chairman of the Committee on Law and Order. For his achievements Mr. Cherdabayev has been awarded with a national “Kurmet” order. Mr. Cherdabayev earned an engineering degree from the Ufa Oil & Gas Institute, with a specialization in “machinery and equipment of oil and gas fields” in 1976. Mr. Cherdabayev also earned an engineering degree from Kazakh Polytechnic Institute,

 

 

with a specialization in “mining engineer on oil and gas fields’ development.” During his career he also completed an English language program in the USA, the CHAMP Program (Chevron Advanced Management Program) at Chevron Corporation offices in San-Francisco, CA, USA, and the CSEP Program (Columbia Senior Executive Program) at Columbia University, New York, NY USA. Mr. Cherdabayev is not a director or nominee of any other SEC reporting issuer.

 

Gamal Kulumbetov. Mr. Kulumbetov graduated from the Kazakh National Technical University, Department of Oil and Gas Geology located in Almaty, Kazakhstan in 1997 where he was awarded a Bachelors degree in Geology. Mr. Kulumbetov is now in the process of completing a Ph.D. from the same university. Since graduating in 1997 Mr. Kulumbetov has completed various oil and gas and geological trainings from Japan National Oil Corporation, MI Drilling Fluids LLC of Germany, Chevron Texaco of Houston, Petroleum Industry Training Center of Almaty, Kazakhstan, and Ernst & Young Company of Almaty, Kazakhstan. In 2000 Mr. Kulumbetov was employed by Halliburton as a Surface Data Logging Engineer. From 2001 through April 2005 Mr. Kulumbetov was employed by LLP TengizChevroil (“TCO”) as the Deputy Manager of the TCO Fields Development Project. From April 2005 to December 2005 Mr. Kulumbetov was employed at Big Sky Energy Corporation as Chief Geologist. Mr. Kulumbetov joined BMB Munai, Inc. as a Vice President of Operations in December of 2005 and has served as CEO since August 2007. Mr. Kulumbetov is not a director or nominee of any SEC reporting issuer.

 

Askar Tashtitov. Mr. Tashtitov has been with the Company since 2004 and has served as President since 2006 and as a Director since May 2008. Prior to joining the Company, from 2002 to 2004, Mr. Tashtitov was employed by PA Government Services, Inc. Mr. Tashtitov worked as a management consultant specializing in oil and gas projects. In May 2002, Mr. Tashtitov earned a Bachelor of Arts degree from Yale University majoring in Economics and History. Mr. Tashtitov passed the AICPA Uniform CPA Examination in August, 2006. Mr. Tashtitov is not a director or nominee of any other SEC reporting issuer.

 

Sanat Kasymov. Mr. Kasymov graduated from Istanbul University of Istanbul, Turkey in 1998 where he was awarded a Bachelors degree in Economics with an emphasis in International Relations. In 2003, Mr. Kasymov passed the AICPA Uniform CPA Examination. From April 1999 through December 2001 Mr. Kasymov was employed as the Chief Specialist of the Corporate Relations Department of Demir Kazakhstan Bank. From December of 2001 through 2004 Mr. Kasymov was employed at Deloitte & Touche as a Senior Auditor where he became proficient in the application of both international and national accounting (IAS/ US GAAP) and auditing standards (ISA/ US GAAS). From February 2005 to January 2006, when he was appointed as the Company’s Chief Financial Officer, Mr. Kasymov served as the Financial Manager of BMB Munai, Inc. Mr. Kasymov is not a director or nominee of any SEC reporting issuer.

 

Jason Kerr. Mr. Kerr graduated from the University of Utah in 1995 with a Bachelors of Science degree in Economics and in 1998 with a Juris Doctor from the same university where he was named the William H. Leary Scholar. Since 2006 Mr. Kerr has been the associate general counsel of Basic Research, LLC, concentrating in intellectual property litigation. Prior to joining Basic Research, Mr. Kerr was a partner with the law firm of Plant, Christensen & Kanell in Salt Lake City, Utah. Mr. Kerr was employed with Plant, Christensen & Kanell from 1996 through 2001 and from 2004 to 2006. From 2001 through 2004 Mr. Kerr was employed as a commercial litigator with the Las Vegas office of Lewis and Roca. Mr. Kerr is not a nominee or director of any other SEC reporting issuer.

 

 

 

Troy F. Nilson, CPA. Since February 2001, Mr. Nilson has served as an Audit Partner with Chisholm, Bierwolf & Nilson, Certified Public Accountants, in Bountiful, Utah. From December 2000 to February 2001, he served as an Audit Manager for Crouch, Bierwolf & Associates, Certified Public Accountants, in Salt Lake City, Utah. Prior to that time, Mr. Nilson served as the Senior Auditor for Intermountain Power Agency in Salt Lake City, Utah from March 1995 to December 2000. In the past five years, Mr. Nilson has had extensive public and private company audit, audit review and Securities and Exchange Commission disclosure and reporting experience. Mr. Nilson received licensure as a Certified Public Accountant in 1997. Mr. Nilson earned a Masters of Science Degree in Business Information Systems from Utah State University in December 1992, and a Bachelor of Science in Accounting from Utah State University in August 1990. Mr. Nilson is not a director or nominee of any other SEC reporting issuer.

 

Stephen Smoot. During the past five years Mr. Smoot has been self-employed as a consultant in the area of foreign technology development and transfer. Mr. Smoot assisted in forming Caspian Service Group Limited, a wholly-owned subsidiary of Caspian Services, Inc., formerly EMPS Corporation, in December 1999, and served as President of Caspian Services from inception until February 2002. Mr. Smoot served as the Interim President of EMPS Corporation from June 2004 until December 2004. Mr. Smoot is not a director or nominee of any other SEC reporting issuer.

 

Leonard M. Stillman Jr. Mr. Stillman received his Bachelor of Science in mathematics from Brigham Young University and Master of Business Administration from the University of Utah. He began his career in 1963 with Sperry UNIVAC as a programmer developing the trajectory analysis software for the Sergeant Missile system. Mr. Stillman spent many years as a designer and teacher of computer language classes at Brigham Young University, where he developed applications for the Administrative Department including the school’s first automated teacher evaluation system. During that time, he was also a Vice-President of Research and Development for Automated Industrial Data Systems, Inc and the Owner of World Data Systems Company, which provided computerized payroll services for companies such as Boise Cascade. Mr. Stillman has over 35 years of extensive business expertise including strategic planning, venture capital financing, budgeting, manufacturing planning, cost controls, personnel management, quality planning and management, and the development of standards, policies and procedures. He has extensive skills in the design and development of computer software systems and computer evaluation. Mr. Stillman is a Co-Founder of Stillman George, Inc., where he is primarily responsible for managing information, technical development and financial analysis projects and development as well as involved in general company management and consulting activities.  The company consolidates a broad variety of skills from a growing group of business professionals to provide needed support in finance, marketing, management, sales, planning, product development and more to businesses worldwide. Mr. Stillman is not a director or nominee of any other SEC reporting issuer.

 

Valery Tolkachev. Since 1999, Mr. Tolkachev has been employed with UniCreditAton in Moscow, Russia, where he currently serves as the Managing Director, Capital Markets. From 1991 to 1999, Mr. Tolkachev served in various positions with various employers including, MDM Bank, InkomBank, InkomCapital and others. Mr. Tolkachev graduated with Honors from the High Military School in Kiev, USSR in 1989. In 2005 he completed his studies at the Academy of National Economy, as a qualified lawyer. Mr. Tolkachev also serves as a director of Caspian Services, Inc., and Bekem Metals, Inc. Both are SEC reporting issuers.

 

 

 

Family Relationships

 

There are no family relationships among our directors and/or executive officers.

 

Involvement in Certain Legal Proceedings

 

During the past five years none of our executive officers, directors, promoters or control persons has been involved in any of the following events that could be material to an evaluation of his ability or integrity, including:

 

(1) Any bankruptcy petition filed by or against any business of which such person was a general partner or executive officer either at the time of the bankruptcy or within two years prior to that time.

(2) Any conviction in a criminal proceeding or being subject to a pending criminal proceeding (excluding traffic violations and other minor offenses);

(3) 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; and

(4) Being found by a court of competent jurisdiction (in a civil action), the Securities and Exchange Commission or the Commodity Futures Trading Commission to have violated a federal or state securities or commodities law, which judgment has not subsequently been reversed, suspended, or vacated.

 

Committees of the Board of Directors

 

Audit Committee

 

Our board of directors has established an audit committee, whose principal functions are to assist the board in the selection, review and oversight of our independent registered public accounting firm, the approval of all audit, review and attest services provided by the independent registered public accounting firm, the integrity of our reporting practices and the evaluation of our internal controls and accounting procedures and to resolve disagreements between management and the independent registered public accountants regarding financial reporting. The audit committee has the sole authority to retain and terminate our independent registered public accounting firm and to approve the compensation paid to our independent registered public accounting firm. The audit committee is responsible for the pre-approval of all non-audit services provided by its independent auditors. Non-audit services are only provided by our independent accountants to the extent permitted by law. The audit committee is comprised of three independent directors, Troy Nilson, Stephen Smoot and Jason Kerr, with Mr. Nilson acting as chairman. Our board of directors has determined that Mr. Nilson qualifies as an “audit committee financial expert” under the rules of the SEC adopted pursuant to the requirements of the Sarbanes-Oxley Act of 2002. Our board of directors has also determined that Mr. Nilson, Mr. Smoot and Mr. Kerr each qualify as “independent” in accordance with the applicable regulations adopted by the SEC and American Stock Exchange.

 

 

 

Report of the Audit Committee of the Board of Directors

June 16, 2008

To the Board of Directors of BMB Munai, Inc.:

We have reviewed and discussed with management the audited consolidated financial statements of BMB Munai, Inc. (the “Company”) as of and for the year ended March 31, 2008.

We have discussed with the independent auditors the matters required to be discussed by Statement on Auditing Standards No. 61, Communication with Audit Committees, as amended, by the Auditing Standards Board of the American Institute of Certified Public Accountants and Public Company Accounting Oversight Board.

We have received and reviewed the written disclosures and the letter from the independent accountants required by Independence Standards Board Standard No. 1, Independence Discussions with Audit Committees, as amended, and have discussed with the independent accountants their independence.

Based on the reviews and discussions referred to above, we recommend to the Board of Directors that the audited financial statements referred to above be included in the Company’s Annual Report on Form 10-K for the year ended March 31, 2008 for filing with the Securities and Exchange Commission.

