United States
Securities and Exchange Commission
Washington, DC 20549
FORM 10-KSB/A-1
Annual Report under Section 13 or 15(d) of
The Securities Exchange Act of 1934
For the Fiscal Year Ended Commission File Number
March 31, 2005 000-28638
BMB MUNAI, INC.
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(Exact name of registrant as specified in its charter)
NEVADA
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(State or other jurisdiction of incorporation or organization
30-0233726
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(I.R.S. Employer Identification No.)
20A Kazibek Bi Street, Almaty, Kazakhstan 480100
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(Address of principal executive offices)
+7 (3272) 58-85-17/47
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(Registrant's telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act: None
Securities registered pursuant to Section 12 (g) of the Act: Common Stock $0.001
Par Value.
Check whether the issuer (1) filed all reports required to be filed by Section
13 or 15(d) of the Exchange Act during the past 12 months (or 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 [ ]
Check if there is no disclosure of delinquent filers in response to item 405 of
Regulation S-B is not contained in this form, and no disclosure will be
contained, to the best of the registrant's knowledge, in definitive proxy or
information statements incorporated by reference in Part III of this Form 10-KSB
or any amendment to this Form 10-KSB. [ ]
Indicate by check mark whether the registrant is an accelerated filer.
YES [ ] NO [X]
The registrant's revenues for its most recent fiscal year: $973,646
The aggregate market value of the voting stock held by non-affiliates based on
the average bid and ask prices of such stock on June 2, 2005 was approximately
$67,590,415.
As of June 2, 2005, the registrant had 31,958,846 shares of its $.001 par value
common stock outstanding.
Transitional small business disclosure format (check one) Yes [ ] No [X]
DOCUMENTS INCORPORATED BY REFERENCE: None
BMB MUNAI, INC.
FORM 10-KSB/A-1
TABLE OF CONTENTS
Page
EXPLANATORY NOTE
PART I
Items 1 & 2. Business and Properties.........................................3
PART II
Item 6. Management's Discussion and Analysis of Financial Condition and
Results of Operations............................................22
Item 7. Financial Statements...............................................28
Item 8A. Controls and Procedures............................................31
Item 13. Exhibits...........................................................29
Signatures.........................................................30
2
Explanatory Note to Amendment No. 1 to Form 10-KSB
This Form 10-KSB/A-1 is being filed to correct errors in the
Consolidated Financial Statements and Notes to the Consolidated Financial
Statements and Management's Discussion and Analysis resulting from a downward
revision of the Company's proved oil and gas reserves as of March 31, 2005. In
response to comments raised by the staff of the Securities and Exchange
Commission, the Company's independent petroleum engineering firm re-evaluated
its estimate of the Company's proved reserves at March 31, 2005. The
re-evaluation resulted in a reduction of the Company's proved reserves from
approximately 40 million barrels of oil equivalent to 13 million barrels of oil
equivalent. This downward revision of proved reserves requires the Company to
restate its Consolidated Balance Sheet as of March 31, 2005 to correct its
accounting for oil and gas properties and Consolidated Statements of Loss for
the year ended March 31, 2005 and for the period from inception (May 6, 2003) to
March 31, 2005 to correct its accounting for depletion expenses.
The primary effect of the correction discussed above resulted in the
Company reducing the long-term asset "Oil and Gas Properties, Full Cost Method,
Less Accumulated Depreciation" by $161,954 on its Consolidated Balance Sheet as
of March 31, 2005 and additional accrual of depletion expense by $161,954 on its
Consolidated Statement of Loss for the year ended March 31, 2005 and for the
period from inception (May 6, 2003) to March 31, 2005. The restatement also
resulted in the Company reducing its proved developed reserves of natural gas by
15,917,000 Mcf, proved developed reserves of oil, condensate and natural gas
liquids by 3,034,000 barrels and its standardized measure of discounted future
net cash flows by $15,164,000.
The Consolidated Financial Statements and the entire text of Part I,
Items 1 and 2. Business and Properties, and Part II, Item 6. Management's
Discussion and Analysis and Item 8A. Controls and Procedures have been included
in this Form 10-KSB/A-1 and reflect the revisions discussed above. Otherwise,
this Amendment No. 1 does not modify or update disclosures presented in the
original Form 10-KSB. This Amendment No. 1 speaks to the original filing date of
the Form 10-KSB on July 14, 2005, and does not modify or update disclosures
contained therein, including the nature and character of such disclosures, to
reflect events occurring, or items discovered, after the original filing date of
the Form 10-KSB.
BMB MUNAI, INC.
Unless otherwise indicated by the context, references herein to the
"Company", "BMB", "we", our" or "us" means BMB Munai, Inc, a Nevada corporation,
and its corporate subsidiaries and predecessors.
Forward Looking Information
Certain of the statements contained in all parts of this document
including, but not limited to, those relating to our drilling plans, future
expenses, changes in wells operated and reserves, future growth and expansion,
future exploration, future seismic data, expansion of operations, our ability to
generate new prospects, our ability to obtain a production license, review of
3
outside generated prospects and acquisitions, additional reserves and reserve
increases, managing our asset base, expansion and improvement of capabilities,
integration of new technology into operations, credit facilities, new prospects
and drilling locations, future capital expenditures and working capital,
sufficiency of future working capital, borrowings and capital resources and
liquidity, projected cash flows from operations, future commodity price
environment, expectations of timing, the outcome of legal proceedings,
satisfaction of contingencies, the impact of any change in accounting policies
on our financial statements, the number, timing or results of any wells, the
plans for timing, interpretation and results of new or existing seismic surveys
or seismic data, future production or reserves, future acquisitions of leases,
lease options or other land rights, management's assessment of internal control
over financial reporting, financial results, opportunities, growth, business
plans and strategy and other statements that are not historical facts contained
in this report are forward-looking statements. When used in this document, words
like "expect," "project," "estimate," "believe," "anticipate," "intend,"
"budget," "plan," "forecast," "predict," "may," "should," "could," "will" and
similar expressions are also intended to identify forward-looking statements.
Such statements involve risks and uncertainties, including, but not limited to,
market factors, market prices (including regional basis differentials) of
natural gas and oil, results for future drilling and marketing activity, future
production and costs and other factors detailed herein and in our other
Securities and Exchange Commission filings. Should one or more of these risks or
uncertainties materialize, or should underlying assumptions prove incorrect,
actual outcomes may vary materially from those indicated. These forward-looking
statements speak only as of their dates and should not be unduly relied upon. We
undertake no obligation to publicly update or revise any forward-looking
statement, whether as a result of new information, future events or otherwise.
PART I
Items 1 and 2. Business and Properties
Overview
BMB Munai, Inc., is an independent oil and natural gas company engaged
in the exploration, development, acquisition and production of crude oil and
natural gas properties in the Republic of Kazakhstan (sometimes also referred to
herein as the "ROK" or "Kazakhstan"). During the fiscal year ended March 31,
2005, we changed our domicile from the State of Delaware to the State of Nevada.
We are currently in the development stage. Our current drilling strategy is
focused toward enhancing cash flows and increasing proved developed reserves by
drilling developmental wells within a proximity of existing wells, which we
believe decreases our likelihood of drilling a dry hole, while at the same time
increasing our current production and cash flow. As our cash flow and proved
developed reserves grow, we will begin drilling exploratory wells to find new
reservoirs or extend known reservoirs. We believe this strategy will result in
growth of proved developed reserves, production and financial strength.
4
Recent Developments
At year-end fiscal 2005, our proved reserves were estimated to be 13.2
million barrels of oil. Reserves quoted in BOE were calculated using a
conversion of 6 Mscf/bbl. Approximately 80% of proved total reserves were
developed as of year-end fiscal 2005 and they were all located onshore in
western Kazakhstan. We began workover activities in December 2003 and drilling
activities in July 2004. Through the fiscal year ended March 31, 2005, we have
re-entered three previously existing wells and drilled two new wells. Of these
five wells, one well is currently in test production, three wells are undergoing
testing and one well is undergoing additional workover. In December 2004, the
government of Kazakhstan granted an extension of our ADE Block, which added an
additional 64,247 acres (approximately 260 square kilometers) to the ADE Block
(the "Extended Territory"). The additional territory is adjacent to the ADE
Block. In April 2005, we contracted with TatArka, LLP for a 3D seismic survey of
the Extended Territory. We believe with the completion of a 3D seismic study and
data processing and interpretation of the results of this study, we will have
sufficient information to evaluate the oil and gas reserves of the Extended
Territory, and prepare an efficient work program for further exploration and
development of the Extended Territory.
Strategy
Our goal is to increase stockholder value by investing in oil and
natural gas projects with attractive rates of return on capital employed. We
plan to achieve this goal by exploiting and developing our existing oil and gas
properties and pursuing the acquisition of additional properties. We have and
will continue to focus on the following:
Increasing our Production and Cash Flow. To sustain our operations we
need capital. To date, most of our operating capital has come from the sale of
our securities. We believe that to increase shareholder value and economic
stability, we need to increase our revenues by increasing our production. For
this reason, we have focused our efforts on drilling developmental wells
strategically located within proved areas with the intent to drill wells with a
high probability of success. We believe this strategy will allow us to increase
our current production and correspondingly our cash flows.
Developing and Exploiting Existing Properties. We believe that there is
significant value to be created by drilling the identified undeveloped
opportunities on our properties. We own interest in 640 gross (640 net)
developed acres, plus 960 gross (960 net) acres of proved undeveloped reserves.
We also own interest in approximately 49,150 gross (49,150 net) unproved,
undeveloped acres. Our expected capital budget for development of existing
properties in fiscal 2006 is between $10 million and $14 million.
Pursuing Profitable Acquisitions. While our emphasis in fiscal 2006 is
anticipated to focus on the further development of our existing properties, we
will continue to look for properties with both existing cash flow from
production and future development potential. We intend to pursue acquisitions of
5
properties that we believe have exploitation and development potential
comparable to or greater than our existing properties. We have an experienced
team of management professionals who will identify and evaluate acquisition
opportunities.
Oil and Natural Gas Reserves
The following table sets forth our estimated net proved oil and natural
gas reserves and the present value of estimated cash flows related to such
reserves as of March 31, 2005. We engaged Chapman Petroleum Engineering, Ltd.
("Chapman"), to estimate our net proved reserves, projected future production,
estimated net revenue attributable to our proved reserves, and the present value
of such estimated future net revenue as of March 31, 2005. Chapman's estimates
are based upon a review of production histories and other geologic, economic,
ownership and engineering data provided by us. Chapman has independently
evaluated our reserves for the past nine months. In estimating the reserve
quantities that are economically recoverable, Chapman used oil and natural gas
prices in effect during March 2005 without giving effect to hedging activities.
In accordance with requirements of the Securities and Exchange Commission (the
"SEC") regulations, no price of cost escalation or reduction was considered by
Chapman. The present value of estimated future net revenues before income taxes
was prepared using constant prices as of the calculation date, discounted 10%
per annum on a pretax basis, and is not intended to represent the current market
value of the estimated oil and natural gas reserved owned by us. The oil and
natural gas reserve data included in or incorporated by reference in this
document are only estimates and may prove to be inaccurate.
Proved Reserves
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Developed(1) Undeveloped(2) Total
----------------- ------------------- ----------------
Oil and condensate (MBbls)(3) 10,580 2,580 13,160
Natural gas (MMcf) - - -
Total BOE (MBbls) 10,580 2,580 13,160
Estimated future net revenue before income
taxes (M$) $ 182,377 $ 38,038 $ 220,415
Present value of estimated future net
revenue before income taxes (discounted
10% per annum)(4) $ 68,241 $ 9,037 $77,278
Standardized measure of discounted future
net cash flows(5) $ 99,921
- --------------------
(1) Proved developed reserves are proved reserves that are expected to be
recovered from existing wells with existing equipment and operating methods.
