Freedom Holding Corp. - Quarter Report: 2010 June (Form 10-Q)

BMB MUNAI, INC.

August 13, 2010

/s/ Gamal Kulumbetov

Gamal Kulumbetov

Chief Executive Officer

q063010.htm

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, DC 20549

FORM 10-Q

	x	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
		For the Quarterly Period Ended June 30, 2010


	o	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
		For the Transition Period From ________ to _________

Commission File Number 001-33034

BMB MUNAI, INC.
(Exact name of registrant as specified in its charter)

Nevada			30-0233726
(State or other jurisdiction of			(I.R.S. Employer
incorporation or organization)			Identification No.)

202 Dostyk Ave, 4th Floor
Almaty, Kazakhstan			050051
(Address of principal executive offices)			(Zip Code)

+7 (727) 237-51-25
(Registrant's telephone number, including area code)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes x No o

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

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

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

As of August 13, 2010, the registrant had 51,840,015 shares of common stock, par value $0.001, issued and outstanding.

BMB MUNAI, INC.

FORM 10-Q

TABLE OF CONTENTS

		Page
PART I — FINANCIAL INFORMATION

Item 1. Unaudited Consolidated Financial Statements

	Consolidated Balance Sheets as of June 30, 2010 and March 31, 2010	3

	Consolidated Statements of Operations for the Three Months Ended June 30, 2010 and 2009	4

	Consolidated Statements of Cash Flows for the Three Months Ended June 30, 2010 and 2009	5

	Notes to Consolidated Financial Statements	7

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations		40

Item 3. Qualitative and Quantitative Disclosures About Market Risk		50

Item 4. Controls and Procedures		51

PART II — OTHER INFORMATION

Item 1. Legal Proceedings		52

Item 1A. Risk Factors		52

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds		52

Item 6. Exhibits		54

Signatures		54

PART I - FINANCIAL INFORMATION

Item 1 - Unaudited Consolidated Financial Statements

BMB MUNAI, INC.

CONSOLIDATED BALANCE SHEETS (UNAUDITED)

	Notes		June 30, 2010 (unaudited)		March 31, 2010
ASSETS
CURRENT ASSETS
Cash and cash equivalents	3	$	10,214,824	$	6,440,394
Trade accounts receivable			4,531,629		6,423,402
Prepaid expenses and other assets, net	4		4,108,360		4,083,917

Total current assets			18,854,813		16,947,713

LONG TERM ASSETS
Oil and gas properties, full cost method, net	5		241,736,128		238,601,842
Gas utilization facility, net	6		13,343,576		13,569,738
Inventories for oil and gas projects	7		13,845,948		13,717,847
Prepayments for materials used in oil and gas projects			98,813		141,312
Other fixed assets, net			3,667,666		3,815,422
Long term VAT recoverable	8		3,460,543		3,113,939
Convertible notes issue cost			1,070,467		1,201,652
Restricted cash	9		768,724		770,553

Total long term assets			277,991,865		274,932,305

TOTAL ASSETS		$	296,846,678	$	$ 291,880,018

LIABILITIES AND SHAREHOLDERS’ EQUITY

CURRENT LIABILITIES
Accounts payable		$	6,945,846	$	3,948,851
Accrued coupon payment	10		1,391,667		641,667
Taxes payable, accrued liabilities and other payables			4,455,616		4,802,361

Total current liabilities			12,793,129		9,392,879

LONG TERM LIABILITIES
Convertible notes issued, net	10		62,399,684		62,178,119
Liquidation fund	11		4,831,533		4,712,345
Deferred taxes	16		4,964,382		4,964,382
Capital lease liability	12		310,315		369,801

Total long term liabilities			72,505,914		72,224,647

COMMITMENTS AND CONTINGENCIES	19		-		-

SHAREHOLDERS’ EQUITY
Preferred stock - $0.001 par value; 20,000,000 shares authorized; no shares
issued or outstanding	13		-		-
Common stock - $0.001 par value; 500,000,000 shares authorized, 51,840,015 and
51,865,015 shares outstanding, respectively	13		51,840		51,865
Additional paid in capital	13		161,067,269		160,653,969
Retained earnings			50,428,526		49,556,658

Total shareholders’ equity			211,547,635		210,262,492

TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY		$	296,846,678	$	291,880,018

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

BMB MUNAI, INC.

CONSOLIDATED STATEMENTS OF OPERATIONS (UNAUDITED)

			Three months ended June 30,
	Notes		2010 (unaudited)		2009 (unaudited)

REVENUES	14	$	12,787,846	$	11,766,806

COSTS AND OPERATING EXPENSES
Rent export tax			2,721,749		1,533,437
Oil and gas operating			2,341,837		1,559,000
General and administrative			3,165,111		4,851,766
Depletion			2,343,338		2,243,304
Interest expense			1,102,750		1,148,047
Amortization and depreciation			150,559		130,973
Accretion expense			119,188		107,847
Total costs and operating expenses			11,944,532		11,574,374

INCOME FROM OPERATIONS			843,314		192,432

OTHER INCOME / (EXPENSE)
Foreign exchange loss, net			(96,404)		(82,321)
Interest income			101,464		33,160
Other income/(expense), net			23,494		(112,489)
Total other income/(expense)			28,554		(161,650)

INCOME BEFORE INCOME TAXES			871,868		30,782

INCOME TAX EXPENSE	16		-		-

NET INCOME		$	871,868	$	30,782

BASIC NET INCOME PER COMMON SHARE	17	$	0.02	$	0.00
DILUTED NET INCOME PER COMMON SHARE	17	$	0.02	$	0.00

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

BMB MUNAI, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)

			Three months ended June 30,
	Notes		2010 (unaudited)		2009 (unaudited)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income		$	871,868	$	30,782
Adjustments to reconcile net income to net cash provided by operating activities:
Depletion	5		2,343,338		2,243,304
Depreciation and amortization			376,721		130,973
Interest expense			1,122,594		1,148,047
Accretion expense	11		119,188		107,847
Stock based compensation expense	13		413,275		2,401,576
Stock issued for services			-		31,832
Loss on disposal of fixed assets			7,180		- -
Changes in operating assets and liabilities:
Decrease/(increase) in trade accounts receivable			1,891,773		(2,971,473)
(Increase)/decrease in prepaid expenses and other assets			(66,859)		2,056,186
Increase in VAT recoverable			(346,604)		(785,829)
Increase in current liabilities			2,650,250		1,214,924

Net cash provided by operating activities			9,382,724		5,608,169

CASH FLOWS FROM INVESTING ACTIVITIES:
Purchase and development of oil and gas properties	5		(4,736,469)		(5,813,067)
Purchase of other fixed assets			(118,593)		(117,180)
Increase in inventories and prepayments for materials used in oil and gas projects			(718,147)		- -
Increase/(decrease) in restricted cash			1,829		(3,872)

Net cash used in investing activities			(5,571,380)		(5,934,119)

CASH FLOWS FROM FINANCING ACTIVITIES:
Payment of capital lease obligation			(39,614)		-

Net cash used in financing activities			(39,614)		-

NET CHANGE IN CASH AND CASH EQUIVALENTS			3,774,430		(325,950)
CASH AND CASH EQUIVALENTS at beginning of period			6,440,394		6,755,545
CASH AND CASH EQUIVALENTS at end of period		$	10,214,824	$	6,429,595

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

BMB MUNAI, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)

(CONTINUED)

			Three months ended June 30,
	Notes		2010 (unaudited)		2009 (unaudited)

Non-Cash Investing and Financing Activities
Transfer of inventory and prepayments for materials used in oil and gas projects to oil and gas properties	5	$	632,545	$	240,385
Depreciation on other fixed assets capitalized as oil and gas properties			108,610		-
Transfers from oil and gas properties, construction in progress and other fixed assets to gas utilization facility			-		99,107
Issuance of common stock for the settlement of liabilities	18	$	-	$	5,973,185

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

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

JUNE 30, 2010

NOTE 1 - DESCRIPTION OF BUSINESS

The corporation known as BMB Munai, Inc. (“BMB Munai” or the “Company”), a Nevada corporation, 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. BMB Munai changed its domicile from Delaware to Nevada on December 21, 2004.

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.

Currently the Company has completed twenty-four wells. As discussed in more detail in Note 2, the Company engages in exploration of its licensed territory pursuant to an exploration license and has not yet applied for or been granted a commercial production license.

NOTE 2 - SIGNIFICANT ACCOUNTING POLICIES

Business condition

As further discussed in detail in Note 10, in July 2007 the Company issued 5.0% Convertible Senior Notes due 2012 in the amount of $60,000,000. Among other terms of the Notes, the Noteholders had the right to require the Company redeem all or a portion of the notes on three separate dates, including July 13, 2010. The first two dates passed without the redemption right being exercised. The Company and the Noteholders are in the process of negotiating a restructuring of the Notes and on June 7, 2010 entered into Supplemental Indenture No. 1 dated June 1, 2010 that granted a fourth put date that commenced June 13, 2010 and expires September 13, 2010. The intent of the fourth put date is to allow time to work out a debt restructuring agreeable to all parties.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

JUNE 30, 2010

If the Company and Noteholders are not able to agree on a debt restructuring, and the Noteholders exercise their redemption right, the Company will need to pursue other financing options and there is no guarantee that they can be obtained.

Prior to entering into the Supplemental Indenture, the Company was in default under certain covenants contained in Article 9 of the Indenture requiring the Company to maintain a minimum net debt to equity ratio and to comply with certain notice, delivery and other provisions. In the context of the Indenture, the equity portion of the ratio is determined by reference to the market value of the Company’s common stock, not the Company’s book value. The market value of the Company’s stock has declined since the Notes were issued. The Noteholders have separately agreed to contingently waive these defaults until the earlier of: (i) September 1, 2010 or (ii) the fourth put date (as contained in the Supplemental Indenture), with the understanding that such waiver shall not constitute a waiver of any default under the Indenture that remains ongoing as of September 1, 2010 or occurs after June 8, 2010. The Company currently believes it will not be able to remedy the net debt to equity ratio covenant by September 1, 2010 and, therefore, anticipates it will be in default under the Indenture at that time unless a future waiver is obtained from the Noteholders. There is no assurance the Noteholders will provide any future waiver or any further extension of their redemption put rights under the Indenture.