SUBMITTED BY THE AUDIT COMMITTEE OF THE BOARD OF DIRECTORS:

Troy Nilson, Chairman

Stephen Smoot

Jason Kerr

 

 

 

 

Our board of directors has also established a compensation committee. The principal functions of the compensation committee are to:

 

 

Our compensation committee is comprised of three directors consisting of Troy Nilson, Valery Tolkachev and Stephen Smoot. Our board of directors has determined that Mr. Tolkachev qualifies as “independent” in accordance with the applicable regulations adopted by the SEC and the American Stock Exchange. Compensation for all other officers is also recommended to the board for determination, by the compensation committee.

 

We have adopted a corporate governance and nominating committee charter, which is staffed by all of the independent members of our board of directors. In general, when the board determines that expansion of the board or replacement of a director is necessary or appropriate, the independent directors will review, through candidate interviews with members of the other members of the board and management, consult with the candidate’s associates and through other means determine a candidate’s honesty, integrity, reputation in and commitment to the community, judgment, personality and thinking style, residence, willingness to devote the necessary time, potential conflicts of interest, independence, understanding of financial statements and issues, and the willingness and ability to engage in meaningful and constructive discussion regarding Company issues. The independent directors review any special expertise, for example, that qualifies a person as an audit committee financial expert, membership or influence in a particular geographic or business target market, or other relevant business experience. To date we have not paid any fee to any third-party to identify or evaluate, or to assist it in identifying or evaluating, potential director candidates.

 

The independent directors may consider director candidates nominated by shareholders during such times as the Company is actively considering obtaining new directors. Candidates recommended by shareholders will be evaluated based on the same criteria described above. Shareholders desiring to suggest a candidate for consideration should send a letter to the Company’s Secretary and include:

 

 

 

 

 

Because of the small size of the Company and the limited need to seek additional directors, there is no assurance that all shareholder proposed candidates will be fully considered, that all candidates will be considered equally, or that the proponent of any candidate or the proposed candidate will be contacted by the Company or the board, and no undertaking to do so is implied by the willingness to consider candidates proposed by shareholders.

 

 

Compliance with Section 16(a) of the Exchange Act

 

Based solely on a review of Forms 3, 4 and 5 and amendments thereto furnished to us during its most recent fiscal year, it appears that in December 2007 Askar Tashtitov and in February 2008 Sanat Kasymov inadvertently failed to timely file Form 4s when the final part of their restricted stock grant made pursuant to our 2004 Stock Incentive Plan vested. In December 2007 Boris Cherdabayev filed a Form 4 covering the sale of shares of common stock one day late.

 

Code of Ethics

 

We have adopted a Code of Ethics that applies to our principal executive, financial and accounting officers and persons performing similar duties. The Code is designed to deter wrong-doing and promote honest and ethical behavior, full, fair, timely, accurate and understandable disclosure and compliance with applicable governmental laws, rules and regulations. It is also designed to encourage prompt internal reporting of violations of the Code to an appropriate person and provides for accountability for adherence to the Code. A copy of our Code of Ethics has been posted on our website and may be viewed at www.bmbmunai.com. A copy of the Code of Ethics will be provided to any person without charge upon written request to our Corporate Secretary at our U.S. offices, 324 South 400 West, Suite 225, Salt Lake City, Utah 84101. 

 

Item 11. Executive Compensation

 

Compensation Discussion and Analysis

 

We have a compensation committee of three independent directors. That committee has been delegated authority from our board of directors and its activities are governed by a compensation committee charter. One of the roles of the compensation committee under its charter is to review and approve annually all compensation decisions relating to our executive officers. Our compensation committee utilizes external analyses and other benchmarking to inform its executive compensation decisions and processes.

 

Objectives and Philosophy of Our Executive Compensation Program

 

The primary objectives of our executive compensation program are to:

 

 

 

 

 

To achieve these objectives, our compensation committee evaluates our executive compensation program with the objective of setting compensation at levels the committee believes to be competitive with those of other companies in our industry. In addition, our executive compensation program ties a portion of each executive’s overall compensation to key strategic, financial and operational goals set by our board of directors, such as satisfying our annual minimum work program. We also provide a portion of our executive compensation in the form of equity awards that vest over time, which we believe will help to retain our executives and to align their interests with those of our stockholders by allowing the executives to participate in our longer term success as reflected in asset growth and stock price appreciation.

 

Components of our Executive Compensation Program

 

At this time, the primary elements of our executive compensation program are:

 

 

We do not have any formal or informal policy or target for allocating compensation between long-term and short-term compensation, between cash and non-cash compensation or among the different forms of non-cash compensation. Instead, we determine subjectively on a case-by-case basis the appropriate level and mix of the various compensation components.

 

Base salaries

 

Base salaries are used to recognize the experience, skills, knowledge and responsibilities required of all our employees, including our executives. Base salaries for our executives typically have been set in our offer letter to the executive at the outset of employment. Under the terms of our employment agreements, consistent with our executive compensation program objectives, base salaries for our executives, together with other components of compensation, may be evaluated by our compensation committee for adjustment based on an assessment of an executive’s performance and compensation trends in our industry.

 

Cash bonuses

 

We use cash bonuses to incentivized our employees. Our compensation committee has the discretion to award cash bonuses based on our financial performance and individual objectives. The corporate financial performance measures, which have typically been developed by our board of directors, are given the greatest weight in this bonus analysis. During fiscal 2008 the named executive officers were awarded cash bonuses.

 

 

Equity incentive awards

 

Our equity award program is the primary vehicle for offering long-term incentives to our executives. Our equity awards to executives have typically been made in the form of restricted stock grants and stock options. Although we do not have any equity ownership guidelines for our executives, we believe that equity grants provide our executives with a direct link to our long-term performance, create an ownership culture and align the interests of our executives and our stockholders. In addition, the vesting feature of our equity grants should further our objective of executive retention because this feature provides an incentive to our executives to remain in our employ during the vesting period.

 

In determining the size of equity grants to our executives, our compensation committee and board of directors have considered comparative share ownership of executives in our compensation peer group, the Company’s performance, the applicable executive’s performance, the amount of equity previously awarded to the executive, the vesting of such awards and the recommendations of management.

 

Grants of equity awards, including those to executives, are all approved by our compensation committee and the board of directors and generally are granted based on the fair market value of our common stock. In the past, vesting of equity awards has varied from immediate vesting to vesting of periods ranging from three to five years depending on the purpose of the award. When we made equity awards that vested immediately, they were typically in recognition of services already rendered or goals already accomplished. Since fiscal 2007, the compensation committee has moved to tie the vesting of equity awards to the realization of certain Company goals.

 

Generally, our compensation committee meets annually to review our executive compensation program objectives and make recommendations to our board of directors regarding equity awards and  incentives to retain employees. We do not have a program, plan or practice of selecting grant dates for equity compensation to our executive officers in coordination with the release of material non-public information. Equity award grants are made from time to time in the discretion of our compensation committee consistent with our executive compensation program objectives. Our compensation committee did not determine or propose equity incentive awards during the 2008 fiscal year.

 

Benefits and other compensation

 

Under the terms of their employment contracts, our named executive officers are permitted to participate in such pension, profit sharing, bonus, life insurance, hospitalization, major medical and other employee benefit plans as may be in effect from time to time to the extent the executive is eligible under the terms of such plans.

 

Under the employment agreements with our named executive officers, we agree to pay all taxes and dues under applicable laws of Kazakhstan for our named executive officers including income and social taxes and government pension fund payments.

 

 

 

We make payments of mandatory social tax in an amount ranging from 5% to 13% of employee wages. These costs are recorded in the period when they are incurred and presented as salary related tax expense in the income statement.

 

Pension fund payment

 

In accordance with the legislative requirements of the Republic of Kazakhstan during 2008 we were required to pay into an employee pension fund an amount equivalent to 10% of each employee’s wages, up to a maximum of $700 per month. Pension fund payments are withheld from employees’ salaries and included with other salary costs in the income statement. We do not have any other liabilities related to any supplementary pensions, post retirement health care, insurance benefits or retirement indemnities.

 

 

Summary Compensation Table

 

The table below summarizes compensation paid to or earned by our Chief Executive Officer, our Chief Financial Officer and our other most highly compensated executive officers, who we refer to collectively as our “named executive officers.”

 

 

 

All Other Compensation

 

The table below provides additional information regarding “all other compensation” awarded to the named executive officers as disclosed in the “All Other Compensation” column of the “Summary Compensation Table for Fiscal Year 2008” above.

 

 

 

 

 

Employment Agreements

 

We have employment agreements with each of our named executive officers.

 

Except for annual salary, and as otherwise specifically addressed herein, the terms and conditions of the employment agreement of each of the executive and non-executive level officers are the same in all material respects. The employment agreements provide for an initial term of one year with two consecutive one-year renewals unless terminated by either party prior to the beginning of the renewal term. A form of the Employment Agreement was filed as an exhibit to the Current Report on Form 8-K we filed on April 12, 2007.

 

Under the agreements, salary is reviewable no less frequently than annually and may be adjusted up or down by the compensation committee in its sole discretion, but may not be adjusted below the initial annual salary amount listed in the agreement. The agreements provide that each of the officers is entitled to participate in such pension, profit sharing, bonus, life insurance, hospitalization, major medical and other employee benefit plans of the company that may be in effect from time to time, to the extent the individual is eligible under the terms of those plans. The agreements provide that each officer is eligible at the discretion of the compensation committee and the board of directors to receive performance bonuses. Each officer is entitled to 28 days vacation in accordance with the vacation policies of the Company, as well as paid holidays and other paid leave set forth in the Company’s policies. There is no accrual of vacation days and holidays.

 

The agreements and, as detailed below, all obligations thereunder may be terminated upon the occurrence of the following events: i) death, ii) disability; iii) for cause immediately upon notice from the Company or at such time as indicated by the Company in said notice; iv) for good reason upon not less than 30 days notice from an officer to the Company; v) an extraordinary event, unless otherwise agreed in writing.

 

Under the agreements the named executive officer may be deemed disabled if for physical or mental reasons he is unable to perform his duties for 120 consecutive days or 180 days during any 12 month period. Such disability will be determined by a jointly agreed upon medical doctor.