(2) Proved undeveloped reserves are proved reserves which are expected to be
recovered from new wells on undrilled acreage or from existing wells where a
relatively major expenditure is required for recompletion.
(3) Includes natural gas liquids.
(4) Estimated future net reserves represents estimated future gross revenue to
be generated from the production of proved reserves, net of estimated future
production and development costs, using the average oil and gas prices we
6
had been receiving in the Kazakhstan domestic market, as of March 31, 2005,
which was $21.27 per Bbl of oil.
(5) The standardized measure of discounted future net cash flows represents the
present value of future cash flow after income tax discounted at 10%.
The reserve data set forth herein represents estimates only. Reserve
engineering is a subjective process of estimating underground accumulations of
oil and natural gas that cannot be measured in an exact manner. The accuracy of
any reserve estimate is a function of the quality of available data and of
engineering and geological interpretation and judgment. As a result, estimates
made by different engineers often vary from one another. In addition, results of
drilling, testing and production subsequent to the date of an estimate may
justify revision of such estimates, and such revisions may be material.
Accordingly, reserve estimates are generally different from the quantities of
oil and natural gas that are ultimately recovered. Furthermore, the estimated
future net revenue from proved reserves and the present value thereof are based
upon certain assumptions, including current prices, production levels and costs
that may not be what is actually incurred or realized.
No estimates of proved reserves comparable to those included herein
have been included in reports to any federal agency other than the SEC.
In accordance with SEC regulations, the Chapman Report used oil and
natural gas prices in effect at March 31, 2005. The prices used in calculating
the estimated future net revenue attributable to proved reserves do not
necessarily reflect market prices for oil and natural gas production subsequent
to March 31, 2005. There can be no assurance that all of the proved reserves
will be produced and sold within the periods indicated, that the assumed prices
will actually be realized for such production or that existing contracts will be
honored or judicially enforced.
Cost Information
Capitalized Costs
Capitalized costs and accumulated depletion, depreciation and
amortization relating to our oil and natural gas producing activities, all of
which are conducted in the Republic of Kazakhstan, are summarized below:
2005 2004
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Developed oil and natural gas properties $ 43,031,811 $ 6,495,186
Unevaluated oil and natural gas properties - -
Accumulated depletion, depreciation and
Amortization (229,406) -
------------ ------------
Net capitalized cost $ 42,802,405 $ 6,495,186
============ ============
7
Exploration, Development and Acquisition Capital Expenditures
The following table sets forth certain information regarding the total
costs incurred associated with exploration, development and acquisition
activities.
2005 2004
------------ ------------
Acquisition costs:
Unproved properties $ - $ -
Proved properties 20,788,119 1,713,119
Exploration costs 3,373,092 2,659,872
Development costs 18,870,600 2,122,195
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Subtotal 43,031,811 6,495,186
Asset retirement costs - -
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Total costs incurred $ 43,031,811 $ 6,495,186
============ ============
Oil and Natural Gas Volumes, Prices and Operating Expense
The following table sets forth certain information regarding production
volumes, average sales prices and average operating expense associated with our
sale of oil and natural gas for the periods indicated.
For the Period from
For the Year Ended Inception (May 6, 2003)
March 31, 2005 to March 31, 2004
------------------ -----------------------
Production:
Oil and condensate (Bbls) 68,755 -
Natural gas liquids (Bbls) - -
Natural gas (Mcf) - -
Barrels of oil equivalent (BOE) - -
Average Sales Price(1):
Oil and condensate ($ per Bbl) $15.17 $ -
Natural gas liquids ($ per Bbl) $ - $ -
Natural gas ($ per Mcf) $ - $ -
Barrels of oil equivalent ($ per BOE) $ - $ -
Average oil and natural gas operating expenses including
production and ad valorem taxes ($ per BOE)(2) $ 3.08 $ -
- -----------------
(1) During the period from inception through the year ended March 31, 2005, the
Company has not engaged in any hedging activities, including derivatives.
(2) Includes direct lifting costs (labor, repairs and maintenance, materials and
supplies), expensed workover costs and the administrative costs of field
production personnel, insurance and production and ad valorem taxes.
Drilling Activity
The following table sets forth our drilling activity for the period
from inception (May 6, 2003) through March 31, 2004 and for the fiscal year
ended March 31, 2005. In the table, "Gross" refers to the total wells in which
we have a working interest or back-in working interest after payout and "Net"
refers to gross wells multiplied by our working interest therein.
8
For the Year Ended For the Period from Inception (May
March 31, 2005 26, 2003) to March 31, 2004
------------------------------------- ---------------------------------------
Gross Net Gross Net
---------------- ----------------- --------------- -------------------
Exploratory:
Productive - - - -
Non-productive - - - -
---------------- ----------------- --------------- -------------------
Total - - - -
---------------- ----------------- --------------- -------------------
Development:
Productive 5 5 - -
Non-productive - - - -
---------------- ----------------- --------------- -------------------
Total - - - -
---------------- ----------------- --------------- -------------------
Grand Total 5 5 - -
================ ================= =============== ===================
Productive Wells
The following table sets forth the number of productive oil and natural
gas wells in which we owned an interest as of March 31, 2005.
Company-operated Non-operated Total
-------------------------- ------------------------- ---------------------------
Gross Net Gross Net Gross Net
--------- ------------- -------- ------------- -------- ---------------
Oil 5 5 - - 5 5
Natural Gas - - - - - -
--------- ------------- -------- ------------- -------- ---------------
Total 5 5 - - 5 5
========= ============= ======== ============= ======== ===============
Our Properties
We currently own a 100% interest in a license to use subsurface mineral
resources and a hydrocarbon exploration contract issued by the ROK in 1999 and
2000, respectively (collectively referred to herein as the "license" or the
"contract"). The original contract granted its holder the right to engage in
exploration and development activities in an area of approximately 50,000 acres
referred to as the ADE Block. The ADE Block is located onshore in Kazakhstan in
the Mangistau Oblast, approximately 50 kilometers from the Kazakhstan city of
Aktau, a seaport on the Caspian Sea. The ADE Block is comprised of three fields,
the Aksaz, Dolinnoe and Emir fields. When initially granted, the exploration and
development stage of the contract had a five year term. This time for
exploration and development has since been extended to June 9, 2007. If we
desire to move from the exploration and development stage to the commercial
production stage, we must make application to the ROK before June 9, 2007.
During the fiscal year ended March 31, 2005, the territory covered
under the contract was expanded to include an additional 64,247 acres of land
adjacent to the ADE Block, (this land is referred to herein as the "Extended
Territory" or collectively included with the ADE Block as the "ADE Block" or
"our properties.") The Extended Territory is governed under the terms of the
original contract.
9
Under the terms of our contract, we currently have the right to engage
in exploration and development activities within the ADE Block, as extended,
until June 9, 2007. We also have the right to gather and sell all oil and
natural gas we produce until June 9, 2007, with the revenue from such sales
belonging to BMB. During the fiscal year ended March 31, 2005, all sales were
made to the Kazakhstan domestic market. The average price per barrel in the
Kazakhstan domestic market is approximately $25-$30 per barrel lower than the
average world market price. With the completion of additional storage capacity,
we are now capable of exporting oil for sale in the world markets. We will apply
for permission from the government to begin exporting our production for sale in
the world markets. We anticipate realizing greater revenue per barrel in the
international world markets.
To maintain our contract during the exploration and development stage
we are required to meet minimum annual capital expenditures in the exploration
and development of the ADE Block and the Extended Territory. The following table
shows the minimum capital expenditures we are required to make during the 2005
and 2006 calendar years and for the period from January 1, 2007 through June 9,
2007.
Year Minimum Capital Expenditure
---- ---------------------------
2005 $9,300,000
2006 $6,000,000
2007 $4,500,000
Under the terms of the contract, if we wish to move to commercial
production, we must apply to the ROK for commercial production rights. Under our
contract, we must apply for commercial production rights prior to the expiration
of the contract. The terms of our commercial production rights will be
negotiated at the time we move to commercial production. During exploration and
development stage, we have the right to produce and sell oil and natural gas at
a royalty rate of 2%. When we move to commercial production, royalty rates are
negotiated and vary depending on the reserve and production rates. Royalty rates
are established by the taxing authorities of the ROK. The royalty rate is based
on production rates and the rate increases on a sliding scale. Current royalty
rates range for 2% to 6%. Commercial production rights may also require up to
20% of the oil sold to the Kazakhstan domestic market at considerably lower
prices than received in the world export markets, as discussed above.
Under our contract, we have the exclusive right to negotiate for and
receive commercial production rights. The government is required to negotiate
the terms of these rights in good faith in accordance with the Law of Petroleum
of Kazakhstan. So long as we establish commercially producible reserves and have
fulfilled our obligations during exploration and development, the government is
required to grant us production rights. We have not yet applied for commercial
production rights because we enjoy certain economic advantages during
exploration and development as discussed herein.
10
During fiscal 2005 we re-entered one well in the Aksaz field,
re-entered one well and drilled two wells in the Dolinnoe field and re-entered
one well in the Emir field. Each of these wells was successfully completed and
is either in testing, test production or additional workover. These wells
accounted for 100% of our total production during the year. In fiscal 2006 we
expect to drill one additional well in the ADE block. This well is planned in
the Aksaz field. Because we were not granted the Extended Territory until
December 2004, we did not engage in any exploration or development activities in
the Extended Territory during the fiscal year ended March 31, 2005.
Title to Properties
We hold an exploration contract from the Republic of Kazakhstan that
grants us the right explore and engage in test production of hydrocarbons on the
ADE Block and the Extended Territory. Our rights to the properties will
terminate in June 2007 unless we are able to negotiate an extension of our
current property exploration contract or we are granted a commercial production
contract.
Marketing
Currently we are selling all oil from test production to local
refineries at the domestic market price. Delivery is made by railcars filled at
the pouring station terminal located at the oil storage facility we lease.
We anticipate that once we begin commercial production we will market
our production to third parties consistent with industry practices.
In the domestic market, the price per barrel is lower than in world
markets. When we are able to access the world markets, our marketing objective
will be to receive the highest possible price for our product.
There are a variety of factors which affect the market for oil and
natural gas, including the extent of domestic production and imports of oil and
natural gas, the availability, proximity and capacity of natural gas pipelines
and other transportation facilities, demand for oil and natural gas, the
marketing of competitive fuels and the effects of state and federal regulations
on oil and natural gas productions and sales.
Sales to Major Customers
We sold production representing 10% or more or our total revenues for
the fiscal year ended March 31, 2005 as listed below.
Volume (Bbls) Amount ($) % of Sales
--------------- --------------- ------------
Atyrau Refinery 43,959 $ 564,788 69%
LLC Shugla 20,210 $ 408,858 31%
We produced no crude oil or natural gas during the period from
inception (May 6, 2003) through March 31, 2004.
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In the exploration, development and production business, production is
normally sold to relatively few customers. Substantially all of our customers
are concentrated in the oil and gas industry, and revenue can be materially
affected by current economic conditions and the price of certain commodities
such as natural gas and crude oil the cost of which is passed through to the
customer. However, based on the current demand for natural gas and crude oil and
the fact that alternate purchasers are readily available, we believe that the
loss of any of our major purchasers would not have a long-term material adverse
effect on our operations.