Basis of consolidation

The Company’s unaudited 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 Unaudited Consolidated Financial Statements.

Reclassifications

Certain reclassifications have been made in the financial statements for the three months ended June 30, 2009 to conform to the June 30, 2010 presentation. The reclassifications had no effect on net income.

Use of estimates

The preparation of Unaudited 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 Unaudited 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 Unaudited Consolidated Financial Statements.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2010

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 are 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”) 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 (the “MEMR”) granted a second extension of the 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 “Southeast Block.” The Southeast Block includes the Kariman field and the Yessen and Borly structures and is governed by the terms of the Company’s original contract. On June 24, 2008, the MEMR agreed to extend the exploration stage of the Company’s contract from July 2009 to January 2013 in order to permit the Company to conduct additional exploration drilling and testing activities within the ADE Block and the Southeast Block.

On October 15, 2008, the MEMR approved Addendum # 6 to Contract No. 482 with Emir Oil LLP, dated June 09, 2000 extending Emir Oil LLP’s exploration territory from 460 square kilometers to a total of 850 square kilometers (approximately 210,114 acres). The additional territory is located to the north and west of the Company’s current exploration territory, extending the exploration territory toward the Caspian Sea and is referred to herein as the “Northwest Block.”

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

JUNE 30, 2010

To move from the exploration 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. The Government is obligated to conduct these negotiations under the Law of Petroleum in Kazakhstan. If the Company does not move from the exploration 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 three months ended June 30, 2010 and 2009, sales to one customer represented 98% and 100% of total sales, respectively. At June 30, 2010 and 2009, this customer made up 95% and 100% of accounts receivable, respectively. While the loss of this foregoing customer could have a material adverse effect on the Company in the short-term, the loss of this customer should not materially adversely affect the Company in the long-term because of the available market for the Company’s crude oil and natural gas production from other purchasers.

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 FASC Topic 718 – Stock Compensation. 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.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

JUNE 30, 2010

The Company has a stock option plan as described in Note 13. 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 three months ended June 30, 2010 and 2009 was $413,275 and $2,401,576, 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 are 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 transfers. Produced but unsold products are recorded as inventory until sold.

Export duty

In December 2008 the Government of the Republic of Kazakhstan issued a resolution that cancelled the export duty effective January 26, 2009 for companies operating under the new tax code.

In July 2010 the Government of the Republic of Kazakhstan issued a resolution which reenacted export duty for several products (including crude oil). The Company will become subject to the export duty beginning in August 2010. The export duty will be calculated based on a fixed rate of $2.60 per barrel exported. The export duty fees will be expensed as incurred and will be classified as costs and operating expenses.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

JUNE 30, 2010

Mineral extraction tax

The mineral extraction tax replaced the royalty expense the Company had paid. The rate of this tax depends on annual production output. The new code currently provides for a 5% mineral extraction tax rate (6% starting from 2013 and 7% starting from 2014) on production sold to the export market, and a 2.5% tax rate (3% in 2013 and 3.5% starting from 2014) on production sold to the domestic market. The mineral extraction tax expense is reported as part of oil and gas operating expense.

Rent export tax

This tax is calculated based on the export sales price and ranges from as low as 0%, if the price is less than $40 per barrel, to as high as 32%, if the price per barrel exceeds $190. Rent export tax is expensed as incurred and is classified as costs and operating expenses.

Income taxes

Provisions for income taxes are based on taxes payable or refundable for the current year and deferred taxes. Deferred taxes are provided on differences between the tax bases of assets and liabilities and their reported amounts in the financial statements, and tax carryforwards. Deferred tax assets and liabilities are included in the financial statements at currently enacted income tax rates applicable to the period in which the deferred tax assets and liabilities are expected to be realized or settled. As changes in tax laws or rates are enacted, deferred tax assets and liabilities are adjusted through the provision for income taxes.

Fair value of financial instruments

The carrying values reported for cash equivalents, accounts receivable, accounts payable and accrued liabilities approximate their respective fair values in the accompanying balance sheet due to the short-term maturity of these financial instruments. In addition, the Company has long-term debt with financial institutions. The carrying amount of the long-term debt approximates fair value based on current rates for instruments with similar characteristics.

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.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

JUNE 30, 2010

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 June 30, 2010 and no provision for obsolete inventory has been provided.

Oil and gas properties

The Company uses the full cost method of accounting for oil and gas properties. Under this method, all costs associated with acquisition, exploration, and development of oil and gas properties are capitalized. Costs capitalized include acquisition costs, geological and geophysical expenditures, and costs of drilling and equipping productive and non-productive wells. Drilling costs include directly related overhead costs. These costs do not include any costs related to production, general corporate overhead or similar activities. Under this method of accounting, the cost of both successful and unsuccessful exploration and development activities are capitalized as property and equipment. Proceeds from the sale or disposition of oil and gas properties are accounted for as a reduction to capitalized costs unless a significant portion of the Company’s proved reserve are sold (greater than 25 percent), in which case a gain or loss is recognized.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

JUNE 30, 2010

Capitalized costs less accumulated depletion and related deferred income taxes shall not exceed an amount (the full cost ceiling) equal to the sum of:

a) the present value of estimated future net revenues computed by applying current prices of oil and gas reserves to estimated future production of proved oil and gas reserves, less estimated future expenditures (based on current costs) to be incurred in developing and producing the proved reserves computed using a discount factor of ten percent and assuming continuation of existing economic conditions;

b) plus the cost of properties not being amortized;

c) plus the lower of cost or estimated fair value of unproven properties included in the costs being amortized;

d) less income tax effects related to differences between the book and tax basis of the properties.

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.

All capitalized costs of oil and gas properties, including the estimated future costs to develop proved reserves and estimated future costs to plug and abandon wells and costs of site restoration, less the estimated salvage value of equipment associated with the oil and gas properties, are amortized on the unit-of-production method using estimates of proved reserves as determined by independent engineers.

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.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2010

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:

Buildings and improvements	7-10 years
Machinery and equipment	6-10 years
Vehicles	3-5 years
Office equipment	3-5 years
Software	3-4 years
Furniture and fixtures	2-7 years

Maintenance and repairs are charged to expense as incurred. Renewals and betterments are capitalized as leasehold improvements, which are amortized on a straight-line basis over the shorter of their estimated useful lives or the term of the lease.

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. Based on the Company’s analysis at June 30, 2010, no impairment of other assets is necessary.

Gas Utilization Facility

The gas utilization facility (the “GUF”) is valued at historical cost less accumulated depreciation. Historical cost includes all direct costs associated with the acquisition and construction of the GUF.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

JUNE 30, 2010

Depreciation of the GUF is calculated using the straight-line method based upon an estimated useful life of 10 years and is charged to operating expenses. Maintenance and repairs are charged to expense as incurred. Renewals and betterments are capitalized as part of the GUF and depreciated over the useful life of the GUF.

The GUF will be evaluated annually for impairment. If the sum of expected undiscounted cash flows is less than net book value, unamortized costs of the GUF will be reduced to fair value. At June 30, 2010, no impairment of the GUF was considered necessary.

Convertible notes payable issue costs

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 classifies cash payments for bond issue costs as a financing activity. The Company capitalized cash payments for bond issue costs as part of oil and gas properties in periods of drilling activities.

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 U.S. Dollar is therefore its functional currency.

Income per common share

Basic income per common share is computed by dividing net income by the weighted-average number of common shares outstanding during the period. Diluted income per share reflects the potential dilution that could occur if all contracts to issue common stock were converted into common stock, except for those that are anti-dilutive.

New accounting policies

In January 2010, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update 2010-03 (“ASU 2010-03”) to align the oil and natural gas reserve estimation and disclosure requirements of ASC Topic 932, Extractive Industries — Oil and Gas, with the requirements in the Securities and Exchange Commission’s final rule, Modernization of the Oil and Gas Reporting Requirements, which was issued on December 31, 2008 and was effective for the year ended March 31, 2010. Modernization of the Oil and Gas Reporting Requirements was designed to modernize and update the oil and gas disclosure requirements to align with current practices and changes in technology. The Company implemented ASU 2010-03 prospectively as a change in accounting principle inseparable from a change in accounting estimate at March 31, 2010.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

JUNE 30, 2010

In January 2010, the FASB issued Accounting Standards Update 2010-06, “Fair Value Measurements and Disclosures: Improving Disclosures about Fair Value Measurements” (“ASU 2010-06”). ASU 2010-06 requires additional disclosures and clarifies existing disclosure requirements about fair value measurement as set forth in ASC Topic 820, Fair Value Measurements and Disclosures. The Company implemented the new disclosures and clarifications of existing disclosure requirements under ASU 2010-06 effective with the first quarter of 2011, except for certain disclosure requirements regarding activity in Level 3 fair value measurements which are effective for fiscal years beginning after December 15, 2010. The implementation of ASU 2010-06 had no impact on the Company’s financial position or results of operations.

NOTE 3 - CASH AND CASH EQUIVALENTS

As of June 30, 2010 and March 31, 2010, cash and cash equivalents included:

		June 30, 2010		March 31, 2010

US Dollars	$	9,524,459	$	5,264,496
Foreign currency		690,365		1,175,898
	$	10,214,824	$	6,440,394

As of June 30, 2010 and March 31, 2010, cash and cash equivalents included $1,321,807 and $1,321,774 placed in money market funds having 30 day simple yields of 0.01%.