 

The agreements provide that any of the following will constitute “cause”: i) breach of the employment agreement; ii) failure to adhere to the written policies of the Company; iii) appropriation by the officer of a material business opportunity; iv) misappropriation of funds or property of the Company; v) conviction, indictment or the entering of a guilty plea or a plea of no contest to a felony.

 

“Good reason” under the agreements may mean any of the following: i) a material breach of the employment agreement; ii) assignment of the officer without his consent to a position of lesser status or degree of responsibility.; iii) relocation of the Company’s principal executive offices outside the Republic of Kazakhstan; iv) if the Company requires the officer to be based somewhere other than principal executive offices of the Company without the officer’s consent.

 

 

Under the employment agreements, “extraordinary event” is defined as any consolidation or merger of the Company or any of its subsidiaries with another person, or any acquisition of the Company or any of its subsidiaries by any person or group of persons, acting in concert, equal to thirty percent (30%) or more of the outstanding stock of the Company or any of its subsidiaries, or the sale of all or substantially all of the assets of the Company or any of its subsidiaries.

 

Upon termination of an employment agreement, the Company will make a termination payment to the officer in lieu of all other amounts and in settlement and complete release of all claims employee may have against the Company. In the event of termination for good reason by the officer, the Company will pay the officer the remainder of his salary for the calendar month in which the termination is effective and for six consecutive calendar months thereafter. The officer shall also be entitled to any portion of incentive compensation for the year, prorated to the date of termination. Notwithstanding the foregoing, if the officer obtains other employment prior to the end of the six-month period, salary payments by the Company after he begins employment with a new employer shall be reduced by the amount of the cash compensation received from the new employer. If the officer is terminated for cause, he will receive salary only through the date of termination and will not be entitled to any incentive compensation for the year in which his employment is terminated. If the termination is the result of a disability, the Company will pay salary for the rest of the month during which termination is effective and for the shorter of six consecutive months thereafter or until disability insurance benefits commence. If employment is terminated as a result of the death of the officer, his heirs shall be entitled to salary through the month in which his death occurs and to incentive compensation prorated through the month of his death. If the employment agreement is terminated as a result of an extraordinary event, the officer shall be entitled to severance pay as follows:

 

 

All benefits terminate on the date of termination. The named executive officer shall be entitled to accrued benefits. In accordance with local Kazakh legislation, a Kazakhstan-based officer would also be entitled to compensation for unused vacation, holiday, sick leave or other leave.

 

Grants of Plan-Based Awards Table for Fiscal Year 2008

 

During fiscal 2008 we made no grants of plan-based awards to any of the named executive officers.

 

 

Outstanding Equity Awards at Fiscal Year End Table for Fiscal Year End 2008

 

The following table sets forth information regarding the outstanding stock options held by our named executive officers as of March 31, 2008.

 

 

 

 

Option Exercises and Stock Vested for Fiscal Year 2008

 

The following table sets forth the number of shares acquired pursuant to the exercise of stock options by, and the number of restricted stock awards that vested for, our named executive officers during fiscal 2008 and the aggregate dollar amount realized by our named executive officers upon exercise of options.

 

 

 

Compensation of Directors

 

We use a combination of cash and equity-based compensation to attract and retain candidates to serve on our board of directors. We compensate the independent members of our board of directors.

 

Meeting Fees

 

Independent members of the board of directors are paid a $25,000 stipend per year, plus $1,000 for each directors meeting attended in person, plus airfare and hotel expenses.

 

Equity Compensation

 

We do not currently have a fixed plan for the award of equity compensation to our non-employee directors. Equity compensation of independent directors, if any, is typically recommended by the compensation committee or management and is subject to approval of the full board of directors. All equity grants to directors are granted at a price equal to the fair market value of our common stock on the date of the grant. We anticipate that the vesting, exercise date and expiration date of future grants will vary.

 

Director Compensation Table

 

The following table sets forth a summary of the compensation we paid to our non-employee directors for services on our board during our 2008 fiscal year.

 

 

 

Compensation Committee Interlocks and Insider Participation

 

Mr. Nilson, Mr. Smoot and Mr. Tolkachev served on our compensation committee during the entire 2008 fiscal year. No member of our compensation committee during fiscal 2008 is or was formerly an officer or employee of the Company or any of its subsidiaries. No interlocking relationship exists between any member of our compensation committee and the compensation committee of any other company, nor has any such interlocking relationship existed in the past.

 

 

Compensation Committee Report

 

The compensation committee of the board of directors has reviewed and discussed the Compensation Discussion and Analysis required by Item 402(b) of Regulation S-K with management and, based on such review and discussions, the compensation committee recommended to the board of directors that the Compensation Discussion and Analysis be included in this Annual Report on Form 10-K.

 

 

 

The term “beneficial owner” refers to both the power of investment and the right to buy and sell our shares. It also refers to rights of ownership or the right to receive distributions from the Company and proceeds from the sale of Company shares. Since these rights may be held or shared by more than one person, each person who has a beneficial ownership interest in shares is deemed to be the beneficial owners of the same shares because there is shared power of investment or shared rights of ownership.

 

The following table sets forth as of June 10, 2008, the name and the number of shares of our common stock, par value of $0.001 per share, held of record or beneficially by each person who held of record, or was known by us to own beneficially, more than 5% of the 44,784,134 outstanding shares of our common stock, and the name and shareholdings of each director and of all executive officers and directors as a group.

 

 

 

 

 

* Less than 1%.

 

  66

Messers. Kasymov, Kulumbetov and Tashtitov are officers of the Company. Mr. Tolmakov is an officer of the Company’s wholly-owned subsidiary, Emir Oil, LLP. Messers. Cherdabayev, Kerr, Nilson, Smoot, Stillman, Tashtitov and Tolkachev are directors of the Company.

 

Item 13. Certain Relationships and Related Transactions and Director Independence

 

During 2008, 2007 and 2006 we leased land, oil storage facilities and office and warehouse space in Aktau, Kazakhstan from Term Oil LLC. We expect to continue to lease these facilities for the full term of our agreement with Term Oil LLC, which expires on December 31, 2009. During the fiscal years ended March 31, 2008, 2007 and 2006 we paid Term Oil $254,427, $203,686 and $276,055, respectively for the use of these facilities. Toleush Tolmakov, a BMB shareholder and the director of Emir Oil, is the sole owner of Term Oil.

 

In accordance with the written policy adopted by our board of directors and the American Stock Exchange listing standards, our audit committee is charged with monitoring and reviewing issues involving potential conflicts of interests and reviewing and approving all related party transactions. In general, for purposes of the Company’s written policy, a related party transaction is a transaction, or a material amendment to any such transaction, involving a related party and the Company involving $120,000 or more. Our policy requires the audit committee to review and approve related party transactions. In reviewing and approving any related party transaction or material amendment to any such transaction, the audit committee must satisfy itself that it has been fully informed as to the related party’s relationship to the Company and interest in the transaction and as to the material facts of the transaction, and must determine that the related party transaction is fair to the Company.

 

Director Independence

 

The board of directors has determined that Boris Cherdabayev the Chairman of our board of directors and Askar Tashtitov, our Company president would not be considered “independent directors” as that term is defined in the listing standards of the American Stock Exchange. The board of directors has further determined that Leonard Stillman, who will become our interim CFO upon the effectiveness of the resignation of our current CFO, will also no longer be considered independent upon his appointment as interim CFO. The board of directors has determined that the other four members of our board are “independent directors” as that term is defined in the listing standards of the American Stock Exchange. Such independence definition includes a series of objective tests, including that the director is not an employee of the company and has not engaged in various types of business dealings with the company. In addition, as further required by the American Stock Exchange listing standards, the board of directors has made a subjective determination as to each independent director that no relationships exist which, in the opinion of the board of directors, would interfere with the exercise of independent judgment in carrying out the responsibilities of a director.

 

 

Item 14. Principal Accounting Fees and Services

 

On February 21, 2007, the audit committee of our board of directors terminated the engagement of BDO Kazakhstanaudit, who had served as our independent registered public accounting firm since February 2004. On February 21, 2007, we engaged Hansen, Barnett & Maxwell, Certified Public Accountants to serve as our independent registered public accounting firm.

 

Principal accounting fees for professional services rendered for us by Hansen, Barnett & Maxwell P.C. and BDO Kazakhstanaudit for the years ended March 31, 2008 and 2007 were:

 

 

Audit Fees. Audit fees were for professional services rendered in connection with the audit of the financial statements included in our annual report on Form 10-K and review of the financial statements included in our quarterly reports of Form 10-Q and for services normally provided by our independent registered public accounting firm in connection with statutory and regulatory filings or engagements and fees for Sarbanes-Oxley 404 audit work.

 

Tax Fees. Hansen Barnett & Maxwell billed us an aggregate of $6,329 for professional services rendered for tax compliance, tax advice and tax planning within the United States for the fiscal year ended March 31, 2008.

 

Audit Committee Pre-Approval Policies and Procedures. The Audit Committee had not, as of the time of filing this annual report on Form 10-K with the Securities and Exchange Commission, adopted policies and procedures for pre-approving audit or permissible non-audit services performed by our independent auditors. Instead, the Audit Committee as a whole has pre-approved all such services. In the future, our Audit Committee may approve the services of our independent auditors pursuant to pre-approval policies and procedures adopted 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 our management.

 

The Audit Committee has determined that the provision of services by Hansen, Barnett & Maxwell described above are compatible with maintaining Hansen, Barnett & Maxwell’s independence as our independent registered public accounting firm.

 

 

Item 15. Exhibits, Financial Statement Schedules

 

Exhibit 12.1

Computation of Earnings to Fixed Charges

 

 

 

SIGNATURES

 

In accordance with Section 12 of the Securities Exchange Act of 1934, the registrant caused this registration statement to be signed on its behalf, thereunto duly authorized.

 

 

 

 

 

 

CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED MARCH 31, 2008, 2007 AND 2006

 

 

 

 

Table of Contents

 

 

 

HANSEN, BARNETT & MAXWELL, P.C.

 

 

 

 

 

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

 

To the Board of Directors and Stockholders

BMB Munai, Inc.

 

We have audited the accompanying consolidated balance sheets of BMB Munai, Inc. and subsidiary as of March 31, 2008 and 2007, and the related consolidated statements of operations, stockholders’ equity, and cash flows for each of the years in the two-year period ended March 31, 2008. BMB Munai, Inc.’s management is responsible for these financial statements. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits 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 audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of BMB Munai, Inc. and subsidiary as of March 31, 2008 and 2007, and the results of its operations and its cash flows for each of the years in the two-year period ended March 31, 2008 in conformity with accounting principles generally accepted in the United States of America.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), BMB Munai, Inc.’s internal control over financial reporting as of March 31, 2008, based on criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO), and our report dated June 11, 2008 expressed an unqualified opinion.