Competition
Hydrocarbons exploration is highly competitive. Competition in
Kazakhstan and Central Asia includes other junior hydrocarbons exploration
companies, mid-size producers and major exploration and production companies. We
will have to compete for additional exploration and production properties with
these companies who in most cases may have greater financial resources and
larger technical staff than us.
We believe we have an advantage because we have a proven track record
with major former Soviet Union oil and gas and banking industry players forming
our board of directors and executive management team. We have several prominent
figures in the oil and gas industry and banking. In addition our staff has vast
domestic and international experience and has been working in Kazakhstan and
Russia for up to 30 years, and has developed relationships with the government
and its departments and ministries at many levels. We also employ experienced
national and foreign specialists at senior levels in our operating subsidiary.
There is significant competition for capital with other exploration and
production companies and industry sectors. At times, other industry sectors may
be more in favor with investors limiting our ability to obtain necessary
capital.
Government Regulation
Our operations are subject to various levels of government controls and
regulations in the United States and in Kazakhstan. We attempt to comply with
all legal requirements in the conduct of our operations and employ business
practices that we consider to be prudent under the circumstances in which we
operate. It is not possible for us to separately calculate the costs of
compliance with environmental and other governmental regulations as such costs
are an integral part of our operations.
In Kazakhstan, legislation affecting the oil and gas industry is under
constant review for amendment or expansion. Pursuant to such legislation,
various governmental departments and agencies have issued extensive rules and
regulations that affect the oil and gas industry, some of which carry
substantial penalties for failure to comply. These laws and regulations can have
a significant impact on the industry by increasing the cost of doing business
12
and, consequentially, can adversely affect our profitability. Inasmuch as new
legislation affecting the industry is commonplace and existing laws and
regulations are frequently amended or reinterpreted, we are unable to predict
the future cost or impact of complying with such laws and regulations.
Risk Factors Relating to our Business
Limited Capital Resources and Liquidity
We are a development stage company and have not yet generated
significant production or revenues from the development of our primary
properties in Kazakhstan.
While we have raised capital to fund acquisitions, undertake our first
year work program, including 3D seismic, processing and interpretation of the
data obtained during 3D seismic, re-entering old wells in the Aksaz, Dolinnoe
and Emir fields, well work over, construction of the ground facilities for
pre-sale oil processing, drilling of several new wells, start-up expenses, etc.,
we still lack sufficient capital to complete exploration and development of our
properties. Thus we are using more cash in operations than we are generating.
Furthermore, we anticipate that the development of our properties will require
substantial additional funding before we can achieve significant production and
revenues from operations.
Inability to Obtain Additional Funding
To satisfy future capital investment commitments and liquidity needs
with respect to our ongoing operations, we may require additional equity or debt
financing. Our ability to arrange financing and the cost of financing depends
upon many factors, including:
o economic and capital market conditions;
o investor confidence in the oil and gas industry, in Kazakhstan
and in the Company;
o credit availability from banks and other lenders; and
o provisions of taxes and securities laws that are conducive to
raising capital.
The terms and conditions on which future funding or financing may be
made available may not be acceptable or available at all. If we issue capital
stock or convertible securities to raise funds, your ownership could be diluted
or new investors might obtain terms more favorable than yours. If we decide to
raise additional funds by incurring debt, we may become more leveraged and
subject to more restrictive financial covenants and ratios. Our inability to
procure sufficient financing could adversely affect our ability to implement our
business strategy.
Failures to Satisfy our Commitments During Exploration and Development
Stage
We have committed to the government of Kazakhstan to make various
capital investments and to develop the ADE Block in accordance with specific
requirements during exploration and development. Additionally, to undertake
13
commercial production, we will need to apply for and be granted commercial
production rights. The requirements of our current license may be inconsistent
with the terms of any new licenses we are issued. Additionally, we may not be
able to satisfy all commitments in the future. If we fail to satisfy these
commitments our contract may be cancelled. The cancellation of our contract
could have a material adverse effect on our business, results of operations and
financial condition. Although we would seek waivers of any breaches or to
renegotiate the terms of our commitments, we cannot assure you that we would be
successful in doing so.
Inadequate Infrastructure
Our exploration and development activities could suffer due to
inadequate infrastructure in the region. We are working to improve the
infrastructure on our properties. Any problem or adverse change affecting our
operational infrastructure, or infrastructure provided by third parties, could
have a material adverse effect on our financial condition and results of
operations. Similarly, if we are unsuccessful in developing the infrastructure
on our properties it could have a material adverse effect on our financial
conditions and results of operations.
Reliance on Third Parties for Transportation Systems
The crude oil we produce must be transported through pipelines or by
rail. These pipelines and railways are operated by state-owned entities or other
third parties, and there can be no assurance that these transportation systems
will always be functioning and available, or that the transportation costs will
remain at acceptable levels. In addition, any increase in the cost of pipeline
transportation or reduction in its availability to us could have a material
adverse effect on our results of operations. There can be no assurance that we
will be able to procure sufficient transportation capacity on economical terms,
if at all.
Liquidity of our Common Shares
Our stock has limited trading volume on the Over-the-Counter Bulletin
Board and is not listed on a national exchange. Moreover, a significant
percentage of our outstanding common stock is "restricted" and therefore subject
to the resale restrictions set forth in Rule 144 of the rules and regulations
promulgated by the Securities and Exchange Commission under the Securities Act
of 1933. These factors could adversely affect the liquidity, trading volume,
price and transferability of our common shares.
Control by our Officers and Directors
In the aggregate, our executive officers and directors control
approximately 40% of the outstanding shares of our common stock. Such
concentrated control may adversely affect the price of our common stock. Our
officers and directors may be able to exert significant influence, or even
14
control, over matters requiring approval by our security holders, including the
election of directors. Such concentrated control may also make it difficult for
our shareholders to receive a premium for their shares of our common stock in
the event we merge with a third party or enter into a different transaction
which requires shareholder approval.
Key Personnel
Our success is dependent on the performance of our senior management
and key technical personnel each of whom have extensive experience in either the
oil and gas or finance industries. The loss of our executive officers, directors
or other key employees could have an adverse effect on our business. We do not
have employment agreements in place with our senior management or key employees.
We do not currently carry key man insurance for any of our senior management or
key employees, nor do we anticipate obtaining key man insurance in the
foreseeable future.
Risk Factors Relating to our Industry
Exploration and Development Risks
Our success is dependent on finding, developing and producing economic
quantities of oil and gas. We make use of the best information available to us
and employ current technologies and consultants to attempt to mitigate risks.
However, despite these efforts, we may be unsuccessful in finding economically
recoverable reserves. We are also subject to operating risks normally associated
with the exploration, development and production of oil and gas. These risks
include high pressure or irregularities in geological formations, blowouts,
fires, shortages or delays in obtaining equipment and qualified personnel,
equipment failure or accidents, and adverse weather conditions, such as winter
snowstorms. These risks can result in catastrophic events, or they may result in
higher costs and operating delays. We do not currently maintain insurance
coverage to compensate for these risks as such coverage is either not available
or is not considered to be cost-effective.
Oil and Gas Reserve Risks
There are numerous uncertainties inherent in estimating quantities of
proved oil and gas reserves and projecting future rates of production and timing
of development expenditures. Changes in prices and cost levels, as well as the
timing of future development costs, may cause actual results to vary
significantly from the projected ones. The economic success of our properties is
dependent on proving existing reserves and rates of production from existing and
new wells to generate positive cash flow and provide an economic rate of return
on our investments in the fields.
Hydrocarbons Exploration, Development and Production Industry
Hydrocarbons exploration and development is a speculative business
characterized by a number of significant uncertainties. The marketability of
hydrocarbons acquired or discovered by us may be affected by numerous factors
15
that are beyond our control and that cannot be accurately predicted, such as
market fluctuations, the proximity and capacity of exploration and production
facilities, hydrocarbons markets and processing equipment, and other factors
such as government regulations, including regulations relating to royalties,
allowable production, importing and exporting of hydrocarbons, and environmental
protection, a combination of which factors may result in us not receiving an
adequate return on invested capital.
Hydrocarbons Price Fluctuations
Our future success is dependent on being able to transport and market
our production either within Kazakhstan or preferably through export to
international markets. The market price of hydrocarbons is volatile and beyond
our control and may adversely affect the feasibility or future profitability of
potential projects. The decision to put a field into production and the
commitment of the funds necessary for that purpose must be made long before the
first revenues from production will be received. Hydrocarbons price fluctuations
as well as forecast production costs between the time that such decision is made
and the commencement of production can completely change the economics of any
field.
Although it is possible to protect against hydrocarbons price
fluctuations by hedging in certain circumstances, the volatility of hydrocarbons
prices represents a substantial risk in the exploration and production industry
generally, which no amount of planning or technical expertise can eliminate.
If we are successful in establishing meaningful quantities of oil and
gas production, the prices we receive for our oil production will have a
significant impact on our future financial position and results.
Risks of Doing Business in Kazakhstan
We believe that the present policies of the government of the ROK are
favorable to foreign investment and to exploration and production and are not
aware of any impending changes. While there is a certain amount of bureaucratic
"red tape" we have significant experience working in Kazakhstan, and good
relationships with government agencies at many levels.
We, however, remain subject to all the risks inherent in international
operations, including adverse governmental actions, political risks, and
expropriation of assets, loss of revenues and the risk of civil unrest or war.
Our primary oil and gas property is located in Kazakhstan, which until 1990 was
part of the Soviet Union. Kazakhstan retains many of the laws and customs from
the former Soviet Union, but has developed and is continuing to develop its own
legal, regulatory and financial systems. As the political and regulatory
environment changes, we may face uncertainty about the interpretation of our
agreements and in the event of dispute, may have limited recourse within the
legal and political system.
16
If we are successful in establishing commercial production from our
properties, an application will be made for commercial production rights. We
have the exclusive right to negotiate this contract for the ADE Block and
Extended Territory, and the government is required to conduct these negotiations
under the Law of Petroleum. Such contracts are customarily awarded upon
determination that the field is capable of commercial rates of production and
that the applicant has complied with the other terms of its license and
exploration contract. The terms of the commercial production contract will
establish the royalty and other payments due to the government in connection
with commercial production. At the time the commercial production contract is
issued, we will be required to begin repaying the government its historical
investment costs of exploration and development of the ADE Block and the
Extended Territory. The obligation associated with the ADE Block is
approximately $6 million. The obligation we will be required to assume in
connection with the Extended Territory has not yet been determined and is
currently being negotiated. If satisfactory terms for commercial production
rights cannot be negotiated, it could have a material adverse effect on our
financial position.
Environmental Risks
The exploration and development of our projects are subject to Kazakh
laws and regulations concerning environmental matters and the discharge of
hazardous wastes and materials. We have and intend to continue to conduct our
activities in compliance with international environmental and occupational
health and safety norms, even if they exceed the currently applicable Kazakh
requirements.
Future environmental laws and regulations could impose increased
capital or operating costs on us and could restrict and/or delay the development
or operation of our projects.
As the holder of rights to oil and gas properties, we are subject to
various federal, states, local and foreign laws and regulations relating to
discharge of materials into, and protection of, the environment. These laws and
regulations may impose liability on us for the cost of pollution cleanup
resulting from operations and could subject us to liability for pollution
damages.
Employees
At the time of this filing, we had 133 full-time employees. We believe
that our relationships with our employees are good. None of our employees are
covered by a collective bargaining agreement. From time to time we utilize the
services of independent consultants and contractors to perform various
professional services. Field and on-site production operation services, such as
pumping, maintenance, dispatching, inspection and testing are generally provided
by independent contractors.