NOTE 4 - PREPAID EXPENSES AND OTHER ASSETS

Prepaid expenses and other assets as of June 30, 2010 and March 31, 2010, were as follows:

		June 30, 2010		March 31, 2010

Advances for services	$	2,442,874	$	2,593,527
Taxes prepaid		1,002,719		920,066
Other		662,767		570,324
	$	4,108,360	$	4,083,917

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

JUNE 30, 2010

NOTE 5 - OIL AND GAS PROPERTIES

Oil and gas properties using the full cost method as of June 30, 2010 and March 31, 2010, were as follows:

		June 30, 2010		March 31, 2010

Cost of drilling wells	$	98,303,335	$	96,562,442
Professional services received in exploration and development activities		64,796,523		62,967,506
Material and fuel used in exploration and development activities		53,391,462		52,221,735
Subsoil use rights		20,788,119		20,788,119
Geological and geophysical		8,011,186		7,883,856
Deferred tax		7,219,219		7,219,219
Capitalized interest, accreted discount and amortised bond issue costs on convertible notes issued		6,633,181		6,633,181
Infrastructure development costs		1,455,422		1,429,526
Other capitalized costs		17,783,067		17,198,306
Accumulated depletion		(36,645,386)		(34,302,048)
	$	241,736,128	$	238,601,842

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

NOTE 6 – GAS UTILIZATION FACILITY

The Company has entered into an Agreement on Joint Business (the “Agreement”) with Ecotechnic Chemicals AG incorporated in Switzerland, for construction of the GUF to utilize the associated gas from the Company’s fields.

The GUF was completed on January 1, 2009. All costs associated with the completion of the GUF, which includes amounts previously classified as construction in progress, have been reported as the Gas Utilization Facility on the balance sheet.

During the year ended March 31, 2010, the Company made payment to Ecotechnic Chemicals AG in the amount of $75,000 and contributed property totalling $24,107 to the completion of the Facility.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

JUNE 30, 2010

Beginning on May 1, 2010, the Company entered into an agreement with LLP Aktau Gas Processing Factory to sell gas. Gas sales are currently realized at price $40 per thousand of cubic meters or $6.79 per BOE. As per agreement the Company is obliged to pay $33,000 per month for technical support and maintenance of the GUF. This agreement to sell gas is valid through December 31, 2010.

Based on the selling agreement mentioned above, the Company officially placed the GUF into service on May 1, 2010 and will depreciate the GUF over an estimated useful life of 10 years. During the three months ended June 30, 2010, depreciation expense for the GUF of $226,162 was recognized as part of oil and gas operating expenses.

NOTE 7 – INVENTORIES FOR OIL AND GAS PROJECTS

As of June 30, 2010 and March 31, 2010 inventories included:

		June 30, 2010		March 31, 2010

Construction material	$	12,863,904	$	12,756,417
Spare parts		96,051		87,722
Crude oil produced		2,009		2,895
Other		883,984		870,813
	$	13,845,948	$	13,717,847

NOTE 8 - LONG TERM VAT RECOVERABLE

As of June 30, 2010 and March 31, 2010, the Company had long term VAT recoverable in the amount of $3,460,543 and $3,113,939, 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 cannot 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 three months ended June 30, 2010, the Company received refunds of VAT in the amount of $378,841.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

JUNE 30, 2010

NOTE 9 - RESTRICTED CASH

Under the laws of the Republic of Kazakhstan, the Company is obligated to set aside funds for required environmental remediation. As of June 30 and March 31, 2010 the Company had restricted $768,724 and $770,553, respectively, for this purpose.

NOTE 10 - 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 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 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:

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

JUNE 30, 2010

Conversion Date	Percentage

On or before July 13, 2008	81.6
Thereafter, but on or before July 13, 2009	86.2
Thereafter, but on or before July 13, 2010	90.9
Thereafter, but on or before July 13, 2011	95.5
Thereafter, and until Maturity Date	100.0

If a holder of Notes shall convert its notes following the date on which notice of a change in control event is given by the Company but on or prior to the 60th day following the date of such notice, then the Company 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:

Conversion Date	Amount

On or before July 13, 2008	$ 0.12239
Thereafter, but on or before July 13, 2009	$ 0.07246
Thereafter, but on or before July 13, 2010	$ 0.02250
Thereafter, but on or before July 13, 2011	$ -
Thereafter, and until Maturity Date	$ -

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. Under the initial terms of the Notes, the Holders of the Notes had 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. As discussed in greater detail in Note 2 above under “Business condition”, in connection with negotiations to restructure the Notes, the Company entered into a Supplemental Indenture with the Holders of the Notes granting the Holders of the Notes an additional put date that commenced on June 13, 2010 and that expires on September 13, 2010. 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 have been used for further exploration of the Company’s oil and gas drilling and production activities in western Kazakhstan.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

JUNE 30, 2010

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:

·	have been effectively registered under the Securities Act and disposed of in accordance with the registration statement relating thereto;

·	may be resold without restriction pursuant to Rule 144 under the Securities Act or any successor provision thereto;

(A) are not subject to the restrictions imposed by Rule 903(b)(3)(iii) under the Securities Act or any successor provision thereto and (B) may be resold pursuant to Rule 144 under the Securities Act or any successor provision thereto without being subject to the restrictions imposed by paragraphs (e), (f) and (h) of Rule 144 under the Securities Act or any successor provisions thereto; provided that the requirements set forth in paragraph (c) of Rule 144

·	under the Securities Act or any successor provision thereto are met as of such date; or

·	have been publicly sold pursuant to Rule 144 under the Securities Act or any successor provision thereto.

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 June 30, 2010 and March 31, 2010, the convertible notes payable amount is presented as follows:

		June 30, 2010		March 31, 2010

Convertible notes redemption value	$	64,323,785	$	64,323,785
Unamortized discount		(1,924,101)		(2,145,666)
	$	62,399,684	$	62,178,119

As of June 30, 2010 and March 31, 2010, the Company has accrued interest of $1,391,667 and $641,667, respectively, 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 $2,399,684 and $2,178,119 as of June 30, 2010 and March 31, 2010, respectively. The carrying value of convertible notes will be accreted to the redemption value of $64,323,785. During the three months ended June 30, 2010 and March 31, 2010 the Company recorded interest expense in the amount of $1,102,750 and $1,148,047, respectively.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

JUNE 30, 2010

On June 7, 2010, the Company entered into a Supplemental Indenture No. 1, dated as of June 1, 2010, between BMB Munai, Inc. and The Bank of New York Mellon, as trustee (the “Supplemental Indenture.”) The Supplemental Indenture amends and supplements the indenture dated September 19, 2007, between BMB Munai, Inc. and The Bank of New York Mellon, as trustee (the “Original Indenture”).

The Original Indenture provided for three put dates that allowed the holders of the Notes to redeem the Notes prior to their 2012 maturity date. The first two put dates passed unexercised. The third put date is July 13, 2010. In connection with ongoing negotiations to restructure the Notes, the Company entered into the Supplemental Indenture which grants the Noteholders a fourth put date that commences on June 13, 2010 and expires on September 13, 2010. In exchange for the granting of the fourth put date in the Supplemental Indenture, the Noteholders separately agreed they will not exercise their put option for the third put date and they will not exercise their put option for the fourth put date prior to September 1, 2010; provided, however, the Noteholders may exercise such put options at any time upon the occurrence of any of the following: (i) any default has occurred under the Indenture, excluding certain defaults that occurred prior to June 7, 2010, (ii) failure by the Company or any of its material subsidiaries to timely pay any Indebtedness (as defined in the Indenture) or any guarantee of any Indebtedness that exceeds U.S. $1,000,000, or any Indebtedness becomes due and payable prior to its stated maturity other than at the option of the Company or any of its material subsidiaries, or (iii) the Noteholders holding a majority in outstanding principal amount of the Notes provide notice to the Company that negotiations with respect to the restructuring have terminated. Therefore, it is possible the Noteholders could exercise a put option with respect to the Notes prior to September 1, 2010 if any of the foregoing events occur.

Prior to entering into the Supplemental Indenture, the Company was in default under certain covenants contained in Article 9 of the Indenture requiring the Company to maintain a minimum net debt to equity ratio and to comply with certain notice, delivery and other provisions. The Noteholders separately agreed to waive these defaults until the earlier of: (i) September 1, 2010 or (ii) the fourth put date (as contained in the Supplemental Indenture), with the understanding that such waiver shall not constitute a waiver of any default under the Indenture that remains ongoing as of September 1, 2010 or occurs after June 8, 2010. At March 31, 2010, the Notes have been classified as a long-term liability on the balance sheet as the defaults have been waived by the Noteholders and the put-option was not in place. The Company currently believes it will not be able to remedy the net debt to equity ratio covenant by September 1, 2010 and, therefore, anticipates it will be in default under the Indenture at that time unless a future waiver is obtained from the Noteholders. There is no assurance the Noteholders will provide any future waiver or any further extension of their redemption put rights under the Indenture. As such, the Company expects to reclassify the Notes as a current liability at September 1, 2010, unless additional waivers are obtained.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

JUNE 30, 2010

NOTE 11 - LIQUIDATION FUND

A reconciliation on the Liquidation Fund (Asset Retirement Obligation) at June 30, 2010 and March 31, 2010 is as follows:

		Total

At March 31, 2010	$	4,712,345

Accrual of liability		-
Accretion expenses		119,188

At June 30, 2010	$	4,831,533

Management believes that the liquidation fund should be accrued for future abandonment costs of 24 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 June 30, 2010, undiscounted expected future cash flows that will be required to satisfy the Company’s obligation by 2013 for the Dolinnoe, Aksaz, Emir and Kariman fields, respectively, are $6,204,545. After application of a 10% discount rate, the present value of the Company’s liability at June 30, 2010 and March 31, 2010 was $4,831,533 and $4,712,345, respectively.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

JUNE 30, 2010

NOTE 12 – CAPITAL LEASE

In December 2009 the Company entered into a capital lease agreement with a vehicle leasing company for the lease of oil trucks in the amount of $554,820. The Company did not put the oil trucks into operations as oil tanks have not been received yet. Accordingly, depreciation expense has not been recognized as the Company has not placed the oil trucks into service.

The capital lease payment schedule is as following:

Year ended June 30,	Total Minimum Payments

2011	$	187,747
2012		240,149
2013		70,167

Net minimum lease payments		498,063
Less: Amount representing interest		(117,167)
Present value of net minimum lease payments	$	380,896

The current portion of the capital lease liability in the amount of $187,747 is recognized as part of accounts payable as of June 30, 2010. The non-current portion of the capital lease liability as of June 30, 2010 totals to $310,315.