As discussed in Note 2, the accompanying consolidated balance sheet as of March 31, 2007 and consolidated statement of cash flows for the year ended March 31, 2007 have been restated for the effects of correcting the classification of inventories for oil and gas projects and prepayments for materials used in oil and gas projects as of March 31, 2007.

 

 

HANSEN, BARNETT & MAXWELL, P.C.

Salt Lake City, Utah

June 11, 2008

 

 

 

BDO KAZAKHSTANAUDIT, LLP

56A building, 6 mcr,

Almaty City, 050036 Kazakhstan

Phone (727) 228-1401

Fax (727) 298-2709

www.bdo.kz

 

 

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

 

The Board of Directors

BMB Munai, Inc.

 

We have audited the accompanying consolidated balance sheets of BMB Munai, Inc. as of March 31, 2006 and of March 31, 2005, and the related consolidated statements of loss, shareholders' equity, and cash flows for the year ended March 31, 2006 and of March 31, 2005. These 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 an 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 misstatements. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audit included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for purposes of expressing an opinion on the effectiveness of the Company's internal control over financial reporting.

 

Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audit provides reasonable basis for our opinion.

 

In our opinion, the financial statements referred to above present fairly, in all material respects, the consolidated financial position of BMB Munai, Inc. at March 31, 2006 and at March 31, 2005 and the consolidated results of its operations and its cash flow for the year ended March 31, 2006 and March 31, 2005 in conformity with accounting principles generally accepted in the United States of America.

 

As discussed in Note 2, the accompanying consolidated statement of cash flows for the year ended March 31, 2006 have been restated for the effects of correcting the classification of inventories for oil and gas projects and prepayments for materials used in oil and gas projects as of March 31, 2006.

 

 

/s/ BDO Kazakhstanaudit, LLP

 

June 26, 2006, except for Note 2, which date is as of June 11, 2008.

Almaty, Kazakhstan

 

 

 

 

 

 

BMB MUNAI, INC.

 

CONSOLIDATED BALANCE SHEETS

 

 

 

See notes to the consolidated financial statements.

 

 

BMB MUNAI, INC.

CONSOLIDATED STATEMENTS OF OPERATIONS

 

 

 

See notes to the consolidated financial statements.

 

 

BMB MUNAI, INC

CONSOLIDATED STATEMENTS OF SHAREHOLDERS’ EQUITY

 

 

 

 

 

See notes to the consolidated financial statements.

 

 

 

BMB MUNAI, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS
 

 

 

See notes to the consolidated financial statements.

 

 

 

BMB MUNAI, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS (CONTINUED)
 

 

 

 

See notes to the consolidated financial statements.

 

F-7

 

 

BMB MUNAI, INC.

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

NOTE 1 - DESCRIPTION OF BUSINESS

 

The corporation now known as BMB Munai, Inc., (“BMB Munai” or the “Company”) was originally incorporated in Utah in July 1981. On February 7, 1994, the corporation changed its name to InterUnion Financial Corporation (“InterUnion”) and its domicile to Delaware. BMB Holding, Inc. (“BMB Holding”) was incorporated on May 6, 2003 for the purpose of acquiring and developing oil and gas fields in the Republic of Kazakhstan. On November 26, 2003, InterUnion executed an Agreement and Plan of Merger (the “Agreement”) with BMB Holding. As a result of the merger, the shareholders of BMB Holding obtained control of the corporation. BMB Holding was treated as the acquiror for accounting purposes. A new board of directors was elected that was comprised primarily of the former directors of BMB Holding and the name of the corporation was changed to BMB Munai, Inc.

 

The Company’s consolidated financial statements presented are a continuation of BMB Holding, and not those of InterUnion Financial Corporation, and the capital structure of the Company is now different from that appearing in the historical financial statements of InterUnion Financial Corporation due to the effects of the recapitalization.

 

The Company has a representative office in Almaty, Republic of Kazakhstan.

 

From inception (May 6, 2003) through January 1, 2006 the Company had minimal operations and was considered to be in the development stage. The Company began generating significant revenues in January 2006 and is no longer in the development stage.

 

If the Company is unable to drill and complete a sufficient number of wells in each of its identified structures to support its claim of commercially producible reserves before the end of the term of its exploration contract, as extended, the Company may not be granted a commercial production contract for each of its structures.

 

In order to obtain a commercial production license for the structures contained within the Company’s licensed territory, it must engage in sufficient exploration, drilling and testing activities to gather adequate data to support its claims that it has discovered commercial producible reserves within its contract territory. These activities must be completed during the term of the exploration license, which expires in July 2009. It is generally accepted that one exploratory and two appraisal wells are sufficient to determine whether a license holder has discovered a commercially producible reserve, although in some instances, license holders are able to establish commercially producible reserves with fewer than three wells. Currently the Company has completed eighteen wells with an additional four wells in progress. As discussed in more detail in Note 2, at March 31, 2008, the Company has not yet applied for or been granted a commercial production license, and is currently pursuing an extension of the exploration phase.

 

F-8

 

 

BMB MUNAI, INC.

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

 

NOTE 2 - SIGNIFICANT ACCOUNTING POLICIES

 

Basis of consolidation

 

The Company’s consolidated financial statements present the consolidated results of BMB Munai, Inc., and its wholly owned subsidiary, Emir Oil LLP (hereinafter collectively referred to as the “Company”). All significant inter-company balances and transactions have been eliminated from the Consolidated Financial Statements.

 

Use of estimates

 

The preparation of Consolidated Financial Statements in conformity with US GAAP requires management to make estimates and assumptions that affect certain reported amounts of assets and liabilities and the disclosures of contingent assets and liabilities at the date of the Consolidated Financial Statements and revenues and expenses during the reporting period. Accordingly, actual results could differ from those estimates and affect the results reported in these Consolidated Financial Statements.

 

Restatement of Financial Statements

 

The consolidated balance sheet as of March 31, 2007 and the statements of cash flows for the years ended March 31, 2007 and 2006 have been restated to correct the classification of inventories for materials for oil and gas projects and prepayments for materials used in oil and gas projects from current assets to long term assets. The Company concluded inventories for materials for oil and gas projects and prepayments for materials used in oil and gas projects should be treated as long term assets due to their future classification to oil and gas properties once the materials are used in the projects. The correction of these balances had no effect on the previously reported net income. The effects of the restatements were as follows:

 

F-9

 

 

BMB MUNAI, INC.

 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

 

 

Concentration of Credit Risk and Accounts Receivable

 

Financial instruments that potentially subject the Company to a concentration of credit risk consist principally of cash and accounts receivable. The Company places its cash with high credit quality financial institutions. Substantially all of the Company’s accounts receivable is from purchasers of oil and gas. Oil and gas sales are generally unsecured. The Company has not had any significant credit losses in the past and believes its accounts receivable are fully collectable. Accordingly, no allowance for doubtful accounts has been provided.

 

Licences and contracts

 

Emir Oil LLP is the operator of the Company’s oil and gas fields in Western Kazakhstan. The Government of the Republic of Kazakhstan (the “Government”)

 

 

BMB MUNAI, INC.

 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

 

initially issued the license to Zhanaozen Repair and Mechanical Plant on April 30, 1999 to explore the Aksaz, Dolinnoe and Emir oil and gas fields (the “ADE Block” or the “ADE Fields”). On June 9, 2000, the contract for exploration of the Aksaz, Dolinnoe and Emir oil and gas fields was entered into between the Agency of the Republic of Kazakhstan on Investments and the Zhanaozen Repair and Mechanical Plant. On September 23, 2002, the contract was assigned to Emir Oil LLP. On September 10, 2004 the Government extended the term of the Contract for exploration and License from five years to seven years through July 9, 2007. On February 27, 2007, the Ministry of Energy and Mineral Resources of the Republic of Kazakhstan (“MEMR”) granted a second extension of Company’s exploration contract. Under the terms of the contract extension, the exploration period was extended to July 2009 over the entire exploration contract territory. On December 7, 2004 the Government assigned to Emir Oil LLP exclusive right to explore an additional 260 square kilometers of land adjacent to the ADE Block, which is referred to as the “Extended Territory.” The Extended Territory includes the Kariman, Yessen and Borly oil and gas fields and is governed by the terms of the Company’s original contract.

 

To move from the exploration and development stage to the commercial production stage, the Company must apply for and be granted a commercial production contract. The Company is legally entitled to apply for a commercial production contract and has an exclusive right to negotiate this Contract and the Government is obligated to conduct these negotiations under the Law of Petroleum in Kazakhstan. If the Company does not move from the exploration and development stage to the commercial production stage, it has the right to produce and sell oil, including export oil, under the Law of Petroleum for the term of its existing contract.

 

Major Customers

 

During the years ended March 31, 2008, 2007 and 2006, sales to one customer represented 91%, 100% and 100% of total sales, respectively. At March 31, 2008, 2007 and 2006, this customer made up 97%, 100% and 100% of accounts receivable, respectively. The loss of this foregoing customer could have a material adverse affect on the Company, although there is an available market for the Company’s crude oil and natural gas production from other purchasers.

 

 

BMB MUNAI, INC.

 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

Foreign currency translation

 

Transactions denominated in foreign currencies are reported at the rates of exchange prevailing at the date of the transaction. Monetary assets and liabilities denominated in foreign currencies are translated to United States Dollars at the rates of exchange prevailing at the balance sheet dates. Any gains or losses arising from a change in exchange rates subsequent to the date of the transaction are included as an exchange gain or loss in the Consolidated Statements of Operations.

 

Share-based compensation

 

The Company accounts for options granted to non-employees at their fair value in accordance with SFAS No. 123R, Share Based Payment and EITF Abstracts Issue 96-18, Accounting for Equity Instruments That Are Issued to Other Than Employees for Acquiring, or in Conjunction with Selling, Goods or Services. Under SFAS No. 123R, share-based compensation is determined as the fair value of the equity instruments issued. The measurement date for these issuances is the earlier of the date at which a commitment for performance by the recipient to earn the equity instruments is reached or the date at which the recipient’s performance is complete. Stock options granted to the “selling agents” in the private equity placement transactions have been offset to the proceeds as a cost of capital. Stock options and stocks granted to other non-employees are recognized in the Consolidated Statements of Operations.