17
Executive Offices
Our principal executive and corporate offices are located in an office
building located at 20A Kazibek Bi Street, in Almaty, Kakzakhstan. We lease this
space and believe it is sufficient to meet our needs for the foreseeable future.
During our fourth fiscal quarter we decided to close our New York
office. We are currently in the process of finalizing that closure and hope to
sublease this office space for the remaining term of the lease.
Reports to Security holders
We file Annual Reports on Form 10-KSB, Quarterly Reports on Form
10-QSB, Current Reports on Form 8-K and other items with the Securities and
Exchange Commission (SEC). We provide free access to all of these SEC filings,
as soon as reasonably practicable after filing, on our Internet web site located
at . In addition, the public may read and copy any documents we file with the
SEC at the SEC's Public Reference Room at 450 Fifth Street, NW, Washington, DC
20549. The public may obtain information on the operation of the Public
Reference Room by calling the SEC at 1-800-SEC-0330. The SEC maintains its
Internet site www.sec.gov, which contains reports, proxy and information
statements and other information regarding issuers like BMB Munai.
PART II
Item 6. Management's Discussion and Analysis of Results of Operations
The following discussion is intended to assist you in understanding our
results of operations and our present financial condition. Our Consolidated
Financial Statements and the accompanying notes included elsewhere in this Form
10-KSB/A-1 contain additional information that should be referred to when
reviewing this material.
Statements in this discussion may be forward-looking. These
forward-looking statements involve risks and uncertainties, including those
discussed below, which could cause actual results to differ from those
expressed. Please read Forward-Looking Information on page 3.
Overview
We operate in one segment, natural gas and oil exploration and
development. We hold a contract that currently allows us to explore and develop
approximately 460 square kilometers in western Kazakhstan. Our contract includes
the ADE Block and the Extended Territory, which are collectively referred to
herein as "our properties."
Under our contract we are permitted to explore for oil and natural gas
within our properties. Our contract also grants us the right to sell the oil and
natural gas recovered during test production to generate revenue. We have been
engaged in test production and selling of crude oil since May 2004. Under the
terms of our contract, we are required to sell the oil and gas we produce in the
18
Kazakhstan domestic market until we apply for and are granted permission to
export our production. The average price per barrel of crude oil in the
Kazakhstan domestic market during the past twelve months has been approximately
$15 per barrel, significantly lower than the world market price. For most of
fiscal 2005, we lacked sufficient storage capacity to accumulate adequate
volumes of oil for exportation. With the completion of additional storage
capacity at the facility, we now have the capability to export oil for sale in
the world markets. We will apply for permission from the government to begin
exporting our production for sale in the world markets. We anticipate realizing
greater revenue per barrel once we begin exporting oil to the international
world markets.
During the fiscal year ended March 31, 2005 we generated revenue of
$973,646. We did not generate any revenue during the period from inception (May
6, 2003) through March 31, 2004 because we did not begin test production until
May 2004. For the year ended March 31, 2005 crude oil accounted for 100% of our
production and revenues.
We invested approximately $17,411,861 in cash in exploration and
development of our properties during the fiscal year ended March 31, 2005. Our
budget for exploration and development of our properties for the upcoming fiscal
year is approximately $10 million to $14 million.
We have and will continue to seek to increase our proven reserves
through continued exploration of our properties, as well as the acquisition of
other properties with exploration and production potential.
For us to operate profitably and grow in the future we need to obtain
additional capital either through additional fund raising or through
significantly increased production. Our revenue, profitability and future growth
depend substantially on factors beyond our control, such as economic, political
and potential regulatory and competition from other sources of energy. Oil and
natural gas prices historically have been volatile and may fluctuate widely in
the future. Sustained periods of low prices for oil or natural gas could
materially and adversely affect our financial position, results of operations,
the quantities of oil and natural gas reserves that we can economically produce,
the markets into which we can sale our oil and our access to additional capital.
In a worst case scenario, future drilling operations could be largely
unsuccessful, oil and gas prices could sharply decline, we could fail to gain
access to the world oil markets and/or other factors beyond our control could
cause us to modify or substantially curtail our exploration and development
plans, which could negatively impact our earnings, cash flow and most likely the
trading price of our securities.
Results of Operations
The following table sets forth selected operating data for the periods
indicated:
19
For the period from inception
For the year ended (May 6, 2003) through
March 31, 2005 March 31, 2004
------------------ -----------------------------
Revenues:
Oil and gas sales $ 973,646 -
Expenses:
Oil and gas operating(1) 197,697 -
Production 265,149 -
Selling 206,929 -
Depreciation, depletion and
amortization 295,857 4,758
General and administrative 4,060,962 781,757
Net Production Data:
Oil (Bbls) 68,755 -
Natural gas (Mcf) - -
Barrels of oil equivalent (BOE) - -
Average Sales Price:
Oil (per Bbl) 15.17 -
Natural gas (per Mcf) - -
Equivalent price (per BOE) - -
Expenses ($ per BOE):
Oil and gas operating(1) 3.08 -
Depreciation, depletion and
amortization(2) 3.58 -
- ------------------
(1) Includes lease operating costs and production and ad valorem taxes.
(2) Represents depreciation, depletion and amortization of oil and gas
properties only.
Year ended March 31, 2005 compared to the period from inception (May 6,
2003) through March 31, 2004
Revenue and Production
The following table summarizes production volumes, average sales prices
and operating revenue for our oil and natural gas operations for the year ended
March 31, 2005 and the period from inception (May 6, 2003) to March 31, 2004.
Fiscal 2005 Compared to the
Period from inception (May
6, 2003) through March 31,
2004
For the Period ----------------------------
For the Fiscal from Inception $ %
Year ended Through Increase Increase
March 31, 2005 March 31, 2004 (Decrease) (Decrease)
------------------ -------------------- ------------ -------------
Production volumes:
Natural gas (Mcf) - - - -
Natural gas liquids (Bbls) - - - -
Oil and condensate (Bbls) 68,755 - 68,755 N/A
Barrels of oil equivalent (BOE) - - - -
20
Average Sales Price
Natural gas ($ per Mcf) $ - $ - $ - $ -
Natural gas liquids ($ per Bbl) $ - $ - $ - $ -
Oil and condensate ($ per Bbl) $ 15.17 $ - N/A N/A
Natural gas Barrels of oil
equivalent ($ per BOE) - $ - $ - $ -
Operating Revenue:
Natural gas $ - $ - - $ -
Natural gas liquids $ - $ - - $ -
Oil and condensate $973,646 $ - $ 973,646 N/A
Gain on hedging and derivatives(1) $ - $ - $ - $ -
--------------- ----------------- --------------- -------------
Total $973,646 $ - $ 973,646 $ -
=============== ================= =============== =============
- -------------------
(1) We did not engage in hedging transactions, including derivatives during the
fiscal year ended March 31, 2005, or the period from inception to March 31,
2004.
Revenues. We generate revenue under our contract from the sale of oil
and natural gas recovered during test production. During the year ended March
31, 2005, we realized revenue from oil and gas sales of $973,646 compared to $0
during the year ended March 31, 2004. This increase in revenues in the 2005
fiscal year is primarily the result of the fact that in the period from
inception through March 31, 2004, we were just beginning operations and seeking
to acquire rights to oil and gas properties and we had no oil and gas sales
during that period. We anticipate revenues will continue to increase in the
upcoming fiscal year. At the present time, however, it is unclear the rate at
which our production and corresponding revenues may increase.
Our revenue is sensitive to changes in prices received for our
products. Our production is sold at the prevailing market price in Kazakhstan,
which fluctuates in response to many factors that are outside our control.
Imbalances in the supply and demand for oil can have a dramatic effect on the
prices we receive for our production. Political instability, the economy,
weather and other factors outside our control could impact supply and demand.
Costs and Operating Expenses
Production Expenses. During the fiscal year ended March 31, 2005, we
incurred $427,103 in production expenses. We had no similar expense during the
period from May 6, 2003, to March 31, 2004 because we were not engaged in oil
and gas production during the prior period. We expect production expenses to
continue to increase in the upcoming fiscal year. At the present time, however,
it is unclear the rate at which our production expenses may increase in the
upcoming fiscal year.
Selling Expenses. We incurred selling expenses of $206,929 during the
fiscal year ended March 31, 2005 compared to $0 during the period from inception
through March 31, 2004. We did not incur selling expenses in the prior year
period because we did not engage in the sale of oil or gas during that period.
21
General and Administrative Expenses. General and administrative
expenses during the fiscal year ended March 31, 2005 were $4,060,962 compared to
$781,757 during the period from inception on May 6, 2003 through March 31, 2004.
This represents a 419% increase in general and administrative expenses. This
significant increase is attributable to a 208% increase in payroll and other
compensation, a 284% increase in professional fees, a 781% increase in business
trip expenses, a 359% increase in taxes, a 2,049% increase in rent, a 992%
increase in transportation, a 5,016% increase in insurance expense, a 2,152%
increase in communication expenses and a 979% increase in other expenses. During
the 2005 fiscal year we accrued a $250,000 obligation required under our work
program to contribute to the Astana Fund, a government fund used to fund
construction and development Astana, Kazakhstan - the capital of Kazakhstan.
This was a one-time obligation. This amount was paid by us subsequent to our
fiscal year end. Additionally, we established bad debt reserves in the amount of
$129,051 on advances for inventory purchases during the fiscal year ended March
31, 2005. The significant increase in general and administrative expenses is
largely the result of hiring more personnel to operate our business, using
services of technicians, engineers, accountants and lawyers, as well as
incurring other general corporate expenses. We anticipate general and
administrative expenses will increase in the upcoming fiscal year. However, we
do not expect general and administrative expenses to increase at such a
significant rate in the upcoming year. We anticipate increases in revenue,
operating costs and selling costs will outpace the increase in general and
administrative expenses in the upcoming year.
In April 2005 we elected to relocate our U.S. offices to Salt Lake
City. Consequently we plan to sublease our office space in New York City to
another company. We also reduced the number of employees we have in our U.S.
office. We believe these measures will reduce our rent, taxes and other relevant
expenses in the upcoming fiscal year.
Loss from Operations. As a result of significantly increasing expenses,
which were only partially offset by revenue from oil and gas sales, during the
fiscal year ended March 31, 2005 we realized a loss from operations of
$3,787,799 compared to a net loss from operations of $786,515 during the period
from May 6, 2003 to March 31, 2004. Until such time as revenue from oil and gas
sales exceeds expenses we will continue to generate operating losses. At this
time, it is unclear when we will generate sufficient oil and gas to offset our
expenses.
Other Income. During the fiscal year ended March 31, 2005 we realized
total other income of $501,830 compared to $254,717 for the period from May 6,
2003 to March 31, 2004. This 97% increase in other income is largely
attributable to $428,572 increase in exchange gain resulting from fluctuations
of foreign currency rates against the U.S. Dollar, a $165,699 increase in
realized gain on dealing securities and our realizing interest income of $17,799
compared to interest payments of $84,007, partially offset by a $501,174
decrease in realized and unrealized gains on marketable securities. During the
2005 fiscal year we raised approximately $27 million through the sale of our
securities in private placement transactions. Therefore, at times during the
year, we had funds that were not being used in operations that we invested in
22
marketable securities. We anticipate the funds held in marketable securities
will be used to fund our operations and therefore expect gains from marketable
securities, both realized and unrealized, to decrease in the next twelve months.