NOTE 13 - SHARE AND ADDITIONAL PAID IN CAPITAL

Share-Based Compensation

On July 17, 2008 the shareholders of the Company approved the BMB Munai, Inc. 2009 Equity Incentive Plan (“2009 Plan”) to provide a means whereby the Company could attract and retain employees, directors, officers and others upon whom the responsibility for the successful operations of the Company rests through the issuance of equity awards. 5,000,000 common shares are reserved for issuance under the 2009 Plan. Under the terms of the 2009 Plan the board of directors determines the terms of the awards made under the 2009 Plan, within the limits set forth in the 2009 Plan guidelines.

Common Stock Grants

On January 1, 2010 the Company entered into Restricted Stock Grant Agreements with certain executive officers, directors, employees and outside consultants of the Company. The stock grants were approved by the Company board of directors and recommended by the compensation committee of the Company’s board of directors. The total number of shares granted was 1,500,000.

All of the restricted stock grants were awarded on the same terms and subject to the 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 one-year anniversary of the grant date; 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 fifty percent (50%) or more of the outstanding stock of the Employer or any of its subsidiaries, or the sale of forty percent (40%) or more of the assets of the Employer or any of its subsidiaries, or one (1) person or more than one person acting as a group, acquires fifty percent (50%) or more of the total voting power of the stock of the Employer. In the event of an Extraordinary Event, the grants shall be deemed fully 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.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

JUNE 30, 2010

The shares representing the restricted stock grants (the “Restricted Shares”) shall be issued as soon as practicable, will be deemed outstanding from the date of grant, and will be held in escrow by the Company subject to the occurrence of a Vesting Event. The time between the date of grant and the occurrence of a Vesting Event is referred to as the “Restricted Period.” The grantees may not sell, transfer, assign, pledge or otherwise encumber or dispose of the Restricted Shares during the Restricted Period. During the Restricted Period, the grantees will have the right to vote the Restricted Shares, receive dividends paid or made with respect to the Restricted Shares, provided however, that dividends paid on unvested Restricted Shares will be held in the custody of the Company and shall be subject to the same restrictions that apply to the Restricted Shares. The Restricted 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.

One of the employees left the Company on June 30, 2010. According to the vesting terms, his restricted stock grants have been forfeited back to the Company and non-cash compensation expense of $14,225 related to those restricted stock grants was reversed during three months period ended June 30, 2010.

Non-cash compensation expense in the amount of $413,275, which is net of the expense reversal discussed above, was recognized in the Consolidated Statement of Operations and Consolidated Balance Sheet for the three months ended June 30, 2010.

As of June 30, 2010, there was $840,750 of total unrecognized non-cash 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 0.5 years.

Stock Options

Stock options outstanding and exercisable as of June 30, 2010, were as follows:

	Number of Shares	Weighted Average Exercise Price

As of March 31, 2010	920,783	$ 5.04

Granted	-	-
Exercised	-	-
Expired	-	-
As of June 30, 2010	920,783	$ 5.04

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

JUNE 30, 2010

Additional information regarding outstanding options as of June 30, 2010, is as follows:

Options Outstanding				Options Exercisable
Range of Exercise Price	Options	Weighted Average Exercise Price	Weighted Average Contractual Life (years)	Options	Weighted Average Exercise Price

$4.75 - $ 7.40	920,783	$ 5.04	5.00	920,783	$ 5.04

NOTE 14 – 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.

The Company recognized revenue from sales as follows:

	Three months ended
	June 30, 2010		June 30, 2009

Export oil sales	$	12,542,053	$	11,766,806
Domestic oil sales		-		-
Domestic gas sales		245,793		-
	$	12,787,846	$	11,766,806

NOTE 15 – EXPORT DUTY

On April 18, 2008 the Government introduced an export duty on several products (including crude oil.) The Company became subject to the duty beginning in June 2008. The formula for determining the amount of the crude oil export duty was based on a sliding scale that is tied to several factors, including the world market price for oil. As discussed in Note 2, in December 2008 the Government issued a resolution that cancelled the export duty effective January 26, 2009 for companies operating under the new tax code.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2010

In July 2010 the Government issued a resolution which reenacted the export duty for several products (including crude oil.) The Company will become subject to the export duty beginning in August 2010. The export duty will be calculated based on fixed rate of $2.60 per barrel exported. The export duty fees will be expensed as incurred and will be classified as costs and operating expenses.

NOTE 16 – 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 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. As long as the Company’s capital expenditures exceed generated revenues, the Company will not be subject to Kazakhstan income tax.

As discussed in Note 2, Licenses and contracts, the Company was granted an Exploration contract extension. According to the terms of the Exploration contract, the Company will continue to operate in the exploration phase until January 2013.

Earnings of the Company’s foreign subsidiaries, since acquisition, have been undistributed. 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.

Effective January 1, 2009, the Republic of Kazakhstan adopted a new tax code, which decreased the corporate income rate for legal entities to 20%.

No provision for income taxes has been recorded by the Company for the three months ended June 30, 2010.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

JUNE 30, 2010

Accounting for Uncertainty in Income Taxes - In accordance with generally accepted accounting principles, the Company has analyzed its filing positions in all jurisdictions where it is required to file income tax returns. The Company’s U.S. federal income tax returns for the fiscal years ended March 31, 2006 through 2009 remain subject to examination. The Company currently believes that all significant filing positions are highly certain and that all of its significant income tax filing positions and deductions would be sustained upon an audit. Therefore, the Company has no reserves for uncertain tax positions. No interest or penalties have been levied against the Company and none are anticipated, therefore no interest or penalties have been included in the provision for income taxes.

NOTE 17 - EARNINGS PER SHARE INFORMATION

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

	Three months ended
	June 30, 2010		June 30, 2009

Net income	$	871,868	$	30,782

Basic weighted-average common shares outstanding		51,865,015		47,509,699

Effect of dilutive securities
Warrants		-		-
Stock options		-		-
Unvested share grants		-		-

Dilutive weighted average common shares outstanding		51,865,015		47,509,699

Basic income per common share	$	0.02	$	0.00

Diluted income per common share	$	0.02	$	0.00

The Company has adopted guidance from FASC Topic 260, relating to determining whether instruments granted in share-based payment transactions are participating securities, on April 1, 2009. Accordingly the Company included certain unvested share grants defined as “participating” in the basic weighted average common shares outstanding for the three months ended June 30, 2010 and 2009, respectively. Prior period comparative data has been retrospectively presented to reflect the adoption of this standard.

The diluted weighted average common shares outstanding for the three months ended June 30, 2010 and 2009 does not include the effect of potential conversion of certain warrants and stock options as their effects are anti-dilutive.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

JUNE 30, 2010

The dilutive weighted average common shares outstanding for the three months ended June 30, 2010 and 2009, respectively, does not include the effect of the potential conversion of the Notes because the average market share price for three months ended June 30, 2010 was lower than potential conversion price of the convertible notes for this period.

NOTE 18 - 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 three months ended June 30, 2010 and 2009, totaled to $24,413 and $23,935, respectively. Also the Company made advance payments to Term Oil LLC for leased facilities and fuel tanks in the amount of $76,605 and $143,509 as of June 30, 2010 and June 30, 2009, respectively. A Company shareholder is an owner of Term Oil LLC.

On June 26, 2009 the Company entered into a Debt Purchase Agreement (the “Agreement”) with Simage Limited, a British Virgin Islands international business corporation (“Simage”). Simage is a company owned by Toleush Tolmakov.

Prior to the date of the Agreement, Simage had acquired by assignment, certain accounts receivable owed by Emir to third-party creditors of Emir in the amount of $5,973,185 (the “Obligations”). Pursuant to the terms of the Agreement, Simage assigned to the Company all rights, title and interests in and to the Obligations in exchange for the issuance of 2,986,595 shares of common stock of the Company. The market value of the shares of common stock issued to Simage, at the agreement date, was $3,076,193. The market value was based on $1.03 per share, which was the closing market price of the Company’s shares on June 26, 2009.

As a result of this Agreement, the Company has effectively been released of accounts payable obligations amounting to $5,973,185. The Company has treated this Agreement as a related party transaction, due to the fact that Simage is owned by a Company shareholder. Therefore, the difference between the settled amount of accounts payable and the value of the common stock issued, which amounts to $2,896,997, has been treated as a capital contribution by the shareholder and recognized as an addition to additional-paid-in-capital rather than a gain on settlement of debt.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

JUNE 30, 2010

NOTE 19 - 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, the Southeast Block and the Northwest Block of $5,994,200, $5,350,680 and $5,372,076, respectively. When and if, the Company applies for and, when and if, it is granted commercial production rights for the ADE Block and Southeast Block, the Company will be required to begin repaying these historical investments to the Government. The terms of repayment will be negotiated at the time the Company is granted commercial production rights.

Capital Commitments

To retain its rights under the contract, the Company must spend $27.3 million between January 10, 2011 and January 9, 2012 and $14.9 million between January 10, 2012 and January 9, 2013.

In addition to the minimum capital expenditure requirement, the Company must also comply with the other terms of the work program associated with the contract, which includes the drilling of at least ten new wells by January 9, 2013. 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. The recent addenda to the exploration contract which granted the Company an extension of the exploration period and rights to the Northwest Block also require the Company to:

●	make additional payments to the liquidation fund, stipulated by the Contract;

●	make a one-time payment in the amount of $200,000 to the Astana Fund by the end of 2010; and

●	make annual payments to social projects of the Mangistau Oblast in the amounts of $100,000 from 2010 to 2012.

During the first quarter of 2010, the Company made payment in the amount of $100,000 to social projects of the Mangistau Oblast for 2010.