 

The Company has a stock option plan as described in Note 14. Compensation expense for options and stock granted to employees is determined based on their fair values at the time of grant, the cost of which is recognized in the Consolidated Statements of Operations over the vesting periods of the respective options.

 

Share-based compensation incurred for the years ended March 31, 2008, 2007 and 2006 was $2,303,078, $4,134,823 and $4,973,636, respectively.

 

Risks and uncertainties

 

The ability of the Company to realize the carrying value of its assets is dependent on being able to develop, transport and market oil and gas. Currently exports from the Republic of Kazakhstan are primarily dependent on transport routes either via rail, barge or pipeline, through Russian territory. Domestic markets in the Republic of Kazakhstan historically and currently do not permit world market price to be obtained. Management believes that over the life of the project, transportation options will improve as additional pipelines and rail-related infrastructure is built that will increase transportation capacity to the world markets; however, there is no assurance that this will happen in the near future.

 

 

 

Recognition of revenue and cost

 

Revenue and associated costs from the sale of oil are charged to the period when persuasive evidence of an arrangement exists, the price to the buyer is fixed or determinable, collectability is reasonably assured, delivery of oil has occurred or when ownership title transferred. Produced but unsold products are recorded as inventory until sold.

 

Income taxes

 

The Company accounts for income taxes using the liability method. Under the liability method, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. Under the liability method, the effect on previously recorded deferred tax assets and liabilities resulting from a change in tax rates is recognized in earnings in the period in which the change is enacted.

 

Cash and cash equivalents

 

The Company considers all demand deposits, money market accounts and marketable securities purchased with an original maturity of three months or less to be cash and cash equivalents. The fair value of cash and cash equivalents approximates their carrying amounts due to their short-term maturity.

 

Prepaid expenses and other assets

 

Prepaid expenses and other assets are stated at their net realizable values after deducting provisions for uncollectible amounts. Such provisions reflect either specific cases or estimates based on evidence of collectability. The fair value of prepaid expense and other asset accounts approximates their carrying amounts due to their short-term maturity.

 

Prepayments for materials used in oil and gas projects

 

The Company periodically makes prepayments for materials used in oil and gas projects. These prepayments are presented as long term assets due to their transfer to oil and gas properties after materials are supplied and the prepayments are closed.

 

 

 

Inventories

 

Inventories of equipment for development activities, tangible drilling materials required for drilling operations, spare parts, diesel fuel, and various materials for use in oil field operations are recorded at the lower of cost and net realizable value. Under the full cost method, inventory is transferred to oil and gas properties when used in exploration, drilling and development operations in oilfields.

 

Inventories of crude oil are recorded at the lower of cost or net realizable value. Cost comprises direct materials and, where applicable, direct labor costs and overhead, which has been incurred in bringing the inventories to their present location and condition. Cost is calculated using the weighted average method. Net realizable value represents the estimated selling price less all estimated costs to completion and costs to be incurred in marketing, selling and distribution.

 

The Company periodically assesses its inventories for obsolete or slow moving stock and records an appropriate provision, if there is any. The Company has assessed inventory at March 31, 2008 and no provision for obsolete inventory has been provided.

 

Oil and gas properties

 

The Company follows the full cost method of accounting for its costs of acquisition, exploration and development of oil and gas properties.

 

Under full cost accounting rules, the net capitalized costs of evaluated oil and gas properties shall not exceed an amount equal to the present value of future net cash flows from estimated production of proved oil and gas reserves, based on current economic and operating conditions, including the use of oil and gas prices as of the end of the period.

 

Given the volatility of oil and gas prices, it is reasonably possible that the estimate of discounted future net cash flows from proved oil and gas reserves could change. If oil and gas prices decline, even if only for a short period of time, it is possible that impairments of oil and gas properties could occur. In addition, it is reasonably possible that impairments could occur if costs are incurred in excess of any increases in the cost ceiling, revisions to proved oil and gas reserves occur, or if properties are sold for proceeds less than the discounted present value of the related proved oil and gas reserves.

 

All geological and geophysical studies, with respect to the licensed territory, have been capitalized as part of the oil and gas properties.

 

The Company’s oil and gas properties primarily include the value of the license and other capitalized costs.

 

 

 

Depletion of producing properties is computed using the unit-of-production method based on estimated proved reserves.

 

Liquidation fund

 

Liquidation fund (site restoration and abandonment liability) is related primarily to the conservation and liquidation of the Company’s wells and similar activities related to its oil and gas properties, including site restoration. Management assessed an obligation related to these costs with sufficient certainty based on internally generated engineering estimates, current statutory requirements and industry practices. The Company recognized the estimated fair value of this liability. These estimated costs were recorded as an increase in the cost of oil and gas assets with a corresponding increase in the liquidation fund which is presented as a long-term liability. The oil and gas assets related to liquidation fund are depreciated on the unit-of-production basis separately for each field. An accretion expense, resulting from the changes in the liability due to passage of time by applying an interest method of allocation to the amount of the liability, is recorded as accretion expenses in the Consolidated Statement of Operations.

 

The adequacies of the liquidation fund are periodically reviewed in the light of current laws and regulations, and adjustments made as necessary.

 

Other fixed assets

 

Other fixed assets are valued at historical cost adjusted for impairment loss less accumulated depreciation. Historical cost includes all direct costs associated with the acquisition of the fixed assets.

 

Depreciation of other fixed assets is calculated using the straight-line method based upon the following estimated useful lives:

 

Maintenance and repairs are charged to expense as incurred. Renewals and betterments are capitalized.

 

Other fixed assets of the Company are evaluated annually for impairment. If the sum of expected undiscounted cash flows is less than net book value, unamortized costs of other fixed assets will be reduced to a fair value. The Company’s annual evaluation resulted in no impairment at March 31, 2008.

 

 

 

Convertible notes payable issue costs

 

In accordance with the Accounting Principles Board Opinion 21 “Interest on Receivables and Payables”, the Company recognizes convertible notes payable issue costs on the balance sheet as deferred charges, and amortizes the balance over the term of the related debt. The Company follows the guidance in the EITF 95-13 “Classification of Debt Issue Costs in the Statement of Cash Flows” and classifies cash payments for bond issue costs as a financing activity.

 

Restricted cash

 

Restricted cash includes funds deposited in a Kazakhstan bank and is restricted to meet possible environmental obligations according to the regulations of the Republic of Kazakhstan.

 

Functional currency

 

The Company makes its principal investing and financing transactions in U.S. Dollars and the United States Dollar is therefore its functional currency.

 

Recent accounting pronouncements

 

In March 2008, the FASB issued Statement No. 161, “Disclosures about Derivative Instruments and Hedging Activities – an amendment of FASB Statements No. 133”. This Statement requires that objectives for using derivative instruments be disclosed in terms of underlying risk and accounting designation. This disclosure better conveys the purpose of derivative use in terms of the risks that the entity is intending to manage. Disclosing the fair values of derivative instruments and their gains and losses in a tabular format should provide a more complete picture of the location in an entity’s financial statements of both the derivative positions existing at period end and the effect of using derivatives during the reporting period. Disclosing information about credit-risk-related contingent features should provide information on the potential effect on an entity’s liquidity from using derivatives. This Statement requires cross-referencing within the footnotes, which should help users of financial statements locate important information about derivative instruments. This Statement is effective for financial statements issued for the fiscal years and interim periods beginning after November 15, 2008. Management does not anticipate this Statement will impact the Company’s consolidated financial position or consolidated results of operations and cash flows.

 

In December 2007, the FASB issued Statement No. 160, “Non-controlling Interests in Consolidated Financial Statements.” This Statement requires the ownership interests in subsidiaries held by parties other than the parent be clearly identified,

 

 

 

labeled, and presented in the consolidated statement of financial position within equity, but separate from the parent’s equity; the amount of consolidated net income attributable to the parent and to the non-controlling interest be clearly identified and presented on the face of the consolidated statement of income; changes in a parent’s ownership interest while the parent retains its controlling financial interest in its subsidiary be accounted for consistently; when a subsidiary is deconsolidated, any retained non-controlling equity investment in the former subsidiary be initially measured at fair value; entities provide sufficient disclosures that clearly identify and distinguish between the interests of the parent and the interests of the non-controlling owners. This Statement is effective for financial statements issued for the fiscal years beginning after December 15, 2008. Management does not anticipate this Statement will impact the Company’s consolidated financial position or consolidated results of operations and cash flows.

 

In December 2007, the FASB issued a revision of Statement No. 141, “Business Combinations.” This Statement establishes principles and requirements for how the acquirer recognizes and measures in its financial statements the identifiable assets acquired, the liabilities assumed, and any non-controlling interest in the acquiree; recognizes and measures the goodwill acquired in the business combination or a gain from a bargain purchase; determines what information to disclose to enable users of the financial statements to evaluate the nature and financial effects of the business combination. This Statement applies prospectively to business combinations for which the acquisition date is after the beginning of the first annual reporting period beginning after December 15, 2008. Management does not anticipate this Statement will impact the Company’s consolidated financial position or consolidated results of operations and cash flows.

 

In February 2007, the FASB issued Statement No. 159, “The Fair Value Option for Financial Assets and Financial Liabilities—Including an amendment of FASB Statement No. 115”. This Statement permits entities to choose to measure many financial instruments and certain other items at fair value. The objective is to improve financial reporting by providing entities with the opportunity to mitigate volatility in reported earnings caused by measuring related assets and liabilities differently without having to apply complex hedge accounting provisions. This Statement is expected to expand the use of fair value measurement, which is consistent with the Board’s long-term measurement objectives for accounting for financial instruments. This Statement is effective for financial statements issued for the fiscal years beginning after November 15, 2007. Management does not anticipate this Statement will impact the Company’s consolidated financial position or consolidated results of operations and cash flows.

 

In September 2006, the Financial Accounting Standards Board (FASB) issued SFAS No. 157, Fair Value Measurements, which defines fair value, establishes a framework for measuring fair value in generally accepted accounting principles and expands disclosures about fair value measurements. SFAS No. 157 is effective for

 

 

 

fiscal years beginning after November 15, 2007, and interim periods within those fiscal years. In February 2008, the FASB issued FASB Staff Position (FSP FIN) No. 157-2 which extended the effective date for certain nonfinancial assets and nonfinancial liabilities to fiscal years beginning after November 15, 2008. The Company does not expect the adoption of SFAS No. 157 to have a material impact on the consolidated financial statements.