Net Loss. During the fiscal year ended March 31, 2005 we realized a net
loss of $3,286,312 compared to a net loss of $613,782 for the period from
inception, May 6, 2003 through March 31, 2004. As discussed above this net loss
is largely the result of our engaging in active exploration and development
activities and operations for the entire 2005 fiscal year, whereas we were not
engaged in active operations for much of the prior fiscal period. We will
continue to realize net losses from operations until such time as revenues
generated from oil and gas production and sales and other income offset our
expenses. At this time, it is unclear when, or if, that may occur.
Liquidity and Capital Resources
Funding for our activities has historically been provided by funds
raised through the sale of our common stock. From inception on May 6, 2003
through March 31, 2005, we have raised $37,416,034 through the sale of our
common stock and proceeds from the issuance of convertible debt. As of March 31,
2005, we had cash and cash equivalents of $9,989,632. We anticipate our capital
resources in the upcoming twelve months will likewise consist primarily of funds
raised in financing activities and revenue from the sale of oil and gas
recovered during test production.
Our need for capital, in addition to funding our ongoing operations, is
primarily related to the exploration and development of our properties as
required under our contract, and the potential acquisition of additional oil and
gas properties. For the period from inception on May 6, 2003 through March 31,
2005, we have incurred capital expenditures of $42,802,405 for exploration,
development and acquisition activities.
Cash Flows
During the fiscal year ended March 31, 2005 cash was primarily used to
fund exploration and development expenditures. We had a net increase in cash and
cash equivalents of $7,863,277 during the current fiscal year. See below for
additional discussion and analysis of cash flow.
Period from inception
Twelve months ended (May 6, 2003) through
March 31, 2005 March 31, 2004
------------------- ---------------------
Net cash used in operating activities $ (1,415,004) $(3,445,339)
Net cash used in investing activities $(18,001,879) $(6,564,180)
Net cash provided by financing activities $ 27,280,160 $12,135,874
------------------ ------------------------
NET INCREASE IN CASH AND CASH EQUIVALENTS $7,863,277 $ 2,126,355
================== ========================
23
Our primary source of cash has been cash flows from equity offerings.
During the fiscal year ended March 31, 2005 we realized $27,280,160 from the
sale of our common stock. We primarily used this cash to fund our capital
expenditures. At March 31, 2005 we had cash on hand of $9,989,632.
We continually evaluate our capital needs and compare them to our
capital resources. Our budgeted capital expenditures for the upcoming 12 months
are $10 million to $14 million for exploration, development, production and
acquisitions. We expect to fund these expenditures primarily from additional
capital we will seek and cash on hand. In the event we are not successful in
raising the anticipated funds from the sale of our securities, we nevertheless
believe capital expenditures of approximately $10 million to $14 million could
be financed through cash on hand, the sale of marketable securities and revenues
from anticipated oil production. The minimum level of capital expenditures on
our properties is dictated by the contract. The amount of funds we devote to any
particular activity in excess of the minimum required capital expenditures may
increase or decrease significantly depending on available opportunities, cash
flows and development results, among others.
If we are not successful in obtaining funding, we anticipate that we
will instead seek to develop existing wells and infrastructure in hopes of
generating sufficient revenue to finance our operations. This development would
be funded by cash and cash equivalents and the sale of marketable securities we
currently hold. If the funding is limited to these sources, our anticipated
development activities would be significantly more limited than anticipated
under our present business plan.
As discussed in Note 2 to the Consolidated Financial Statements, we
hold marketable securities consisting of short-term repurchase agreements for
securities issued by Kazakhstan banks and Kazakhstan financial institutions.
Additionally, 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. As more fully disclosed in the "Risks of Doing Business in
Kazakhstan" section of the "Business and Properties" because of the potential
for civil unrest, war and asset expropriation, some or all of these matters,
which impact operating cash flow, may affect our ability to meet our short-term
cash needs.
Contractual Obligations and Contingencies
The following table lists our significant commitments at March 31,
2005, excluding current liabilities as listed on our consolidated balance sheet:
24
Payments Due By Period
--------------------------------------------------------------------------
Contractual obligations Total Less than 1 1-3 years 4-5 years After 5
year years
--------------- -------------- --------------- -------------- ------------
Capital Expenditure $19,800,000 $9,300,000 $10,500,000 - -
Commitment(1)
Due to the Government of
the Republic of Kazakhstan(2)(3) $ 5,994,200 - $ 5,994,200 - -
Due to Reservoir Consultants $ 500,000 $ 278,000 $ 222,000 - -
Liquidation Fund $ 60,973 - - - $60,973
- ---------------------
(1) Under the terms of our contract with the ROK, we are required to spend a
total of at least $19.8 million dollars in exploration, development and
improvements within the ADE Block, as extended during the term of the
license, including $9.3 million in the 2005 calendar year, $6 million in the
2006 calendar year and $4.5 million in the 2007 calendar year. If we fail to
do so, we may be subject to the loss of our exploration license.
(2) In connection with our acquisition of the oil and gas contract covering the
ADE Block, we are required to repay the ROK for historical costs incurred by
it in undertaking geological and geophysical studies and infrastructure
improvements. The repayment terms of this obligation will not be determined
until such time as we apply for and are granted commercial production rights
by the ROK. Under our contract, if we wish to commence commercial
production, we must apply for such right prior to the expiration of our
exploration and development rights in June 2007. We are legally entitled to
receive commercial production rights and have the exclusive right to
negotiate such with the ROK, and the ROK is required to conduct the
negotiations under the Law of Petroleum in Kazakhstan. Although we can apply
for commercial production rights at any time, we enjoy certain benefits
under our contract that currently make it more economically advantageous for
us to continue exploration and development activities at this time. We
anticipate that we will apply for commercial production rights sometime
during the first half of the 2007 calendar year. Should we decide not to
pursue a commercial production contract, we can relinquish the ADE Block to
the ROK in satisfaction of this obligation.
(3) As with the ADE Block, we will also be required to repay the ROK its
historical costs for access to and use of geological and geophysical data
gathered and infrastructure improvement previously made by the ROK within
the Extended Territory. We are presently negotiating the amount and terms of
this obligation with the ROK. This approximately $6 million obligation
represents only our repayment obligation with respect to the ADE Block, and
not the extended territory.
Off-Balance Sheet Financing Arrangements
As of March 31, 2005, we had no off-balance sheet financing
arrangements.
Critical Accounting Policies
We have identified the policies below as critical to our business
operations and the understanding of our financial statements. The impact of
these policies and associated risks are discussed throughout Management's
Discussion and Analysis and Plan of Operations where such policies affect our
reported and expected financial results. A complete discussion of our accounting
policies in included in Note 2 of the Notes to Consolidated Financial
Statements.
Development Stage
We are a development stage company and have not yet commenced our
primary revenue generating activities, which is the commercial production and
sale of oil and natural gas. Our ability to realize the carrying value of our
25
assets is dependent on being able to produce and sell oil from our properties.
Our Consolidated Financial Statements have been presented on the basis that we
are a going concern, which contemplates the realization of assets and
satisfaction of liabilities in the normal course of business. We have
accumulated losses totaling $3,900,094 and have incurred some amount of debt in
the development phase of our operations. To fully develop our properties and
achieve positive cash flow, we will require additional funding. The Consolidated
Financial Statements do not include any adjustments relating to the
recoverability and classification of recorded asset amounts or amounts and
classification of liabilities which might be necessary should we be unable to
continue in existence.
Foreign Exchange Transactions
Transactions denominated in foreign currencies are reported at the
rates of exchange prevailing at the date of the transaction. Monetary assets and
liabilities denominated in foreign currencies are translated to U.S. dollar at
the rates of exchange prevailing at the balance sheet dates. Any gains or losses
arising from a change in exchange rates subsequent to the date of the
transaction are included as an exchange gain or loss in the Consolidated
Statements of Income.
Full Cost Method of Accounting
We follow the full cost method of accounting for our costs of
acquisition, exploration and development of oil and gas properties.
Under full cost accounting rules, the net capitalized costs of
evaluated oil and gas properties shall not exceed an amount equal to the present
value of future net cash flows from estimated production of proved oil and gas
reserves, based on current economic and operating conditions, including the use
of oil and gas prices as of the end of each quarter.
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.
Recently Issued Accounting Pronouncements
In June 2004, the FASB issued an exposure draft of a proposed
statement, "Fair Value Measurements" to provide guidance on how to measure the
fair value of financial and non-financial assets and liabilities when required
by other authoritative accounting pronouncements. The proposed statement
attempts to address concerns about the ability to develop reliable estimates of
fair value and inconsistencies in fair value guidance provided by current U.S.
GAAP, by creating a framework that clarifies the fair value objective and its
application in GAAP. In addition, the proposal expands disclosures required
about the use of fair value to re-measure assets and liabilities. The standard
26
would be effective for financial statements issued for fiscal years beginning
after June 15, 2005. We are reviewing The Exposure Draft to determine the
potential impact, if any, on our Consolidated Financial Statements.
In November 2004, the EITF ratified Issue No. 03-13, "Applying the
Conditions in Paragraph 42 of FASB Statement No.144, Accounting for the
Impairment or Disposal of Long-Lived Assets, in Determining Whether to Report
Discontinued Operations." The EITF reached a consensus that classification of a
disposed of or held-for-sale component as a discontinued operation is only
appropriate if the ongoing entity (i) expects to have no continuing "direct"
cash flows, and (ii) does not retain or expect to retain an interest, contract
or other arrangement sufficient to enable it to exert significant influence over
the disposed component's operating and financial policies after the disposal
transaction. Application of this consensus did not have a material impact on our
Consolidated Financial Statements.
In December 2004, the FASB issued Statement 153, "Exchanges of
Non-monetary Assets," an amendment of APB Opinion 29, Accounting for
Non-monetary Transactions. This amendment eliminates the exception for
non-monetary exchanges of similar productive assets and replaces it with a
general exception for exchanges of non-monetary assets that do not have
commercial substance. Under Statement 153, if a non-monetary exchange of similar
productive assets meets a commercial-substance criterion and fair value is
determinable, the transaction must be accounted for at fair value resulting in
recognition of any gain or loss. This statement is effective for non-monetary
transactions in fiscal periods that begin after June 15, 2005 and will not
impact our financial position or results of operations, and cash flows.
In December 2004, the FASB issued a revision of SFAS No. 123
"Share-Based Payment" (No. 123R). The statement establishes standards for the
accounting for transactions in which an entity exchanges its equity investments
for goods and services. It also addresses transactions in which an entity incurs
liabilities in exchange for goods or services that are based on the fair value
of the entity's equity instruments or that may be settled by the issuance of
those equity instruments. The statement does not change the accounting guidance
for share-based payments with parties other than employees. The statement
requires a public entity to measure the cost of employee service received in
exchange for an award of equity instruments based on the grant-date fair value
of the award (with limited exception). That cost will be recognized over the
period during which an employee is required to provide service in exchange for
the award (usually the vesting period). A public entity will initially measure
the cost of employee services received in exchange for an award of a liability
instrument based on its current fair value; the fair value of that award will be
remeasured subsequently at each reporting date through the settlement date.
Changes in fair value during the requisite service period will be recognized as
compensation over that period. The grant-date for fair value of employee share
options and similar instruments will be estimated using option-pricing models
adjusted for the unique characteristics of these instruments. We will be
required to comply with this pronouncement for periods beginning after December
15, 2005.