Capital Lease Agreement

In December 2009 the Company entered into a capital lease agreement with an oil tanks leasing company for the lease of oil tanks in the amount of $493,000. The agreement is effective upon receiving oil tanks by the Company. As of June 30, 2010 the Company had not received the oil tanks. The Company expects to receive the oil tanks in August 2010, at which time the capital lease will be recorded. The agreement calls for average monthly payments of $12,056 during the first year and average monthly payments of $15,010 during the second and third year.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

JUNE 30, 2010

Executive Contracts

On December 31, 2009, the Company entered into new employment agreements with the following executive officers of the Company, Gamal Kulumbetov, Askar Tashtitov, Evgeniy Ler and Anuarbek Baimoldin. Each of these individuals was serving in such capacity prior to entering the employment agreements.

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 three 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 filed on January 6, 2010.

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 annual 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 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.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2010

“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.

Each of the employment agreements, provides that an “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 fifty percent (50%) or more of the outstanding stock of the Company or any of its subsidiaries, or the sale of forty percent (40%) or more of the assets of the Company or any of its subsidiaries, or if one or more persons, acting alone or as a group, acquires fifty percent (50%) or more of the total voting power of the Company. In addition to these provisions, the employment agreement of Mr. Tashtitov provides that the following events also constitute an extraordinary event: i) that a disposition by the Chairman of the Company’s board of directors of by the General Director of the Company’s subsidiary, of seventy five (75%) or more of the shares either individual currently owns, including stock attributed to either of them by Internal Revenue Code Section318; or ii) should the Company terminate the registration of any of its securities under Section 12 of the Exchange Act of 1934, voluntarily ceases, or shall terminate its obligation to file reports with United States Securities Commission pursuant to Section 13 of the Exchange Act of 1934.

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. The employment agreements of Mr. Kulumbetov, Mr. Ler and Mr. Baimoldin provide that if the employment agreement is terminated as a result of an extraordinary event, the officer shall be entitled to severance pay depending on the completed years of employment: i) 10% of Basic Compensation Salary if executive completed less than 1 year of employment; ii) 150% of Basic Compensation Salary if executive completed at least 1 year but not less than 2 years of employment; iii) 299% of Basic Compensation Salary if executive completed more than 2 years of employment.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

JUNE 30, 2010

The employment agreement of Mr. Tashtitov provides that in the event his employment agreement is terminated due to an extraordinary event, he will be entitled to receive a severance payment from the Company of $3,000,000.

All benefits terminate on the date of termination. The officer shall be entitled to accrued benefits, but is not entitled to compensation for unused vacation, holiday, sick leave or other leave.

The employment agreements also contain confidentiality, non-competition and non-interference provisions and provide for certain of the Company’s executive officers to potentially receive payments upon termination or change in control.

Consulting Agreement with Boris Cherdabayev

On December 31, 2009 the Company entered into a Consulting Agreement with Boris Cherdabayev, the Chairman of the Company’s board of directors. The Consulting Agreement became effective on January 1, 2010. Pursuant to the Consulting Agreement, in addition to his services as Chairman of the board of directors, Mr. Cherdabayev will provide such consulting and other services as may reasonably be requested by Company management.

The initial term of the Consulting Agreement is five years unless earlier terminated as provided in the Consulting Agreement. The initial term will automatically renew for additional one-year terms unless and until terminated. The Consulting Agreement may be terminated for Mr. Cherdabayev’s death or disability and by the Company for cause. The Company may also terminate the Consulting Agreement other than for cause, but will be required to pay the full fee required under the Consulting Agreement.

Pursuant to the Consulting Agreement, Mr. Cherdabayev will be paid $192,000 per year. This base consulting fee will be net of Social Tax and Social Insurance Tax in the Republic of Kazakhstan, which shall be paid by the Company. Mr. Cherdabayev will be responsible for Personal Income Tax and Pension Fund Tax. The success of projects involving Mr. Cherdabayev shall be reviewed on an annual basis to determine whether the initial base consulting should be increased.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2010

The Consulting Agreement provides for an extraordinary event payment equal to the greater of $5,000,000 or the base compensation fee for the remaining initial term of the Consulting Agreement. The Consulting Agreement defines an extraordinary event 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 fifty percent (50%) or more of the outstanding stock of the Company or any of its subsidiaries, or the sale of forty percent (40%) or more of the assets of the Company or any of its subsidiaries, or if one or more persons, acting alone or as a group, acquires fifty percent (50%) or more of the total voting power of the Company.

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.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

JUNE 30, 2010

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 the Company’s 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 appealed the court’s refusal to stay the litigation pending arbitration in Kazakhstan. On September 28, 2008, the Court of Appeals issued a decision in which it (a) reversed the district court's refusal to stay the claim for specific performance pending arbitration and (b) affirmed the balance of the district court's order.

At the end of 2008, the Company changed legal counsel to represent all defendants in the lawsuit from Bracewell & Giuliani LLP in New York, New York to Manning, Curtis, Bradshaw & Bednar LLC in Salt Lake City, Utah.

On December 12, 2008, plaintiffs sought leave to file a Third Amended Complaint to add claims for (a) breach of fiduciary duty against defendants Cherdabayev, Kunayev, Baiseitov, Agaian, Benarroch and Credifinance based on these defendants’ alleged role as promoters of Sokol, (b) fraud against all defendants; and (c) promissory estoppel against defendants Cherdabayev, Kunayev and Baiseitov. Defendants opposed the Motion for Leave to Amend and leave to amend was denied. Discovery has been completed. Plaintiffs have submitted an expert report on damages that claims damages of between $6.7 million and $10.9 million, plus interest. The Company disputes the plaintiffs’ damage claim, in addition to disputing liability.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2010

In November 2009, all defendants sought leave to file a Motion for Summary Judgment seeking judgment in favor of defendants on all claims. On June 29, 2010, the Court issued its Opinion and Order, granting in part and denying in part defendants’ summary judgment motion. The Court dismissed the breach of contract and breach of fiduciary duty claims in their entirety. The Court allowed the unfair competition and unjust enrichment claim to proceed to trial based on theories of misappropriation of or unjust enrichment from taking the “product of a plaintiff’s investment of labor, skill and expenditures with respect to a business plan, system, or venture, even absent a showing of ‘novelty.’” The Court held that as a matter of law, the ideas and information Plaintiffs claimed to have provided defendants were not novel. The Court also denied summary judgment on the tortious interference claim finding that “There exists a material issue of fact whether Defendants’ intentional conduct caused Tolmakov to abandon the Emir contract and, if so, whether Plaintiffs suffered damages as a result of such conduct.”

A jury trial has been set for ten days beginning October 5, 2010, in the United States District Court for the Southern District of New York.

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 its management.

Economic Environment

In recent years, Kazakhstan has undergone substantial political and economic change. As an emerging market, Kazakhstan does not possess a well-developed business infrastructure, which generally exists in a more mature free market economy. As a result, operations carried out in Kazakhstan can involve significant risks, which are not typically associated with those in developed markets. Instability in the market reform process could subject the Company to unpredictable changes in the basic business infrastructure in which it currently operates. Uncertainties regarding the political, legal, tax or regulatory environment, including the potential for adverse changes in any of these factors could affect the Company’s ability to operate commercially. Management is unable to estimate what changes may occur or the resulting effect of such changes on the Company’s financial condition or future results of operations.

Legislation and regulations regarding taxation, foreign currency translation, and licensing of foreign currency loans in the Republic of Kazakhstan continue to evolve as the central Government manages the transformation from a command to a market-oriented economy. The various legislation and regulations are not always clearly written and their interpretation is subject to the opinions of the local tax inspectors. Instances of inconsistent opinions between local, regional and national tax authorities are not unusual.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

JUNE 30, 2010

3D Seismic Survey Agreement

On March 31, 2010 the Company entered into an agreement for the conduction of 3D seismic survey with Geo Seismic Service LLP (“Geo Seismic”). Mr. Toleush Tolmakov, the General Director of Emir and a holder of more than 10% of the outstanding common stock of the Company, is a 30% owner of Geo Seismic.

The agreement provides that Geo Seismic will carry out 3D field seismic exploration activities of the Begesh, Aday, North Aday and West Aksaz structures, an area of approximately 96 square kilometers within the Company’s Northwest Block. In exchange for these services, Emir will pay Geo Seismic 570,000,000 Kazakh tenge ($3,800,000). In lieu of payment in Kazakh tenge, Emir, at its sole election, may deliver restricted shares of BMB common stock at the agreed value of the higher of: (i) the average closing price of BMB Munai, Inc. common shares over the five days prior to final acceptance by Emir of the 3D seismic work; or (ii) $2.00 per share. The maximum number of shares which may be delivered as payment in full shall not exceed 1,900,000 restricted common shares. The 3D seismic study was completed in July, 2010. Geo Seismic has not yet requested payment, but the Company anticipates such request will be forthcoming. Emir intends to settle this obligation through the issuance of 1,900,000 Company common shares, which the Company anticipates will occur during the upcoming fiscal quarter.

Consulting Agreement

On October 15, 2008 the MEMR increased Emir Oil LLP’s contract territory from 460 square kilometers to 850 square kilometers. In connection with this extension, and any other territory extensions or acquisitions, the Consultant will be paid a share payment in restricted common stock for resources and reserves associated with any acquisition. The value of any acquisition property will be determined by reference to a 3D seismic study and a resource/reserve report by a qualified independent petroleum engineer acceptable to the Company. The acquisition value (“Acquisition Value”) will be equal to the total barrels of resources and reserves, as defined and determined by the engineering report multiplied by the following values:

Resources at $.50 per barrel;

Probable reserves at $1.00 per barrel; and

Proved reserve at $2.00 per barrel.

BMB MUNAI, INC.

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2010

The number of shares to be issued to the Consultant shall be the Acquisition Value divided by the higher of $6.50 or the average closing price of the Company’s trading shares for the five trading days prior to the issuance of the reserve/resource report, provided that in no event shall the total number of shares issuable to the Consultant exceed more than a total of 4,000,000 shares. With the completion of the 3D seismic study the resources associated with the territory extension have now been determined and we anticipate compensation due to the consultant will be approximately 4,000,000 shares. To date, the Consultant has not requested payment. The Company anticipates a request for payment will be forthcoming and anticipates issuing the shares during the upcoming fiscal quarter.