 

NOTE 3 - CASH AND CASH EQUIVALENTS

 

As of March 31, 2008 and 2007 cash and cash equivalents included:

 

 

As of March 31, 2008 and 2007, cash and cash equivalents included $14,203,574 and $7,702,483 placed in money market funds having 30 day simple yields of 2.58% and 4.99%, respectively.

 

NOTE 4 - PREPAID EXPENSES AND OTHER ASSETS

 

Prepaid expenses and other assets as of March 31, 2008 and 2007, were as follows:

 

 

Additional reserves against uncollectible advances and prepayments in the amount of

$ 135,502 were formed for the year ended March 31, 2008.

 

 

 

NOTE 5 - OIL AND GAS PROPERTIES

 

Oil and gas properties using the full cost method as of March 31, 2008 and 2007, were as follows:

 

 

The purchase of Emir Oil LLP (see Note 13) has been accounted for as a non-taxable business combination. Since goodwill was not recognized in this stock based subsidiary acquisition involving oil and gas properties, a recognition of a deferred tax liability related to the acquisition increases the financial reporting basis of the oil and gas properties.

 

NOTE 6 – INVENTORIES FOR OIL AND GAS PROJECTS

 

As of March 31, 2008 and 2007 inventories included:

 

 

 

 

 

NOTE 7 - OTHER FIXED ASSETS

 

 

In accordance with SFAS No. 19, Financial Accounting and Reporting by Oil and Gas Producing Companies, depreciation related to support equipment and facilities used in exploration and development activities in the amount of $180,804 was capitalized to oil and gas properties for the year ended March 31, 2008.

 

NOTE 8 - CONSTRUCTION IN PROGRESS

 

On April 13, 2006 the Company entered into the Agreement on Joint Business (the “Agreement”) with Ecotechnic Chemicals AG incorporated in Switzerland, (“Ecotechnic”) for construction of facility on utilization of associated gas on the Company’s fields (the “Facility”). After completion of the Facility construction, the Company and Ecotechnic will sign the agreement on the formation of a joint venture company, which will operate the Facility.

 

In accordance with terms of the Agreement, as of March 31, 2008, the Company has made payments of $7,261,561 for development of project documentation, purchase of equipment, transportation and customs, and construction of a gas pipe-line.

 

 

 

NOTE 9 - LONG TERM VAT RECOVERABLE

 

As of March 31, 2008 and 2007 the Company had long term VAT recoverable in the amount of $8,106,397 and $4,351,059, respectively. The VAT recoverable is a Tenge denominated asset due from the Republic of Kazakhstan. The VAT recoverable consists of VAT paid on local expenditures and imported goods. VAT charged to the Company is recoverable in future periods as either cash refunds or offsets against the Company's fiscal obligations, including future income tax liabilities. Management can not estimate which part of this asset will be realized in the current year because in order to return funds or offset this tax with other taxes a tax examination must be performed by local Kazakhstan tax authorities. During the year ended March 31, 2008 the Company received refunds of VAT in the amount of $885,775.

 

NOTE 10 - RESTRICTED CASH

 

Under the laws of the Republic of Kazakhstan, the Company is obligated to set aside funds for required environmental remediation. As of March 31, 2008 and 2007 the Company had $622,697 and $303,697, respectively, restricted for this purpose.

 

NOTE 11 - CONVERTIBLE NOTES PAYABLE

 

On July 16, 2007 the Company completed the private placement of $60 million in principal amount of 5.0% convertible senior notes due 2012 (“Notes”) to non-U.S. persons outside of the United States in accordance with Regulation S under the U.S. Securities Act of 1933, as amended (the “Securities Act”) and in compliance with the laws and regulations applicable in each country where the placement took place.

 

The Notes carry a 5% coupon and have a yield to maturity of 6.25%. Interest will be paid at a rate of 5.0% per annum on the principal amount, payable semiannually in arrears on January 13 and July 13 of each year, beginning on January 13, 2008.

 

The Notes are convertible into the Company’s common shares. The initial conversion price was set at $7.2094 per share, subject to customary adjustments in certain circumstances, including but not limited to, changes of control and certain future equity financings. If the conversion price is adjusted pursuant to the conversion provisions, the conversion price shall not be adjusted below $6.95, provided that if the conversion price is adjusted due to (1) the payment of a dividend; (2) a bonus issue; (3) a consolidation or subdivision of the shares; (4) the issuance of shares, share-related securities, rights in respect of shares or rights in respect of share-related securities to all or substantially all of the shareholders as a

 

 

 

class; (5) the issuance of other securities to substantially all shareholders as a class; or (6) other arrangements to acquire securities, then the minimum conversion price will be adjusted at the same time by the same proportion.

 

A change of control event occurs if an offer in respect of the Company’s common shares, for which the consideration is or can be received wholly or substantially in cash, has become or been declared unconditional in all respects and the Company becomes aware that the right to cast more than 50% of the votes which may ordinarily be cast on a poll at a general meeting of the shareholders has or will become unconditionally vested in the offeror and/or any associate(s) of the offeror, or an event occurs which has a like or similar effect. If a change of control event occurs, the conversion price in respect of a conversion date that occurs after the date on which notice of such change in control event is given by the Company, but on or prior to the 60th day following the date of such notice, shall become the product of (1) the conversion price that would otherwise apply on such conversion date in the absence of a change of control event and (2) the percentage determined in accordance with the following:

 

If a holder of notes shall convert its notes following the date on which notice of a change in control event is given by us but on or prior to the 60th day following the date of such notice, then we shall pay to such holder the following U.S. Dollar amounts per U.S. Dollar of notes held by the holder that are to be so converted.

 

 

The Notes are callable after three years at a price equal to 104% of the principal amount thereof plus any accrued and unpaid interest to the date fixed for redemption, subject to the share price trading at least 30% above the conversion price. Holders of the Notes will have the right to require the Company to redeem all or a portion of their Notes on July 13, 2010 at a price equal to 104% of the principal amount thereof plus any accrued and unpaid interest to the date fixed for redemption. Unless previously redeemed, converted or purchased and cancelled, the Notes will be redeemed by the Company at a price equal to 107.2% of the principal

 

 

 

amount thereof on July 13, 2012. The Notes constitute direct, unsubordinated and unsecured, interest bearing obligations of the Company.

 

The net proceeds from the issuance of the Notes will be used for further exploration and development of the Company’s oil and gas drilling and production activities in western Kazakhstan.

 

The Company granted a registration right to the Noteholders. The Company agreed to file, pursue to effectiveness and maintain effective a registration statement in respect of the Notes and the underlying shares of common stock issuable upon the conversion of the Notes (collectively, the “Covered Securities”), until such time as all Covered Securities:

 

 

 

 

 

On October 19, 2007 the Company filed with the U.S. Securities and Exchange Commission (“SEC”) a registration statement on Form S-3, as amended on October 25, 2007 and January 23, 2008, (the “Shelf Registration Statement”) registering the Covered Securities for resale. The Shelf Registration Statement was declared effective by the SEC on January 25, 2008.

 

As of March 31, 2008 the Company has accrued interest of $641,667, relating to the convertible notes outstanding. The Company has also amortized the discount on the convertible notes (difference between the redemption amount and the carrying amount as of the date of issue) in the amount of $535,455 as of March 31, 2008. The carrying value of convertible notes will be accreted to the redemption value of $64,323,785.

 

 

 

As of March 31, 2008 and March 31, 2007 the convertible notes payable amount is presented as follows:

 

 

In accordance with SFAS No. 34, Capitalization of Interest and FIN 33, Applying FASB Statement No. 34 to Oil and Gas Producing Operations Accounted for by the Full Cost Method and Interpretation of FASB Statement No. 34, accrued interest expense in the amount of $2,141,667 and accretion expense relating to the discount on convertible notes (difference between the redemption amount and the carrying amount as of the date of issue) in the amount of $535,455, was capitalized to oil and gas properties for the year ended March 31, 2008.

 

 

 

NOTE 12 - LIQUIDATION FUND

 

A reconciliation on the Liquidation Fund (Asset Retirement Obligation) at March 31, 2008, 2007 and 2006 is as follows:

 

 

Management believes that the liquidation fund should be accrued for future abandonment costs of 18 wells located in the Dolinnoe, Aksaz, Emir and Kariman oil fields. Management believes that these obligations are likely to be settled at the end of the production phase at these oil fields.

 

At March 31, 2008, undiscounted expected future cash flows that will be required to satisfy the Company’s obligation by 2009 for the Dolinnoe, Aksaz and Emir fields, respectively, are $4,224,800. After application of a 10% discount rate, the present value of the Company’s liability at March 31, 2008 and 2007, was $3,728,531 and $2,165,829, respectively.

 

NOTE 13 - INCOME TAXES

 

The Company’s consolidated pre-tax income is comprised primarily from operations in the Republic of Kazakhstan. Pre-tax losses from United States operations of $1,827,168, $3,243,481 and $1,004,561, for the years ended March 31, 2008, 2007 and 2006, respectively, are also included in consolidated pre-tax income.

 

According to the Exploration Contract in the Republic of Kazakhstan, for income tax purposes the Company can capitalize the exploration and development costs and deduct all revenues received during the exploration stage to calculate taxable income. Therefore, the Exploration Contract allows the Company to be exempt from Kazakhstan corporate income tax for the period of exploration phase.

 

Undistributed earnings of the Company’s foreign subsidiaries since acquisition amounted to approximately $31 million at March 31, 2008. Those earnings are considered to be indefinitely reinvested and, accordingly, no U.S. federal and state income taxes have been provided thereon. Upon distribution of those earnings, in the form of dividends or otherwise, the Company would be subject to both U.S. income

 

 

 

taxes (subject to an adjustment for foreign tax credits) and withholding taxes payable to the Republic of Kazakhstan. Determination of the amount of unrecognized deferred U.S. income tax liability is not practical because of the complexities associated with its hypothetical calculation; however, unrecognized foreign tax credits may be available to reduce a portion of the U.S. tax liability.

 

The income tax provision/(benefit) in the Consolidated Statements of Operations is comprised of:

 

 

The following is a reconciliation of income taxes computed using the foreign Republic of Kazakhstan federal statutory rate and the domestic U.S. federal statutory rate to the provision/(benefit) for income taxes:

 

 

As of March 31, 2007, the Company had net operating loss carry forwards for income tax purposes of $8,019,640, which if unused, will expire in 2024, 2025, 2026 and 2027.