27
Effects of Inflation and Pricing
The oil and natural gas industry is very cyclical and the demand for
goods and services of oil field companies, suppliers and others associated with
the industry puts extreme pressure on the economic stability and pricing
structure within the industry. Typically, as prices for oil and natural gas
increase, so do all associated costs. Material changes in prices impact the
current revenue stream, estimates of future reserves, borrowing base
calculations of bank loans and value of properties in purchase and sale
transactions. Material changes in prices can impact the value of oil and natural
gas companies and their ability to raise capital, borrow money and retain
personnel. While we do not currently expect business costs to materially
increase, continued high prices for oil and natural gas could result in
increases in the cost of material, services and personnel.
Item 7. Financial Statements
See Consolidated Financial Statement listed in the accompanying index
to the Consolidated Financial Statements on Page F-1 herein.
Item 8A. Controls and Procedures
Our chief executive officer and our chief financial officer (the
"Certifying Officers") are responsible for establishing and maintaining
disclosure controls and procedures (as defined in Exchange Act Rule 13a-15 and
Rule 15d-15(e)). Such officers have concluded (based upon their evaluations of
these controls and procedures as of the end of the period covered by this
report) that our disclosure controls and procedures are effective to ensure that
information required to be disclosed by us in this report is accumulated and
communicated to management, including the Certifying Officers as appropriate, to
allow timely decisions regarding required disclosure.
In response to comments raised by the staff of the Securities and
Exchange Commission ("SEC") in connection with its review of the SB-2
registration statement filed by us in October 2005, the SEC petroleum
engineering staff conducted a review of our estimates of proved reserves, which
were the proved reserves we provided in our Form 10-KSB annual report for 2005.
Our statement of estimated proved reserves was based upon an evaluation
conducted by Chapman Petroleum Engineering, Ltd., an independent third-party
petroleum engineering firm in Calgary, Canada ("Chapman Petroleum"). Based on
the staff's comments, the Company and Chapman Petroleum commenced a review of
the estimated proved reserves evaluation contained in the Reserve and Economic
Evaluation prepared by Chapman Petroleum as of April 1, 2005 (the "Chapman
Report.") In our Form 10-KSB annual report, we disclosed estimated proved
reserves of oil and natural gas totaling 40,914 MBbls BOE. Following the review
of the Chapman Petroleum report by us and Chapman, it was determined that the
28
estimated proved reserves of oil and natural gas as of March 31, 2005, will be
revised to 13,160 MBbls BOE under the SEC reporting standards. Based on this
review and after consultation with the Audit Committee of our Board of Directors
and our independent registered public accounting firm, on March 22, 2006, we
concluded that our audited consolidated financial statements for the year ended
March 31, 2005, and the unaudited consolidated financial statements for the
quarterly periods ended June 30, 2005, September 30, 2005 and December 31, 2005
required restatement in those periods relating to our calculation of depletion.
The change in estimated proved reserves directly effects the calculation of
depletion.
In light of our determination that the restatement of our proved
reserves as contained in the Chapman Report resulted in the need to restate the
financial statements contained in our annual report for the year ended March 31,
2005 and the quarterly reports for the quarters ended June 30, 2005, September
30, 2005 and December 31, 2005, we carried out an evaluation in accordance with
Exchange Act Rules 13a-15 and 15d-15 and under the supervision and with the
participation of management, including our Certifying Officers, of the
effectiveness of our disclosure controls and procedures as of the end of the
period covered by this report. We have evaluated the accounting procedures and
controls in place and determined that the accounting for depletion was properly
carried out based on the proved reserves figures contained in the original
Chapman Report. We have evaluated the process by which management selected
Chapman Petroleum to perform the independent evaluation of our reserves and
determined that management performed proper and adequate due diligence to
investigate and assess the qualifications, expertise and ability of Chapman
Petroleum to perform the independent evaluation of our petroleum reserves to the
applicable SEC reporting standards. We have evaluated our communications with
Chapman Petroleum and determined that the scope and purpose for which Chapman
Petroleum was retained to evaluate our reserves was clearly and appropriately
communicated to Chapman Petroleum. We have undertaken an investigation to
confirm that information provided by us to Chapman Petroleum was correct. We
have also investigated to determine whether we have certain policies in place,
such as performance based compensation tied to reserve balances, which could
have resulted in undue pressure to inflate proved reserves and determined that
we had and have no such policies in place. Based on this evaluation, our
Certifying Officers have concluded that the restatement of our financial
statements resulting from the restatement of our proved reserves contained in
the Chapman Report was not the result of ineffective disclosure controls and
procedures.
There have been no changes in our internal controls over financial
reporting that occurred during the year ended March 31, 2005.
Item 13. Exhibits
Exhibits. The following exhibits are included as part of this report:
Exhibit 23.1 Consent of Chapman Petroleum Engineering
Ltd., Independent Petroleum Engineers
Exhibit 31.1 Certification of Principal Executive Officer
Pursuant to Section 302 of the
Sarbanes-Oxley Act of 2002
29
Exhibit 31.2 Certification of Principal Financial Officer
Pursuant to Section 302 of the
Sarbanes-Oxley Act of 2002
Exhibit 32.1 Certification of Principal Executive Officer
Pursuant to Section 906 of the
Sarbanes-Oxley Act of 2002
Exhibit 32.2 Certification of Principal Financial Officer
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 registration statement to be signed on its behalf,
thereunto duly authorized.
BMB MUNAI, INC.
Date: April 12, 2006 /s/ Boris Cherdabayev
-------------------------------------------
Boris Cherdabayev, Chief Executive Officer
and Director
Date: April 12, 2006 /s/ Sanat Kasymov
-------------------------------------------
Sanat Kasymov, Chief Financial Officer
Date: April 12, 2006 /s/ Georges Benarroch
-------------------------------------------
Georges Benarroch, Director
Date: April 12, 2006 /s/ Troy Nilson
-------------------------------------------
Troy Nilson, Director
Date: April 12, 2006 /s/ Stephen Smoot
-------------------------------------------
Stephen Smoot, Director
Date: April 12, 2006 /s/ Valery Tolkachev
-------------------------------------------
Valery Tolkachev, Director
30
BMB MUNAI, INC
(A DEVELOPMENT STAGE ENTITY)
CONSOLIDATED FINANCIAL STATEMENTS
For the year ended March 31, 2005
TABLE OF CONTENTS
- --------------------------------------------------------------------------------
Page
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM F-1
CONSOLIDATED FINANCIAL STATEMENTS FOR THE YEAR ENDED MARCH 31, 2005
Consolidated Balance Sheet F-2
Consolidated Statements of Loss F-3
Consolidated Statements of Shareholders' Equity F-4
Consolidated Statements of Cash Flow F-5
Notes to Consolidated Financial Statements F-6 - F-27
Report of Independent Registered Public Accounting Firm
The Board of Directors
BMB Munai, Inc.
We have audited the accompanying consolidated balance sheet of "BMB Munai" Inc.
(a company in the development stage) as of March 31, 2005, and the related
consolidated statements of loss, shareholders' equity, and cash flows for the
year ended March 31, 2005 and for the period from inception (May 6, 2003)
through March 31, 2004. These financial statements are the responsibility of the
Company's management. Our responsibility is to express an opinion on these
financial statements based on our audit.
We conducted an audit in accordance with the Standards of the Public Company
Accounting Oversight Board (United States). Those standards require that we plan
and perform the audit to obtain reasonable assurance about whether the financial
statements are free of material misstatements. The Company is not required to
have, nor were we engaged to perform, an audit of its internal control over
financial reporting. Our audit included consideration of internal control over
financial reporting as a basis for designing audit procedures that are
appropriate in the circumstances, but not for purposes of expressing an opinion
on the effectiveness of the Company's internal control over financial reporting.
Accordingly, we express no such opinion. An audit also includes examining, on a
test basis, evidence supporting the amounts and disclosures in the financial
statements, assessing the accounting principles used and significant estimates
made by management, as well as evaluating the overall financial statement
presentation. We believe that our audit provides reasonable basis for our
opinion.
In our opinion, the financial statements referred to above present fairly, in
all material respects, the consolidated financial position of BMB Munai, Inc. at
March 31, 2005 and the consolidated results of its operations and its cash flow
for the period from inception (May 6, 2003) through March 31, 2005 in conformity
with accounting principles generally accepted in the United States of America.
As discussed in Note 23, the accompanying consolidated financial statements as
of and for the year ended March 31, 2005, and for the period from inception (May
6, 2003) through March 31, 2005, have been restated to correct errors in the
accounting for oil and gas properties.
/s/ BDO Kazakhstanaudit, LLP
June 13, 2005, except for Note 23, which date is
as of April 12, 2006 Almaty, Kazakhstan
F-1
BMB MUNAI, INC
(A DEVELOPMENT STAGE ENTITY)
CONSOLIDATED BALANCE SHEET
AS OF MARCH 31
- ----------------------------------------------------------------------------------------------------------
Notes 2005
(Restated)
ASSETS
CURRENT ASSETS
Cash and cash equivalents 6 $ 9,989,632
Marketable securities 7 788,921
Trade accounts receivable 132,400
Inventories 8 3,227,411
Prepaid expenses, net 9 4,172,291
------------
Total current assets 18,310,655
------------
NON-CURRENT ASSETS
Oil and gas properties, full cost method, net 11 42,802,405
Other fixed assets, net 12 683,459
Intangible assets, net 13 14,435
Restricted cash 14 60,973
------------
Total non-current assets 43,561,272
------------
TOTAL ASSETS $ 61,871,927
============
LIABILITIES AND SHAREHOLDERS' EQUITY
CURRENT LIABILITIES
Accounts payable 18 $ 5,844,639
Due to reservoir consultants 14 278,000
Taxes payable 333,063
Due to Astana Fund 10 250,000
Accrued liabilities and other payables 291,969
------------
Total current liabilities 6,997,671
------------
LONG TERM LIABILITIES
Due to reservoir consultants 14 222,000
Liquidation fund 14 60,973
Deferred income tax liabilities 5 343
------------
Total long term liabilities 283,316
------------
COMMITMENTS AND CONTINGENCIES 19 -
SHAREHOLDERS' EQUITY
Share capital 16 30,514
Additional paid-in capital 16 58,460,520
Deficit accumulated during the development stage (3,900,094)
------------
Total shareholders' equity 54,590,940
------------
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY $ 61,871,927
============
See notes to the consolidated financial statements.
F-2
BMB MUNAI, INC
(A DEVELOPMENT STAGE ENTITY)
CONSOLIDATED STATEMENTS OF LOSS
- ---------------------------------------------------------------------------------------------------------------------------
Period from
Period from inception
inception (May 6, 2003)
Year ended March (May 6, 2003) through
Notes 31, 2005 through March 31, 2005
(Restated) March 31, 2004 (Restated)
REVENUES 4 $ 973,646 $ - $ 973,646
EXPENSES
Production 427,103 - 427,103
Selling 206,929 - 206,929
General and administrative 4,060,962 781,757 4,842,719
Amortization and depreciation 66,451 4,758 71,209
------------------ ------------------ ------------------
Total expenses 4,761,445 786,515 5,547,960
------------------ ------------------ ------------------
LOSS FROM OPERATIONS (3,787,799) (786,515) (4,574,314)
OTHER INCOME (EXPENSE)
Realized gain on marketable securities 185,067 19,368 204,435
Unrealized gain (loss) on marketable
securities (252,767) 248,407 (4,360)
Foreign exchange gain, net 499,521 70,949 570,470
Interest income, net 17,799 (84,007) (66,208)
Other income, net 52,210 - 52,210
------------------ ------------------ ------------------
Total other income (expenses) 501,830 254,717 756,547
------------------ ------------------ ------------------
LOSS BEFORE INCOME TAXES (3,285,969) (531,798) (3,817,767)
INCOME TAX EXPENSE 5 (343) - (343)
------------------ ------------------ ------------------
LOSS BEFORE MINORITY INTEREST (3,286,312) (531,798) (3,818,110)
MINORITY INTEREST 15 - (81,984) (81,984)
------------------ ------------------ ------------------
NET LOSS $ (3,286,312) $ (613,782) $ (3,900,094)
================== ================== ==================
WEIGHT AVERAGE COMMON SHARES OUTSTANDING
17 26,948,437 7,398,240
LOSS PER COMMON SHARE (BASIC AND DILUTED)
17 $ 0.122 $ 0.083
================== ==================
See notes to the consolidated financial statements.