NOTE 20 - FINANCIAL INSTRUMENTS

As of June 30, 2010 and March 31, 2010 cash and cash equivalents included deposits in Kazakhstan banks in the amount $6,796,936 and $3,721,701, respectively, and deposits in U.S. banks in the amount of $3,417,890 and $2,718,693, 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 June 30, 2010 and March 31, 2010. The Company’s deposits in U.S. banks are also in non-FDIC insured accounts which means they too are not insured to the $250,000 FDIC insurance limit. To mitigate this risk, the Company has placed all of its U.S. deposits in a money market account that invests in U.S. Government backed securities. As of June 30, 2010 and March 31, 2010 the Company made advance payments to Kazakhstan companies and Government bodies in the amount of $7,469,213 and $7,219,431, respectively. As of June 30, 2010 and March 31, 2010 restricted cash reflected in the long-term assets consisted of $768,724 and $770,553, 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 of Kazakhstan.

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

The following discussion is intended to assist you in understanding our results of operations and our present financial condition. Our unaudited consolidated financial statements and the accompanying notes included in this quarterly report on Form 10-Q contain additional information that should be referred to when reviewing this material and this document should be read in conjunction with our annual report on Form 10-K of the for the fiscal year ended March 31, 2010.

Cautionary Note Regarding Forward-Looking Statements

This report includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Rule 175 promulgated thereunder, that involve inherent risks and uncertainties. Words such as “expect,” “anticipate,” “intend,” “plan,” “believe,” “estimate,” “seek,” “could,” “should,” “predict,” “continue,” “future,” “may” and variations of such words and similar expressions are intended to identify such forward-looking statements. Forward-looking statements involve known and unknown risks, uncertainties, assumptions, estimates and other factors that could cause actual results, performance or events to differ materially from any results, performance or events expressed or implied by such forward-looking statements. All forward-looking statements are qualified in their entirety by reference to the factors discussed in this report and identified from time to time in our filings with the SEC including, among others, the following risk factors:

	Ÿ	substantial or extended decline in oil prices;
	Ÿ	inaccurate reserve estimates;
	Ÿ	inability to enter a production contract with the Republic of Kazakhstan;
	Ÿ	drilled prospects may not yield oil or natural gas in commercial quantities;
	Ÿ	substantial losses or liability claims as a result of operations;
	Ÿ	insufficient funds to meet our liquidity needs or to repay debts as they come due;
	Ÿ	complex laws that could affect the cost of doing business;
	Ÿ	substantial liabilities to comply with environmental laws and regulations;
	Ÿ	the need to replenish older depleting oil and natural gas reserves with new oil and natural gas reserves;
	Ÿ	inadequate infrastructure in the region where our properties are located;
	Ÿ	unavailability or high cost of drilling rigs, equipment, supplies, personnel and oil field services;
	Ÿ	unavailability or high price of transportation systems;
	Ÿ	competition in the oil and gas industry; and
	Ÿ	adverse Government actions, imposition of new, or increases in existing, taxes and duties, political risks, expropriation of assets and risks of civil war, primarily in the Republic of Kazakhstan.

The above factors may affect future results, performance, events and the accuracy of any forward-looking statement. This list is illustrative but not exhaustive. In addition, new risks and uncertainties may arise from time to time. Accordingly, readers should not place undue reliance on any forward-looking statement.

Any forward-looking statement speaks only as of the date on which it is made and is expressly qualified by these cautionary statements. Except as may be required by law, we undertake no obligation to publicly update or revise any forward-looking statement for any reason or to update the reasons actual results could differ materially from those anticipated in such forward-looking statements, even if new information becomes available in the future.

Overview

BMB Munai, Inc. is organized under the laws of the State of Nevada. Our business activities focus on oil and natural gas exploration and production in the Republic of Kazakhstan (sometimes also referred to herein as the “ROK” or “Kazakhstan”). We hold an exploration contract that allows us to conduct exploratory drilling and oil production in the Mangistau Province in the southwestern region of Kazakhstan. Since the date of execution of the original exploration contract, we have successfully negotiated several amendments to the contract that have extended the term of our exploration contract to January 2013 and extended the territory of the contract area to approximately 850 square kilometers, which is comprised of the “ADE Block”, the “Southeast Block” and the “Northwest Block”.

Exploration Stage Activities

Under the statutory scheme in Kazakhstan, prospective oil fields are developed in two stages. The first stage is exploration stage. During this stage the primary focus is on the search for commercial discoveries, i.e., discoveries of sufficient quantities of oil and gas to make it commercially feasible to pursue execution of, or transition to, the second stage, which is a commercial production contract with the Government.

Minimum Work Program Requirements

In order to be assured that adequate exploration activities are undertaken during exploration stage, the Ministry of Oil and Gas of the Republic of Kazakhstan (“MOG”) 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 within 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 in each field to establish the existence of commercially producible reserves in any field for which it seeks a commercial production license. Failure to complete the minimum annual work program requirements could preclude the contractor from receiving a longer-term production contract, could result in penalties and fines or even in the loss of the contractor’s license.

The contract we hold follows the above format. Our annual work program year ends on January 9 each year. From the beginning of the exploration stage of our contract through January 9, 2010, our minimum mandatory expenditure requirement totaled $59,090,000. During that time period, we expended $307,428,000 in exploration activities, including the drilling of 24 wells. Our minimum annual expenditure requirements are: $27,300,000 from January 2011 to January 2012; and $14,880,000 from January 2012 to January 2013.

We began drilling in the fields of the ADE block in 2004. Since 2005 we have also been drilling in the Southwest Block in the Kariman field. Our drilling activities have consisted in drilling an array of exploratory wells to delineate reservoir structures and developmental wells intended to provide income to the Company. During fiscal 2009 we completed a very active three-year drilling program. During this time we drilled 17 wells to an average depth of 3,800 meters. Beginning in December of 2008 we began to phase out our new well drilling activities and we have released all as drilling projects were completed.

Our strategy for the current fiscal year is to establish a sound financial basis to support our development of a long-term and profitable oil and gas exploration and production business. We intend to do this by focusing our attention during the fiscal year on the following objectives:

·	Reduce current accounts payable;

·	Conduct field operations focused on maximizing production and field delineation; and

·	Commence investigation of the Northwest Block.

Drilling Operations, Well Performance and Production

Over the past financial year we have concentrated our operational efforts on stabilizing and maintaining production through continuous work with the existing wellstock. No new wells were drilled due to the difficult financial situation we have experienced over the past fiscal year when most of our financial resources were diverted to alleviating working capital problem.

During the fiscal quarter ended June 30, 2010, our average daily crude oil production was 2,415 barrels per day. Our production has decreased compared to the previous quarter due to the additional downtime resulting from necessary maintenance of electronic submersible pumps on the Kariman wells and conducting additional workover on certain Aksaz and Dolinnoe wells. In total more than 10% of our producing wells were shut in for workover/maintenance work during the quarter. We also commenced a directional drilling program on the Kariman field. The first well where directional drilling was employed was Kariman-3 well. This exploratory well drilled behind the fault yielded non-economical quantities of crude production, but provided valuable information about a portion of the Kariman field. Directional drilling is expected to be completed and testing to commence by mid-August. Upon completion of the Kariman-3 well, we plan to commence directional drilling on the Kariman-1 well where preliminary drilling results in the middle Triassic formation have shown promising results. We expect to complete directional drilling at the Kairman-1 well by the end of the second quarter of fiscal year 2011. Pending results of directional drilling on these Kariman wells we will make further decision as to directional/ horizontal drilling on Kariman and other wells in subsequent periods.

Overall, the focus of our production increasing strategy will be on directional/horizontal drilling, Kariman-1 in particular, but we also plan to continue working with the existing wellstock to maintain the stable levels of production achieved during our last fiscal year.

We have also continued our preparatory work for eventual transition of a portion of existing assets to commercial production. We have retained the services of a third-party independent consulting company to prepare a geological model of the Kariman, Aksaz and Dolinnoe fields. This work is ongoing and is expected to be completed prior to the end of fiscal year 2011. This step, in conjunction with cooperation with the Kazakhstani design institute, should prepare us for eventual transition to commercial production.

We have completed 3D seismic processing and interpretation of our Northwest extension. Chapman Petroleum Engineering Ltd has calculated the resources on NW extension. The Resource Report identifies four potential structures on the Northwest Block.

Results of Operations

Three months ended June 30, 2010, compared to the three months ended June 30, 2009.

Revenue and Production

The following table summarizes production volumes, average sales prices and operating revenue for our oil and natural gas operations for the three months ended June 30, 2010 and the three months ended June 30, 2009.

						Three months ended June 30, 2010 to the three months ended
		For the three		For the three		June 30, 2009
		months ended		months ended		$ Increase	% Increase
		June 30, 2010		June 30, 2009		(Decrease)	(Decrease)

Production volumes:
Natural gas (in thousand m3)		7,352		-		7,352	100%
Natural gas liquids (Bbls)		-		-		-	-
Oil and condensate (Bbls)		219,754		224,687		(4,933)	(2%)
Barrels of Oil equivalent (BOE) (3)		263,023		224,687		38,336	17%

Sales volumes:
Natural gas (in thousand m3)		6,020		-		6,020	100%
Natural gas liquids (Bbls)		-		-		-	-
Oil and condensate (Bbls)		214,591		222,550		(7,959)	(4%)
Barrels of Oil equivalent (BOE) (3)		250,023		222,550		27,473	12%

Average Sales Price (1)
Natural gas ($ per thousand m3)	$	40.83		-	$	40.83	100%
Natural gas liquids ($ per Bbl)		-		-		-	-
Oil and condensate ($ per Bbl)	$	58.45	$	52.87	$	5.58	11%
Barrels of Oil equivalent ($ per BOE) (3)	$	51.15	$	52.87	$	(1.73)	(3%)

Operating Revenue:
Natural gas	$	245,793		-	$	245,793	100%
Natural gas liquids		-		-		-	-
Oil and condensate	$	12,542,053	$	11,766,806	$	775,247	7%
Gain on hedging and derivatives (2)		-		-		-	-

(1)	At times, we may produce more barrels than we sell in a given period. The average sales price is calculated based on the average sales price per barrel sold, not per barrel produced.