 

Deferred taxes reflect the estimated tax effect of temporary differences between assets and liabilities for financial reporting purposes and those measured by tax laws and regulations. The components of deferred tax assets and deferred tax liabilities are as follows:

 

 

 

 

Deferred income taxes for US and Kazakhstan tax jurisdiction are as follows:

 

 

 

NOTE 14 - SHARE AND ADDITIONAL PAID IN CAPITAL

 

Private placements

 

On July 2, 2004, the Company sold an aggregate of 4,584,340 common shares of the Company at $4.00 per share in a private place,ent offering. The Company received $17,311,906, net of the agent fees and out of pocket expenses.

 

On March 9, 2005, the Company sold an aggregate of 2,000,000 common shares of the Company at $5.00 per share in a private placement offering. The Company received $9,968,254, net of the agent fees and out of pocket expenses.

 

During the fiscal year ended March 31, 2006, the Company sold an aggregate of 1,101,000 common shares of the Company at $5.00 per share in a private placement offering. On April 12, 2005, the Company received $5,221,685, net of the agent fees and out of pocket expenses.

 

F-27

 

 

Also during the fiscal year ended March 31, 2006, the Company sold an aggregate of 9,166,667 common shares of the Company at $6.00 per share in a private placement offering. On December 29, 2005, the Company received $52,189,207, net of the agent fees and out of pocket expenses.

 

Common stock sold in private placements as of March 31, 2008 is as follows:

 

 

The offerings were made only to accredited investors in the United States of America under Regulation D and pursuant to Regulation S to non-U.S. Persons.

 

Share-Based Compensation

 

During the fiscal year ended March 31, 2005 the shareholders of the Company approved an incentive stock option plan (the “Plan”) under which directors, officers and key personnel may be granted options to purchase common shares of the Company, as well as other stock based awards. 5,000,000 common shares were reserved for issuance under the Plan. The Board determines the terms of options and other awards made under the Plan. Under the terms of the Plan, no incentive stock options shall be granted with an exercise price at a discount to the market.

 

Common Stock Grants

 

On July 18, 2005, the Company granted common shares to Company’s directors and officers for past services rendered. The number of shares granted was 360,270. The shares were valued at $4.75 per share. This stock grant vested immediately. Compensation expense in the amount of $1,711,283 was recognized in the Consolidated Statements of Operations and Consolidated Balance Sheet for the year ended March 31, 2006.

 

On July 18, 2005, the Company granted 90,000 restricted common shares to three Company employees. Each employee’s stock grants vest in three equal tranches of 10,000 shares on the first, second and third anniversaries of their employment with the Company. We record the fluctuations in the fair value of certain

 

 

 

unvested stock grants as a deferred compensation asset (reported as a reduction of shareholders’ equity on the balance sheet). This asset is amortized upon vesting of related stock grants as non-cash compensation expense. Compensation expense for vested stock grants in the amount of $31,523, $124,477 and $271,500 have been recognized in the Consolidated Statements of Operations and Consolidated Balance Sheets for the years ended March 31, 2008, 2007 and 2006, respectively.

 

As of March 31, 2008, there was no unrecognized compensation expense related to non-vested share-based compensation arrangements granted under the Plan.

 

On July 18, 2005, the Company also granted common shares to legal counsel, for the legal services rendered. The number of such stock grants has been set at 18,947 shares at the price of $4.75 per share. Stock grants vest immediately. Expense in the amount of $89,998 was recognized in the Consolidated Statements of Operations and Consolidated Balance Sheet.

 

On June 20, 2006, the Company granted common stock to officers and directors and certain employees and consultants of the Company under the Plan. The total number of restricted common shares granted was 495,000. The restricted stock grants were valued at $7.00 per share. All of the restricted stock grants vested immediately upon grant. Compensation expense in the amount of $3,465,000 was recognized in the Consolidated Statements of Operations and Consolidated Balance Sheet for the year ended March 31, 2007.

 

During the quarter ended September 30, 2005 the Company granted restricted common shares to the Company’s former co-chief executive officer and president for services rendered. He was granted 70,526 shares. The shares were valued at $5.02 per share. The stock grants vested immediately. Compensation expense in the amount of $354,041 was recognized in the Consolidated Statements of Operations and Consolidated Balance Sheet for the year ended March 31, 2006.

 

On February 1, 2006 the Company also granted common shares to the Company’s former chief finance officer for the services rendered. He was granted 50,000 shares. The shares were valued at $7.40 per share. The stock grants vested immediately. Compensation expense in the amount of $370,000 was recognized in the Consolidated Statement of Operations and Consolidated Balance Sheet for the year ended March 31, 2006.

 

On March 30, 2007, the Company granted common stock to officers, employees and outside consultants of the Company under the Plan. The total number of restricted common shares granted was 950,000. The restricted stock grants were valued at $5.38 per share. The restricted stock grants were awarded on the same terms and subject to same vesting requirements. The restricted stock grants will vest to the grantees at such time as either of the following events occurs (the "Vesting Events"): i) the Company enters commercial production and is granted a commercial production license from the Republic of Kazakhstan; or

 

 

 

ii) the occurrence of an Extraordinary Event. An “Extraordinary Event” is defined in the restricted stock agreement as any consolidation or merger of the Company or any of its subsidiaries with another person, or any acquisition of the Company or any of its subsidiaries by any person or group of persons, acting in concert, equal to thirty percent (30%) or more of the outstanding stock of the Company or any of its subsidiaries, or the sale of all or substantially all of the assets of the Company or any of its subsidiaries. In the event of an Extraordinary Event, the grants shall be deemed full vested one day prior to the effective date of the Extraordinary Event. The Board of Directors shall determine conclusively whether or not an Extraordinary Event has occurred and the grantees have agreed to be bound by the determination of the Board of Directors. The grantees have the right to vote the shares, receive dividends and enjoy all other rights of ownership over the entire grant amount from the grant date, except for the right to transfer, assign, pledge, encumber, dispose of or otherwise directly or indirectly profit or share in any profit derived from a transaction in the shares prior to the occurrence of a Vesting Event. Shares will only vest to the grantee if the grantee is employed by the Company at the time a Vesting Event occurs. If a Vesting Event has not occurred at the time a grantee's employment with the Company ceases, for any reason, the entire grant amount shall be forfeited back to the Company. Compensation expense in the amount of $2,271,556 was recognized in the Consolidated Statement of Operations and Consolidated Balance Sheet for the year ended March 31, 2008.

 

As of March 31, 2008, there was $2,839,444 of total unrecognized compensation expense related to non-vested share-based compensation arrangements granted under the Plan. That cost is expected to be recognized over a weighted-average period of 1.25 years.

 

Stock Options

 

On June 20, 2006 the Company granted stock options to directors of the Company under the Plan. The total number of options was 200,000. The options are exercisable at a price of $7.00 per share. The options will expire three years from the grant date. All of the options vested immediately upon grant. Compensation expense for options granted is determined based on their fair values at the time of grant, the cost of which in the amount of $545,346 was recognized in the Consolidated Statements of Operations and Consolidated Balance Sheet for the year ended March 31, 2007.

 

On November 12, 2004, the Company granted stock options to its former corporate secretary for past services rendered. These options grant the employee the right to purchase up to 60,000 shares of the Company’s common stock at an exercise price of $4.00 per share. The options vested immediately and expire five years from the date of grant. In April 2006, options to acquire 7,200 common shares were exercised. In January 2008, options to acquire 3,000 common shares were exercised.

 

 

 

On February 1, 2006 the Company granted stock options to former chief finance officer for the past services rendered. These options grant former chief finance officer the right to purchase up to 100,000 shares of the Company’s common stock at an exercise price of $7.40 per share. The options expire five years from the date of grant. Granted options vest immediately. Expense for options granted is determined based on fair value of stocks at the time of grant, the cost of which, $391,795, is recognized in the Consolidated Statements of Operations for the year ended March 31, 2006..

 

On July 18, 2005, the Company granted stock options to Company’s directors and officers for the past services rendered. These options grant the directors and officers the right to purchase up to 779,730 shares of the Company’s common stock at an exercise price of $4.75 per share. The options expire five years from the date of grant. Granted options vest immediately. Compensation expense for options granted is determined based on their fair value at the time of grant, the cost of which in the amount of $1,569,223 was recognized in the Consolidated Statements of Operations for the year ended March 31, 2006.

 

On July 18, 2005, the Company granted options to legal counsel, for the legal services rendered. These options grant legal counsel the right to purchase up to 41,053 shares of the Company’s common stock at an exercise price of $4.75 per share. The options expire five years from the date of grant. Granted options vest immediately. Expense for options granted is determined based on fair value of stocks at the time of grant, the cost of which, $82,684, is recognized in the Consolidated Statements of Operations for the year ended March 31, 2006.

 

During the quarter ended June 30, 2005 the Company recognized additional compensation expense in the amount of $133,112 in the Consolidated Statement of Income and Consolidated Balance Sheet for the year ended March 31, 2006 for the options granted to its former corporate secretary for the past services rendered. These options grant the employee the right to purchase up to 60,000 shares of the Company’s common stock at an exercise price of $4.00 per share. The options expire in five years from the date of grant. Granted options vest immediately.

 

 

 

Warrants

 

On November 26, 2003, the Company granted warrants to placement agents in connection with funds raised on the Company’s behalf. These warrants granted the placement agents the right to purchase up to 142,857 shares of the Company’s common stock at an exercise price of $3.50 per share. These warrants have been offset to the proceeds as a cost of capital. On March 6, 2008, 90,477 of these warrants were exercised.

 

 

 

 

 

NOTE 15 - REVENUES

 

 

The Company exports oil for sale to the world markets via the Aktau sea port. Sales prices at the port locations are based on the average quoted Brent crude oil price from Platt's Crude Oil Marketwire for the three days following the bill of lading date less discount for transportation expenses, freight charges and other expenses borne by the customer.

 

 

 

 

NOTE 16 - EARNINGS PER SHARE INFORMATION

 

The calculation of the basic and diluted earnings/loss per share is based on the following data:

 

 

NOTE 17 - RELATED PARTY TRANSACTIONS

 

The Company leases ground fuel tanks and other oil fuel storage facilities and warehouses from Term Oil LLC. The lease expenses for the years ended March 31, 2008, 2007 and 2006, totaled $254,427, $203,686 and $276,055, respectively. Also the Company had accounts payable to Term Oil LLC in the amount of $53,624 and $29,885 as of March 31, 2008 and 2007, respectively. A Company shareholder is an owner of Term Oil LLC.