F-3
BMB MUNAI, INC
(A DEVELOPMENT STAGE ENTITY)
CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY
- --------------------------------------------------------------------------------------------------------------------------------
Notes Number of Share capital Additional Deficit Total
shares paid-in accumulated
capital during the
development
stage
-------------- -------------- --------------- --------------- ----------------
At May 6, 2003 (Inception date) 491,655 $ 492 $ (492) $ - $ -
Stock dividends 50,000 50 (50) - -
Common stock issued during
the merger 14,285,844 14,286 (14,286) - -
Conversion of debt to common
stock 571,428 571 1,999,429 - 2,000,000
Common stock issued in
private placement 4,830,494 4,830 9,931,044 - 9,935,874
Options exercised 200,000 200 199,800 - 200,000
Net loss for the period - - - (613,782) (613,782)
-------------- -------------- --------------- --------------- ----------------
At March 31, 2004 20,429,421 20,429 12,115,445 (613,782) 11,522,092
Common stock issued in
exchange of 30% shares of
Emir Oil LLC 16 3,500,000 3,500 19,071,500 - 19,075,000
Common stock issued in
private placement 16 6,584,340 6,585 27,273,575 - 27,280,160
Common stock issued for
subscription 16 1,101,000 1,101 5,503,899 - 5,505,000
Subscription receivable 16 (1,101,000) (1,101) (5,503,899) - (5,505,000)
Net loss for the year - - - (3,286,312) (3,286,312)
(Restated)
-------------- -------------- --------------- --------------- ----------------
At March 31, 2005 30,513,761 $ 30,514 $ 58,460,520 $ (3,900,094) $ 54,590,940
============== ============== =============== =============== ================
See notes to the consolidated financial statements.
F-4
BMB MUNAI, INC
(A DEVELOPMENT STAGE ENTITY)
CONSOLIDATED STATEMENTS OF CASH FLOW
- ---------------------------------------------------------------------------------------------------------------------------
Period from Period from
inception inception
(May 6, 2003) (May 6, 2003)
Year ended through through
Notes March 31, 2005 March 31, 2004 March 31, 2005
(Restated) (Restated)
CASH FLOWS FROM OPERATING ACTIVITIES
Net loss $ (3,286,312) $ (613,782) $ (3,900,094)
Adjustments to reconcile net loss to net cash used in
operating activities:
Depreciation, depletion and amortisation 295,857 4,758 300,615
Provision for doubtful accounts 129,051 - 129,051
Minority interest 15 (82,134) 82,134 -
Deferred income tax liabilities 5 343 - 343
Unrealized gain on dealing securities 252,767 (248,407) 4,360
Changes in operating assets and liabilities
Decrease / (increase) in dealing securities 1,837,448 (2,630,729) (793,281)
Increase in accounts receivable (132,400) - (132,400)
Increase in inventories (3,043,527) (183,884) (3,227,411)
Increase in prepaid expenses (3,758,022) (522,148) (4,280,170)
Increase in accounts payable and other accruals 6,371,925 750,726 7,122,651
---------------- ---------------- ---------------
Net cash used in operations (1,415,004) (3,361,332) (4,776,336)
Interest paid - (84,007) (84,007)
---------------- ---------------- ---------------
Net cash used in operating activities (1,415,004) (3,445,339) (4,860,343)
---------------- ---------------- ---------------
CASH FLOWS FROM INVESTING ACTIVITIES
Acquisition of oil and gas properties (17,411,861) (6,253,186) (23,665,047)
Acquisition of other fixed assets (536,700) (264,411) (801,111)
Acquisition of intangible assets (12,345) (5,411) (17,756)
Restricted cash (40,973) (20,000) (60,973)
Deposits - (21,172) (21,172)
---------------- ---------------- ---------------
Net cash used in investing activities (18,001,879) (6,564,180) (24,566,059)
---------------- ---------------- ---------------
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from sale of common stock 16 27,280,160 9,935,874 37,216,034
Proceeds from short-term financing - 500,000 500,000
Repayment of short-term financing - (500,000) (500,000)
Proceeds from issuance of convertible debt - 2,000,000 2,000,000
Proceeds from exercise of common stock options - 200,000 200,000
---------------- ---------------- ---------------
Net cash provided by financing activities 27,280,160 12,135,874 39,416,034
---------------- ---------------- ---------------
NET CHANGE IN CASH AND CASH EQUIVALENTS 7,863,277 2,126,355 9,989,632
CASH AND CASH EQUIVALENTS at beginning of year 2,126,355 - -
---------------- ---------------- ---------------
CASH AND CASH EQUIVALENTS at end of year 6 $ 9,989,632 $ 2,126,355 $ 9,989,632
================ ================ ===============
Non cash transactions:
Conversion of debt into common stock 16 $ - $ 2,000,000
Accrual of liabilities to Astana Fund 10 $ 250,000 $ -
Acquisition of 30% of Emir Oil LLP by issuance of
3,500,000 shares of common stock 16 $ 19,075,000 $ -
See notes to the consolidated financial statements.
F-5
BMB MUNAI, INC
(A DEVELOPMENT STAGE ENTITY)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2005
- --------------------------------------------------------------------------------
1. DESCRIPTION OF BUSINESS
BMB Munai, Inc. (the "Company") was incorporated in Utah in July 1981. The
Company later changed domicile to Delaware on February 7, 1994. Prior to
November 26, 2003, the Company existed under the name InterUnion Financial
Corporation ("InterUnion"). The Company changed domicile from Delaware to
Nevada in December 2004.
On November 26, 2003, InterUnion executed an Agreement and Plan of Merger
(the "Agreement") with BMB Holding, Inc ("BMB"), a private Delaware
corporation, formed for the purpose of acquiring and developing oil and
gas fields in the Republic of Kazakhstan. As a result of the merger, the
shareholders of BMB have obtained control of the Company. BMB was treated
as the acquiror for accounting purposes. A new board of directors was
elected that is comprised primarily of the former directors of BMB
Holding, Inc.
The Company's financial statements presented are a continuation of BMB,
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 owns one hundred percent (100%) interest in Emir Oil LLP
("Emir Oil" or "Emir"). Emir Oil is a Limited Liability Partnership formed
under the laws of the Republic of Kazakhstan for the sole purpose of
acquiring the oil and gas exploration license AI No. 1552 (the "License")
and Contract No. 482 for Exploration of Hydrocarbons in
Aksaz-Dolinnoe-Emir oil fields, located in blocks XXXVI-10-C (Partially),
F (Partially) XXXVI-11-A (Partially),
D n (Partially) (the "Contract"), in the Republic of Kazakhstan.
The Company has a Representative office in Almaty, the Republic of
Kazakhstan.
The Company has minimal operations to date and is considered to be in the
development stage. The Company began test production at one well in May
2004 and at two wells in December 2004. In the first quarter of 2005 the
Company completed drilling of one well.
2. SIGNIFICANT ACCOUNTING POLICIES
Basis of consolidation
The Company's consolidated financial statements present the consolidated
results of BMB Munai, Inc., and Emir Oil LLP, its 100% owned subsidiary
(hereinafter collectively referred to as the "Company"). All significant
inter-company balances and transactions have been eliminated from the
Consolidated Financial Statements.
Emir Oil has a fiscal year ending December 31, which is different from
Company's fiscal year end. All transactions of Emir Oil from the date of
its purchase by BMB (June 7, 2003) through March 31, 2005 are reflected in
the Consolidated Financial Statements and Notes to the Consolidated
Financial Statements.
These consolidated financial statements are prepared in accordance with
United States Generally Accepted Accounting Principles ("US GAAP").
F-6
BMB MUNAI, INC
(A DEVELOPMENT STAGE ENTITY)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2005
- --------------------------------------------------------------------------------
Emir Oil maintains its accounting records in Kazakhstan Tenge and prepares
separate statutory financial statements in accordance with accounting
legislation in the Republic of Kazakhstan. Statutory accounting principles
and procedures in Kazakhstan differ from accounting principles generally
accepted under US GAAP. Accordingly, the accompanying Consolidated
Financial Statements, which include Emir Oil's statutory accounting
records, reflect adjustments necessary for such financial statements to be
presented in accordance with US GAAP.
Use of estimates
The preparation of financial statements in conformity with US GAAP
requires management to make estimates and assumptions that affect certain
reported amounts of assets and liabilities and the disclosures of
contingent assets and liabilities at the date of the Consolidated
Financial Statements and revenues and expenses during the reporting
period. Accordingly, actual results could differ from those estimates and
affect the results reported in these Consolidated Financial Statements.
Licences and contracts
Emir Oil is the operator of the Aksaz, Dolinnoe and Emir oil and gas
fields in western Kazakhstan (the "ADE Block", the "ADE Fields"). The
Government of the Republic of Kazakhstan (the "Government") initially
issued the license to Zhanaozen Repair and Mechanical Plant on April 30,
1999. On September 23, 2002, the license was assigned to Emir Oil. 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. On September
10, 2004 the Government extended duration of the Contract for exploration
and License for seven years to June 9, 2007. On December 7, 2004 the
Government assigned to Emir Oil exclusive right to explore the additional
territory during the remaining term of the License. The Company is legally
entitled to receive this commercial production contract and has an
exclusive right to negotiate this Contract and the Government is obligated
to conduct these negotiations under the Law of Petroleum in Kazakhstan. If
no terms can be negotiated, the Company has a right to produce and sell
oil, including export oil, under the Law of Petroleum for the term of its
existing contract through June 9, 2007.
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 U.S.
dollar at the rates of exchange prevailing at the balance sheet dates. Any
gains or losses arising from a change in exchange rates subsequent to the
date of the transaction are included as an exchange gain or loss in the
Consolidated Statements of Income.
Share-Based Compensation
The Company accounts for options granted to non-employees at their fair
value in accordance with FAS 123, Accounting for Stock-Based Compensation.
Under FAS No. 123, stock-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 were granted
to the "selling agents" in the private equity placement transactions and
have been offset to the proceeds as a cost of capital.
F-7
BMB MUNAI, INC
(A DEVELOPMENT STAGE ENTITY)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2005
- --------------------------------------------------------------------------------
The Company has a stock option plan as described in Note 16. Compensation
expense for options granted to employees is determined based on their fair
values at the time of grant, the cost of which is recognized in the
Consolidated Statement of Income over the vesting periods of the
respective options.
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 might not permit
world market price to be obtained. However, management believes that over
the life of the project, transportation options will be improved by
further increases in the capacity of the transportation options.
Recognition of revenue and cost
Revenue and associated costs from the sale of oil are charged to the
period when goods were shipped or when ownership title transferred.