(2)	We did not engage in hedging transactions, including derivatives during the three months ended June 30, 2010, or the three months ended June 30, 2009.

(3)	The coefficient for conversion production and sales of gas from cubic meters to barrels equals: 1 thousand m3 = 5.8857 Barrels of Oil Equivalent

Revenues. We generate revenue under our exploration contract from the sale of oil and natural gas recovered during test production. During the three months ended June 30, 2010 our oil production decreased 2% compared to the three months ended June 30, 2009.

During the three months ended June 30, 2010 we realized revenue from oil sales of $12,542,034 compared to $11,766,806 during the three months ended June 30, 2009. Production for the three months ended June 20, 2010 is approximately the same as for the three months ended June 30, 2009. During the three months ended June 30, 2010 and 2009 we exported 100% of our oil to the world markets and realized the world market price for those sales. Revenue from oil sold to the world markets made up 98% and 100% of total revenue, respectively, during the three months ended June 30, 2010 and 2009. We anticipate production to remain fairly constant and currently anticipate revenues will be flat quarter-on-quarter in upcoming quarters.

During the first quarter of 2010 we started to realize revenue from natural gas sales to domestic market. During the three months ended June 30, 2010 we realized revenue from natural gas sales of $245,793. During the periods prior to first quarter of 2010 we did not realize revenue from natural gas sales, due to the fact that amount from natural gas sales were insignificant and thus were included in revenue from oil sales. In future periods we anticipate gas production to correlate with oil production.

As discussed above, our revenue is sensitive to changes in prices received for our oil. Political instability, the economy, changes in legislation and taxation, reductions in the amount of oil we are allowed to export to the world markets, weather and other factors outside our control may also have an impact on both supply and demand and on revenue.

Costs and Operating Expenses

The following table presents details of our costs and expenses for the three months ended June 30, 2010 and 2009:

		For the three months ended June 30, 2010		For the three months ended June 30, 2009
Expenses:
Rent export tax	$	2,721,749	$	1,533,437
Oil and gas operating(1)		2,341,837		1,559,000
General and administrative		3,165,111		4,851,766
Depletion(2)		2,343,338		2,243,304
Interest expense		1,102,750		1,148,047
Accretion expenses		119,188		107,847
Amortization and depreciation		150,559		130,973
Total	$	11,944,532	$	11,574,374
Expenses:
Oil and gas operating(1) ($ per BOE)		9.37		7.01
Depletion (2)		9.37		10.08

(1)	Includes transportation cost, production cost and ad valorem taxes (excluding rent export tax).

(2)

Represents depletion of oil and gas properties only.

Rent Export Tax. Rent export tax is calculated based on the export sales price and ranges from as low as 0% if the export sales price is less than $40 per barrel to as high as 32% if the price per barrel exceeds $190. During the three months ended June 30, 2010 rent export tax paid to the Government amounted to $ 2,721,749 compared to $1,533,437 during the three months ended June 30, 2009.

Oil and Gas Operating Expenses. During the three months ended June 30, 2010 we incurred $2,341,837 in oil and gas operating expenses compared to $1,559,000 during the three months ended June 30, 2009. This increase is primarily the result of increased production expense and transportation expense. In addition gas production and gas utilization facility depreciation expenses were added to production cost in the first quarter of 2010.

Oil and gas operating expenses for the three months ended June 30, 2010 and 2009 consist of the following expenses:

		For the three months ended June 30,
		2010				2009
		Total		Per BOE		Total		Per BOE
Oil Operating Expenses:
Production	$	289,776	$	1.16	$	164,093	$	0.74
Transportation		981,869		3.93		767,864		3.45
Mineral extraction tax		844,030		3.38		627,043		2.82
GUF depreciation		226,162		0.90		-		-
Total	$	2,341,837	$	9.37	$	1,559,000	$	7.01

The 214% increase in production expense during the three months ended June 30, 2010 was due to gas production expense and gas utilization facility depreciation expense being realized in the amount of $284,965 during the first quarter of 2010. Additionally, we also realized a $66,880 or 41% increase in payroll and related payments to production personnel during the same period.

Transportation expenses increased by $214,005 or 28% as a result of the increased fuel consumption on oilfields, interest for leased oil tankers, materials used by reservoir park department, increased expenses for brokerage services and increased rates for electricity.

A mineral extraction tax replaced the royalty we were paying under the prior version of the tax code. The rate of this tax depends upon annual production output. The new code currently provides for a 5% mineral extraction tax rate (6% starting in 2013 and 7% starting in 2014) on production sold to the export market, and a 2.5% tax rate (3% in 2013 and 3.5% starting in 2014) on production sold to the domestic market. During the three months ended June 30, 2010 and 2009, mineral extraction tax paid to the Government amounted to $844,030 and $627,043, respectively.

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.

Expense per BOE is a function of total expense divided by the number of barrels of oil and gas we sell. During the three months ended June 30, 2009 we sold 222,550 barrels of oil, compared the three months ended June 30, 2010 we sold 250,023 barrels of oil and gas. The 12% increase in sales of oil and gas volume offset with the 50% increase in oil and gas operating expenses resulted in a $2.36, or 34%, increase in oil and gas operating expense per BOE.

General and Administrative Expenses. General and administrative expenses during the three months ended June 30, 2010 were $3,165,111 compared to $4,851,766 during the three months ended June 30, 2009. This represents a 35% decrease. This decrease in general and administrative expenses was principally the result of an 83% decrease in non-cash compensation expense.

During the three months ended June 30, 2010 we recognized non-cash compensation expense resulting from restricted stock grants previously made to employees in the amount of $413,275. By comparison, during the three months ended June 30, 2009 we recognized non-cash compensation expense in the amount of $2,401,576 for restricted stock grants previously made to employees and outside consultants.

Depletion. Depletion expense for the three months ended June 30, 2010 increased by $100,034 or 4% compared to the three months ended June 30, 2009 as a result of the decrease in proved reserves.

Amortization and Depreciation. Amortization and depreciation expense for the three months ended June 30, 2010 increased by a 15% compared to the three months ended June 30, 2009. The increase resulted from purchases of fixed assets.

Interest Expense. During the three months ended June 30, 2010 we incurred interest expense of $1,102,750 compared to interest expense of $1,148,047 during the same period 2009, which represents decrease by 4%.

Income from Operations. During the three months ended June 30, 2010 we realized income from operations of $843,314 compared to income from operations of $192,432 during the three months ended June 30, 2009. This increase in income from operations during the three months ended June 30, 2010 is the result of the $1,021,040 or 9% increase in revenue.

Total Other Income / (Expense). During the three months ended June 30, 2010 we realized total other income of $28,554 compared to total other expense of $161,650 during the three months ended June 30, 2009. The 118% increase in other income between the respective quarters is largely attributable to a $101,464 interest income from deposits on bank accounts.

Net Income. For the foregoing reasons, during the three months ended June 30, 2010 we realized net income of $871,868 or $0.02 per share compared to net income of $30,782 or $0.00 per share for the three months ended June 30, 2009.

Liquidity and Capital Resources

For the period from inception on May 6, 2003 through June 30, 2010, we have incurred capital expenditures of $307,428,000 for exploration, development and acquisition activities. Funding for our activities has historically been provided by funds raised through the sale of our common stock and debt securities and revenue from oil sales. From inception to June 30, 2010 we raised approximately $94.6 million through the sale of our common stock. Additionally, during the quarter ended June 30, 2007 we completed the placement of $60 million in principal amount of 5.0% Convertible Senior Notes due in 2012. The net proceeds from the Note issuance of approximately $56.2 million were used to pursue our drilling program. For additional detail regarding the Notes, including adjustments to the initial conversion price and the registration right of the Note holders, see Note 10 to the Notes to the unaudited consolidated financial statements, June 30, 2010.

Problems in the credit markets, the significant declines in worldwide oil prices and volatility and downward trends in the stock markets have caused many junior exploration and production companies, including us, to seek additional capital in order to stay in business. Some companies have been acquired by larger companies and others have failed.

At June 30, 2010, our current assets exceeded current liabilities by $6,061,684.

In 2007 we raised $60,000,000 in connection with the issuance of 5.0% Convertible Senior Notes due 2012 (the “Notes”). The terms of the original indenture governing the Notes (the “Original Indenture”) provided for three put dates that allowed the holders of the Notes to redeem the Notes prior to their 2012 maturity date. The first two put dates passed unexercised. The third put date is July 13, 2010. In connection with ongoing negotiations with the holders of the Notes to restructure the Notes, we entered into a Supplemental Indenture which grants the Noteholders a fourth put date that commences on June 13, 2010 and expires on September 13, 2010. In exchange for the granting of the fourth put date, the Noteholders separately agreed they will not exercise their put option for the third put date and they will not exercise their put option for the fourth put date prior to September 1, 2010; provided, however, the Noteholders may exercise such put options at any time upon the occurrence of any of the following: (i) a default occurs under the Indenture, excluding certain defaults that occurred prior to June 7, 2010, (ii) failure by us or Emir to timely pay any Indebtedness (as defined in the Indenture) or any guarantee of any Indebtedness that exceeds U.S. $1,000,000, or any Indebtedness becomes due and payable prior to its stated maturity other than at our or Emir’s option, or (iii) the Noteholders holding a majority in outstanding principal amount of the Notes provide notice to us that negotiations with respect to restructuring the Notes have terminated. Therefore, it is possible the Noteholders could exercise a put option with respect to the Notes prior to September 1, 2010 if any of the foregoing events occur.

Prior to entering into the Supplemental Indenture, we were in default under certain covenants contained in Article 9 of the Indenture requiring us to maintain a minimum net debt to equity ratio and to comply with certain notice, delivery and other provisions. The Noteholders separately agreed to waive these defaults until the earlier of: (i) September 1, 2010 or (ii) the fourth put date, with the understanding that such waiver will not constitute a waiver of any default under the Indenture that remains ongoing as of September 1, 2010 or that occurs after June 8, 2010. We currently believe we will not be able to remedy the default of the net debt to equity ratio covenant by September 1, 2010 and, therefore, we anticipate we will be in default under the Indenture at September 1, 2010 unless a future waiver is obtained from the Noteholders. There is no assurance the Noteholders will provide any future waiver or any further extension of their redemption put rights under the Indenture. Moreover, there is no assurance that we will be successful in renegotiating the terms and conditions of the Notes.