 

The future minimum rental payments required under this operating lease are as follows:

 

 

 

 

NOTE 18 - COMMITMENTS AND CONTINGENCIES

 

Historical investments by the Government of the Republic of Kazakhstan

 

The Government of the Republic of Kazakhstan made historical investments in the ADE Block in total amount of $5,994,200 in relation to ADE Block and $5,350,680 in relation to the Extended Territory. When the Company applies for and is granted commercial production rights for the ADE Block and Extended Territory, the Company will be required to begin repaying these historical investments to the Government of the Republic of Kazakhstan. The terms of repayment will be negotiated at the time the Company applies for commercial production rights.

 

Capital Commitments

 

Under the terms of its subsurface exploration contract, Emir Oil LLP is required to spend a total of $48.7 million in exploration and development activities on the ADE Block and the Extended Territory. To retain its rights under the contract, the Company must spend a minimum of $12.7 million in 2007, $8.5 million in 2008 and $70 thousand in 2009. The Company must also comply with the terms of the work program associated with` the contract, which includes the drilling of at least six additional new wells by July 9, 2009. The Company received approval to extend the subsurface exploration contract to July 2009. The failure to meet the minimum capital expenditures or to comply with the terms of the work program could result in the loss of the subsurface exploration contract.

 

Litigation

 

In December 2003, a complaint was filed in the 15th Judicial Court in and for Palm Beach County, Florida, naming, among others, the Company and former directors, Georges Benarroch and Alexandre Agaian, as defendants. The plaintiffs, Brian Savage, Thomas Sinclair and Sokol Holdings, Inc. allege claims of breach of contract, unjust enrichment, breach of fiduciary duty, conversion and violation of a Florida trade secret statute in connection with a business plan for the development of the Aksaz, Dolinnoe and Emir oil and gas fields owned by Emir Oil, LLP. The parties mutually agreed to dismiss this lawsuit without prejudice.

 

In April 2005, Sokol Holdings, Inc., also filed a complaint in United States District Court, Southern District of New York alleging that BMB Munai, Inc., Boris Cherdabayev, and former BMB directors Alexandre Agaian, Bakhytbek Baiseitov, Mirgali Kunayev and Georges Benarroch wrongfully induced Toleush Tolmakov to breach a contract under which Mr. Tolmakov had agreed to sell to Sokol 70% of his 90% interest in Emir Oil LLP.

 

 

 

In October and November 2005, Sokol Holdings filed amendments to its complaint in the U.S. District Court in New York to add Brian Savage and Thomas Sinclair as plaintiffs and to add Credifinance Capital, Inc., and Credifinance Securities, Ltd., (collectively “Credifinance”) as defendants in the matter. The amended complaints alleged: i) tortious interference with contract, specific performance, breach of contract, unjust enrichment, unfair competition-misappropriation of labors and expenditures against all defendants; ii) breach of fiduciary duty, tortious interference with fiduciary duty and aiding and abetting breach of fiduciary duty by Mr. Agaian, Mr. Benarroch and Credifinance; and iii) breach of fiduciary duty by Mr. Cherdabayev, Mr. Kunayev and Mr. Baiseitov, in connection with a business plan for the development of the Aksaz, Dolinnoe and Emir oil and gas fields owned by Emir Oil, LLP. The plaintiffs have not named Toleush Tolmakov as a defendant in the action nor have the plaintiffs ever brought claims against Mr. Tolmakov to establish the existence or breach of any legally binding agreement between the plaintiffs and Mr. Tolmakov. The plaintiffs seek damages in an amount to be determined at trial, punitive damages, specific performance and such other relief as the Court finds just and reasonable.

 

The Company has retained the law firm of Bracewell & Giuliani LLP in New York, New York to represent us in the lawsuit. The Company moved for dismissal of the amended complaint or for a stay pending arbitration in Kazakhstan. That motion was denied, without prejudice to renewing it, to enable defendants to produce documents to plaintiffs relating to the issues raised in the motion. Following completion of document production, the motion was renewed. Briefing on the motion was completed on August 24, 2006. On June 14, 2007, the court ruled on our motion. The court (a) denied the motion to dismiss on the ground that Kazakhstan is a more convenient forum; (b) denied the motion to dismiss in favor of litigation in New York state court; (c) denied the motion to stay pending arbitration in Kazakhstan; and (d) denied the motion to dismiss on the ground that Mr. Tolmakov is an indispensable party. The court also (a) denied the motion (by defendants other than the Company) to dismiss for lack of personal jurisdiction and (b) granted the motion (by defendants other than the Company) to dismiss several claims for relief alleging breach of fiduciary duty, tortious interference with fiduciary duty and aiding and abetting breach of fiduciary duty. The court dismissed as moot the Company’s cross-motion to stay discovery and instructed the parties to comply with the Magistrate Judge’s discovery schedule.

 

The Company has appealed the court’s refusal to stay the litigation pending arbitration in Kazakhstan. The Company moved for an order to stay all proceedings in the lower court while the aforementioned appeal is pending. This motion was denied by the lower court and we have made a similar motion before the Court of Appeals. Oral argument on the appeal was held on October 26, 2007. The Court of Appeals has not yet rendered a decision on the appeal or the ancillary motion to stay all proceedings pending a decision on the appeal. Therefore, discovery in the case is ongoing.

 

 

 

NOTE 19 - FINANCIAL INSTRUMENTS

 

As of March 31, 2008 and 2007 cash and cash equivalents included deposits in Kazakhstan banks in the amount $2,211,353 and $4,181,698, respectively and deposits in U.S. banks in the amount of $15,027,484 and $7,991,242, respectively. Kazakhstan banks are not covered by FDIC insurance, nor does the Republic of Kazakhstan have an insurance program similar to FDIC. Therefore, the full amount of our deposits in Kazakhstan banks was uninsured as of March 31, 2008 and 2007. Our deposits in the U.S. banks are also in non-FDIC insured accounts which means they too are not insured to the $100,000 FDIC insurance limit. To mitigate this risk, we have placed all of our U.S. deposits in a money market account that invests in U.S. government backed securities. As of March 31, 2008 and 2007 the Company made advance payments to Kazakhstan companies and government bodies in the amount $21,266,329 and $7,115,297, respectively. As of March 31, 2008 and 2007 restricted cash reflected in the long-term assets consisted of $622,697 and $303,697, respectively, deposited in a Kazakhstan bank and restricted to meet possible environmental obligations according to the regulations of Kazakhstan. Furthermore, the primary asset of the Company is Emir Oil LLP; an entity formed under the laws of the Republic Kazakhstan.

 

NOTE 20 - QUARTERLY FINANCIAL DATA (unaudited)

 

Quarterly financial information is presented in the following summary:

 

 

 

 

 

 

 

 

 

NOTE 21 - SIGNIFICANT FOURTH QUARTER ADJUSTMENTS

 

During the quarters ended June 30, 2007, September 30, 2007 and December 31, 2007, the Company recognized income tax expense totaling $7,421,832, which was estimated based on an effective tax rate of 32.6%. The final income tax provision calculation at March 31, 2008, considering the Company’s benefit from exploration phase, resulted in the reverse entry recorded by the Company in the amount of $7,825,413, which lead to the annual income tax benefit in the amount of $403,581.

 

 

This footnote provides unaudited information required by SFAS No. 69, “Disclosures about Oil and Natural Gas Producing Activities.” The Company’s oil and natural gas properties are located in the Republic of Kazakhstan, which constitutes one cost center.

 

Capitalized Costs - Capitalized costs and accumulated depletion, depreciation and amortization relating to our oil and natural gas producing activities, all of which are conducted in the Republic of Kazakhstan, are summarized below:

 

 

Costs Incurred - Costs incurred in oil and natural gas property acquisition, exploration and development activities are summarized below:

 

 

 

Results of Operations – Results of operations for the Company’s oil and natural gas producing activities are summarized below:

 

 

Reserves – Proved reserves are estimated quantities of oil and natural gas, which geological and engineering data demonstrate with reasonable certainty to be, recoverable in future years from known reservoirs under existing economic and operating conditions. Proved developed reserves are proved reserves that can reasonably be expected to be recovered through existing wells with existing equipment and operating methods. Proved oil and natural gas reserve quantities and the related discounted future net cash flows before income taxes (see Standardized Measure) for the periods presented are based on estimates prepared by Chapman Petroleum Engineering Ltd., independent petroleum engineers. Such estimates have been prepared in accordance with guidelines established by the SEC.

 

 

The Company’s net ownership in estimated quantities of proved oil reserves, and changes in net proved reserves, all of which are located in the Republic of Kazakhstan, are summarized below:

 

 

 

 

Standardized Measure – The Standardized Measure of Discounted Future Net Cash Flows relating to the Company’s ownership interests in proved oil reserves for the year ended March 31, 2008, 2007 and 2006 is shown below:

 

 

Our standardized measure of discounted future net cash flows relating to proved oil reserves was prepared in accordance with the provisions of SFAS 69. Future cash inflows are computed by applying year end prices of oil and natural gas to year end quantities of proved oil and natural gas reserves. Future oil and natural gas production and development costs are computed by estimating the expenditures to be incurred in producing and developing the proved oil and natural gas reserves at year end, based on year end costs and assuming continuation of existing economic condition.

 

Future income tax expenses are calculated by applying appropriate year end tax rates to future pre-tax net cash flows relating to proved oil and natural gas reserves, less the tax basis of properties involved. Future income tax expenses give effect to permanent differences, tax credits and loss carryforwards relating to the proved oil and natural gas reserves. Future net cash flows are discounted at a rate of 10% annually to derive the standardized measure of discounted future net cash flows. The Standardized Measure of Discounted Future Net Cash Flows is not intended to represent the replacement cost or fair market value of the Company’s oil and natural gas properties.

 

Changes in Standardized Measure – Changes in Standardized Measure of Discounted Future Net Cash Flows relating to proved oil reserves are summarized below:

 

 

 

 

Sales of oil and natural gas, net of oil and natural gas operating expenses are based on historical pre-tax results. Sales of oil and natural gas properties, extensions and discoveries, purchases of minerals in place and the changes due to revisions in standardized variables are reported on a pre-tax discounted basis, while the accretion of discount is presented on an after tax basis.