If we are unable to extend the waiver of default beyond September 1, 2010, or at any time we are in default under the Indenture, the Noteholders have the right to accelerate the Notes and require us to make immediate payment of all unpaid interest and principal. As of June 30, 2010, the outstanding balance of unpaid principal and interest under the Notes was $62,399,684. If the Noteholders were to accelerate the Notes, we would have insufficient funds to pay the Notes. We do not anticipate obtaining sufficient funds to retire the Notes in the near future. If we default on the Notes, the Noteholders could seek any legal remedies available to them to obtain repayment of the Notes, including forcing us into bankruptcy, which would likely also result in Emir Oil being forced into bankruptcy. Pursuant to Kazakhstan law and the terms of our exploration license, the Government of the Republic of Kazakhstan has the right to cancel our licenses to the ADE Block, the Southeast Block and the Northwest Block in the event Emir Oil becomes insolvent or enters into bankruptcy. If such were to happen, we would be left with limited assets, no operations and ability to generate revenue or otherwise repay the Notes.

Cash Flows

During the three months ended June 30, 2010 cash was primarily used to fund exploration expenditures. See below for additional discussion and analysis of cash flow.

	Three months ended June 30, 2010		Three months ended June 30, 2009

Net cash provided by operating activities	$	9,382,724	$	5,608,169
Net cash used in investing activities	$	(5,571,380)	$	(5,934,119)
Net cash used in financing activities	$	(36,914)	$	-

NET CHANGE IN CASH AND CASH EQUIVALENTS	$	3,774,430	$	(325,950)

Our principal source of liquidity during the three months ended June 30, 2010 was cash and cash equivalents. At March 31, 2010 cash and cash equivalents totaled approximately $6.4 million. At June 30, 2010 cash and cash equivalents had increased to approximately $10.2 million. During the three months ended June 30, 2010, we spent approximately $5.6 million to fund our drilling and development activities.

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 June 30, 2010, excluding current liabilities as listed on our consolidated balance sheet:

		Payments Due By Period
Contractual obligations	Total		Less than 1 year		2-3 years		4-5 years		After 5 years
Capital Expenditure Commitment(1)	$	42,180,000	$	13,650,000	$	28,530,000	$	-	$	-
Due to the Government of the Republic of Kazakhstan(2)		17,016,956		150,000		985,848		3,343,391		12,537,717
Liquidation Fund		4,831,533		-		4,831,533		-		-
Convertible Notes with Interest(3)		71,823,785		3,000,000		68,823,785		-		-

Total	$	135,852,274	$	16,800,000	$	103,171,166	$	3,343,391	$	12,537,717

(1)

Under the terms of our subsurface exploration contract we are required to spend a total of $42.2 million in exploration activities on our properties, including a minimum of $27.3 million by January 2012 and $14.9 million by January 2013. The rules of the MOG provide a process whereby capital expenditures in excess of the minimum required expenditure in any period may be carried forward to meet the minimum obligations of future periods. Our capital expenditures in prior periods have exceeded our minimum required expenditures by more than $200 million.

(2)

In connection with our acquisition of the oil and gas contract covering the ADE Block, the Southeast Block and the Northwest Block, we are required to repay the ROK for historical costs incurred by it in undertaking geological and geophysical studies and infrastructure improvements. Our repayment obligation for the ADE Block is $5,994,200 and our repayment obligation for the Southeast Block is $5,350,680. We anticipate we will also be obligated to assume a repayment obligation in connection with the Northwest Block, although we do not yet know the amount of such obligation. The terms of repayment of these obligations, however, will not be determined until such time as we apply for and are granted commercial production rights by the ROK. Should we decide not to pursue commercial production rights, we can relinquish the ADE Block, the Southeast Block and/or the Northwest Block to the ROK in satisfaction of their associated obligations. The recent addenda to our exploration contract which granted us with the extension of exploration period and the rights to the Northwest Block also require us to:

·	make additional payments to the liquidation fund, stipulated by the Contract;

·	make a one-time payment in the amount of $200,000 to the Astana Fund by the end of 2010; and

·	make annual payments to social projects of the Mangistau Oblast in the amount of $100,000 from 2010 to 2012.

(3)

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”). 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. The Notes are callable and subject to early redemption in July 2010. 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. For additional details regarding the terms of the Notes, see Note 10 – Convertible Notes Payable to the notes to our Unaudited consolidated financial statements.

Off-Balance Sheet Financing Arrangements

As of June 30, 2010, we had no off-balance sheet financing arrangements.

Item 3. 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 third fiscal quarter 2009 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.

During the fiscal quarter ended June 30, 2010, we sold 214,591 barrels of oil. We realized an average sales price per barrel of $58.45. For purposes of illustration, assuming the same sales volume but decreasing the average sales price we receive from oil sales by $5.00 and $10.00 respectively would change total revenue from oil sales as follows:

	Average Price Per Barrel	Barrels of Oil Sold	Approximate Revenue from Oil Sold (in thousands)	Reduction in Revenue (in thousands)
Actual sales for the three months ended June 30, 2010	$ 58.446	214,591	$ 12,542	$ -
Assuming a $5.00 per barrel reduction in average price per barrel	$ 53.446	214,591	$ 11,469	$ 1,073
Assuming a $10.00 per barrel reduction in average price per barrel	$ 48.446	214,591	$ 10,396	$ 2,146

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.

Our foreign-denominated monetary assets and liabilities are revalued on a monthly basis with gains and losses on revaluation reflected in net income. A hypothetical 10% favorable or unfavorable change in foreign currency exchange rate at June 30, 2010 would have affected our net income by less than $1 million.

Item 4. 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 June 30, 2010.

Changes in Internal Control over Financial Reporting

There were no changes in our internal control over financial reporting during the quarter ended June 30, 2010 that materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II - OTHER INFORMATION

Item 1. Legal Proceedings

See Note 19 “Commitments and Contingencies” to the Notes to the consolidated financial statements under Part I – Item 1of this Form 10-Q.

Item 1A. Risk Factors

In addition to the other information set forth in this quarterly report on Form 10-Q, you should carefully consider the risks discussed in our annual report on Form 10-K for the year ended March 31, 2010, including under the heading “Item 1A. Risk Factors” of Part I, which risks could materially affect our business, financial condition or future results. These risks are not the only risks facing our Company. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial also may materially adversely affect our business, financial condition or future results.

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

In November 2007 we entered into an agreement with Caspian Energy Consulting, Ltd., (the “Consultant”) to, among other things, assist the Company in acquiring additional exploration territories. The agreement provided that the Consultant would be paid a share payment in restricted common stock for resources and reserves associated with any such acquisition. The value of any acquisition property would be determined by reference to a 3D seismic study and a resource/reserve report by a qualified independent petroleum engineer acceptable to the Company. The acquisition value (“Acquisition Value”) will be equal to the total barrels of resources and reserves, as defined and determined by the engineering report multiplied by the following values:

Resources at $.50 per barrel;

Probable reserves at $1.00 per barrel; and

Proved reserve at $2.00 per barrel.

With the assistance of the Consultant, in October 2008 Emir Oil was granted a contract territory extension that increased its exploration territory from 460 square kilometers to 850 square kilometers.

In July 2010 3D seismic study and evaluation of the territory extension was completed. With the completion of the study and evaluation the Consultant is now entitled to compensation under the consulting agreement. Based on the resources identified in the resource report of the independent petroleum engineer we anticipate compensation due to the Consultant will be approximately 4,000,000 shares. To date, the Consultant has not requested payment. We anticipate a request for payment will be forthcoming. We anticipate issuing the shares during the upcoming fiscal quarter.

On March 31, 2010 we entered into an agreement for the conduction of 3D seismic survey with Geo Seismic Service LLP (“Geo Seismic”). Mr. Toleush Tolmakov, the General Director of Emir and a holder of more than 10% of the outstanding common stock of the Company, is a 30% owner of Geo Seismic.

The agreement provided that Geo Seismic would carry out 3D field seismic exploration activities of the Begesh, Aday, North Aday and West Aksaz structures, an area of approximately 96 square kilometers within our Northwest Block. In exchange for these services, Emir would pay Geo Seismic 570,000,000 Kazakh tenge ($3,800,000). In lieu of payment in Kazakh tenge, Emir, at its sole election, may deliver restricted shares of BMB common stock at the agreed value of the higher of: (i) the average closing price of BMB Munai, Inc. common shares over the five days prior to final acceptance by Emir of the 3D seismic work; or (ii) $2.00 per share. The maximum number of shares which may be delivered as payment in full shall not exceed 1,900,000 restricted common shares. The 3D seismic study was completed in August, 2010. Geo Seismic has not yet requested payment, but we anticipate such request will be forthcoming. Emir intends to settle this obligation through the issuance of 1,900,000 Company common shares, which we anticipate will occur during the upcoming quarter.

Both Caspian Energy Consulting Ltd and Geo Seismic Services LLP are non-US persons. The foregoing shares will be issued without registration pursuant to Regulation S of the Securities Act Rules.

Item 6. Exhibits

	Exhibit No.		Description of Exhibit

	Exhibit 12.1		Computation of Earnings to Fixed Charges

	Exhibit 31.1		Certification of Principal Executive Officer Pursuant to
			Section 302 of the Sarbanes Oxley Act of 2002

	Exhibit 31.2		Certification of Principal Financial Officer Pursuant to
			Section 302 of the Sarbanes-Oxley Act of 2002

	Exhibit 32.1		Certification Pursuant to Section 906 of the Sarbanes-
			Oxley Act of 2002

	Exhibit 32.2		Certification Pursuant to Section 906 of the Sarbanes-
			Oxley Act of 2002

SIGNATURES

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



Date:	August 13, 2010	/s/ Evgeniy Ler
		Evgeniy Ler Chief Financial Officer