Produced but unsold products are recorded as inventory until sold. As of
March 31, 2005 the production unit of the Company - Emir Oil had test
production sales at Kazakhstan domestic market price which is considerably
lower than world market prices.
Income taxes
The Company accounts for income taxes using the liability method. Under
the liability method, deferred tax assets and liabilities are recognized
for the future tax consequences attributable to differences between
financial statement carrying amounts of existing assets and liabilities
and their respective tax bases. Deferred tax assets and liabilities are
measured using enacted tax rates expected to apply to taxable income in
the years in which those temporary differences are expected to be
recovered or settled. Under the liability method, the effect on previously
recorded deferred tax assets and liabilities resulting from a change in
tax rates is recognized in earnings in the period in which the change is
enacted.
Cash and cash equivalents
The Company considers all demand deposits and money market accounts
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.
Marketable securities
Marketable securities consist of short term repurchase agreements for
securities issued by Kazakhstan banks and Kazakhstan financial
institutions. The Company records these marketable securities as trading
securities and any change in the fair market value is recorded in
earnings.
Trade accounts receivable and prepaid expenses
Accounts receivable and prepaid expenses are stated at their net
realizable values after deducting provisions for uncollectable amounts.
Such provisions reflect either specific cases or estimates based on
evidence of collectability. The fair value of accounts receivable and
prepaid expense accounts approximates their carrying amounts due to their
short-term maturity.
F-8
BMB MUNAI, INC
(A DEVELOPMENT STAGE ENTITY)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2005
- --------------------------------------------------------------------------------
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 and net
realizable value. Cost comprises direct materials and, where applicable,
direct labour costs and those overheads, which have 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.
Oil and gas properties
The Company follows the full cost method of accounting for its costs of
acquisition, exploration and development of oil and gas properties.
Under full cost accounting rules, the net capitalized costs of evaluated
oil and gas properties shall not exceed an amount equal to the present
value of future net cash flows from estimated production of proved oil and
gas reserves, based on current economic and operating conditions,
including the use of oil and gas prices as of the end of each quarter.
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 ADE Block 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 under this method of accounting.
Costs of acquiring unproved leases shall be evaluated for impairment until
such time as the leases are proved or abandoned. In addition, if the sums
of expected undiscounted cash flows are less than net book value,
unamortized costs at the field level will be reduced to a fair value.
Depreciation, depletion and amortization of producing properties is
computed using the unit-of-production method based on estimated proved
recoverable reserves.
Other fixed assets
Other fixed assets are valued at the historical cost adjusted for
impairment loss less accumulated depreciation. Historical cost includes
all direct costs associated with the acquisition of the fixed assets.
F-9
BMB MUNAI, INC
(A DEVELOPMENT STAGE ENTITY)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2005
- --------------------------------------------------------------------------------
Depreciation of other fixed assets is calculated using the straight line
method based upon the following estimated useful lives:
Constructions 7-10 years
Machinery and equipment 6-10 years
Vehicles 3-5 years
Office equipment 3-5 years
Other 2-7 years
Maintenance and repairs is charged to expenses as incurred. Renewals and
betterments are capitalized.
Other fixed assets of the Company are evaluated for impairment. If the
sums of expected undiscounted cash flows are less than net book value,
unamortized costs of other fixed assets will be reduced to a fair value.
Intangible assets
Intangible assets include accounting and other software. Amortization of
intangible assets is calculated using straight line method upon estimated
useful life ranging from 3 to 4 years.
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. The fair value of these funds
approximates their carrying amounts as amount and conditions of deposited
funds governed by the Government of the Republic of Kazakhstan (see Note
14).
Comparative figures
The presentation of certain amounts for previous year has been
reclassified to conform to the presentation adopted for the current year.
Recent accounting pronouncements
In June 2004, the FASB issued an exposure draft of a proposed statement,
"Fair Value Measurements" to provide guidance on how to measure the fair
value of financial and non-financial assets and liabilities when required
by other authoritative accounting pronouncements. The proposed statement
attempts to address concerns about the ability to develop reliable
estimates of fair value and inconsistencies in fair value guidance
provided by current US GAAP, by creating a framework that clarifies the
fair value objective and its application in GAAP. In addition, the
proposal expands disclosures required about the use of fair value to
re-measure assets and liabilities. The standard would be effective for
financial statements issued for fiscal years beginning after June 15,
2005. The Company is reviewing The Exposure Draft to determine the
potential impact, if any, on its Consolidated Financial Statements.
F-10
BMB MUNAI, INC
(A DEVELOPMENT STAGE ENTITY)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2005
- --------------------------------------------------------------------------------
In November 2004, the EITF ratified Issue No. 03-13, "Applying the
Conditions in Paragraph 42 of FASB Statement No.144, Accounting for the
Impairment or Disposal of Long-Lived Assets, in Determining Whether to
Report Discontinued Operations." The EITF reached a consensus that
classification of a disposed of or held-for-sale component as a
discontinued operation is only appropriate if the ongoing entity (i)
expects to have no continuing "direct" cash flows, and (ii) does not
retain or expect to retain an interest, contract or other arrangement
sufficient to enable it to exert significant influence over the disposed
component's operating and financial policies after the disposal
transaction. Application of this consensus did not have a material impact
on the Company's Consolidated Financial Statements.
In December 2004, the FASB issued Statement 153, "Exchanges of
Non-monetary Assets", an amendment of APB Opinion 29, "Accounting for
Non-monetary Transactions." This amendment eliminates the exception for
non-monetary exchanges of similar productive assets and replaces it with a
general exception for exchanges of non-monetary assets that do not have
commercial substance. Under Statement 153, if a non-monetary exchange of
similar productive assets meets a commercial-substance criterion and fair
value is determinable, the transaction must be accounted for at fair value
resulting in recognition of any gain or loss. This statement is effective
for non-monetary transactions in fiscal periods that begin after June 15,
2005 and will not impact the Company's financial position or results of
operations, and cash flows.
In December 2004, the FASB issued a revision of SFAS No. 123 "Share-Based
Payment" (No. 123R). The statement establishes standards for the
accounting for transactions in which an entity exchanges its equity
investments for goods and services. It also addresses transactions in
which an entity incurs liabilities in exchange for goods or services that
are based on the fair value of the entity's equity instruments or that may
be settled by the issuance of those equity instruments. The statement does
not change the accounting guidance for share-based payments with parties
other than employees. The statement requires a public entity to measure
the cost of employee service received in exchange for an award of equity
instruments based on the grant-date fair value of the award (with limited
exception). That cost will be recognized over the period during which an
employee is required to provide service in exchange for the award (usually
the vesting period). A public entity will initially measure the cost of
employee services received in exchange for an award of a liability
instrument based on its current fair value; the fair value of that award
will be remeasured subsequently at each reporting date through the
settlement date. Changes in fair value during the requisite service period
will be recognized as compensation over that period. The grant-date for
fair value of employee share options and similar instruments will be
estimated using option-pricing models adjusted for the unique
characteristics of these instruments. The Company will be required to
comply with this pronouncement for periods beginning after December 15,
2005.
3. ACQUISITION
On June 7, 2003, BMB acquired a 70% equity interest in Emir Oil for
$1,300,000. On May 24, 2004, the Company agreed to purchase the remaining
30% interest of its minority interest partner in Emir Oil in exchange for
3,500,000 shares of restricted Company common stock. On August 6, 2004,
the Company issued the 3,500,000 shares to its minority partner in Emir
Oil (see Note 16). The aggregate purchase price was determined to be
$19,075,000 using a price of the Company's common shares on OTCBB on
August 6, 2004 of $5.45 per share. The entire purchase price has been
allocated to oil and gas properties in the accompanying Consolidated
Balance Sheet.
F-11
BMB MUNAI, INC
(A DEVELOPMENT STAGE ENTITY)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2005
- --------------------------------------------------------------------------------
The results of Emir's operations have been included in the Consolidated
Financial Statements since June 7, 2003. Emir had no operations prior to
its acquisition by BMB. Emir holds an oil and gas contract for the ADE
Block. Based on its ownership of Emir Oil, the Company is required to fund
the exploration and development efforts of Emir Oil (see Note 19).
4. REVENUES
Revenues represent sales of oil and gas during the test of exploration
wells within the domestic market of the Republic of Kazakhstan. Price for
oil and gas in a domestic market of the Republic of Kazakhstan is
substantially lower than world market prices.
5. INCOME TAXES
The income tax charge in the income statement comprised:
2005
Current tax expense $ -
Deferred tax expense 343
-------------------
$ 343
===================
Relationship between tax expenses and accounting loss for the years
ended March 31 are explained as follows:
2005 2004
Loss before income taxes and minority interest $ (3,285,969) $ (531,798)
------------------- -------------------
Expected tax provision (504,227) (129,027)
Add tax effect of:
Permanent differences 495,397 (70,973)
Change in valuation allowance 9,173 200,000
------------------- -------------------
$ 343 $ -
=================== ===================
Deferred taxes reflect the estimated tax effect of temporary
differences between assets and liabilities for financial reporting
purposes and those measured by tax laws and regulations. The components
of deferred tax assets and deferred tax liabilities are as follows:
2005 2004
Deferred tax assets
Loss carryforward $ 209,173 $ 200,000
------------------- -------------------
Deferred tax liabilities:
Unrealised interest income 343 -
Valuation allowance (209,173) (200,000)
------------------- -------------------
Net deferred tax liability $ 343 $ -
=================== ===================
F-12
BMB MUNAI, INC
(A DEVELOPMENT STAGE ENTITY)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2005
- --------------------------------------------------------------------------------
6. CASH AND CASH EQUIVALENTS
As of March 31 cash and cash equivalents included:
2005
Cash at bank, US Dollars $ 9,982,103
Cash at bank, foreign currency 7,529
-------------------
$ 9,989,632
===================
As of March 31, 2005 the Company pledged cash in amount of $15,567 to
collateralize payment to oil drilling and service company for drilling
services.
7. MARKETABLE SECURITIES
Marketable securities as of March 31 were as follows:
2005
Bonds $ 418,952
Shares 369,969
-------------------
$ 788,921
===================
As of March 31, 2005 the Company pledged all marketable securities to
collateralize payment to oil drilling and service company for drilling
services.
8. INVENTORIES
Inventories as of March 31 were as follows:
2005
Construction material $ 3,103,555
Purchased semi products 59,706
Crude oil produced 7,735
Other 56,415
--------------------
$ 3,227,411
====================
F-13
BMB MUNAI, INC
(A DEVELOPMENT STAGE ENTITY)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2005
- --------------------------------------------------------------------------------
9. PREPAID EXPENSES, NET
Prepaid expenses as of March 31 were as follows:
2005
Advances for material $ 2,301,074
VAT recoverable 1,217,751
Advances for services 589,944
Other 192,573
Reserves against uncollectible advances and prepayments (129,051)
--------------------
$ 4,172,291
====================
10. DUE TO ASTANA FUND
In 2004 the Government of the Republic of Kazakhstan imposed a liability
in the amount of $250,000 to make cash contributions to the Astana Fund.
The Astana Fund is a government fund used by the Government of the
Republic of Kazakhstan to accumulate cash for construction and development
of Astana, Kazakhstan, the new capital of the Republic of Kazakhstan.
11. OIL AND GAS PROPERTIES, NET
Oil and gas properties as of March 31 were as follows:
2005
Subsoil use right $ 20,788,119
Cost of drilling wells 9,334,021
Professional services received in exploration and development activities 4,798,314
Material and fuel used in exploration and development activities 2,891,765
Infrastructure development costs 1,231,391
Geological and geophysical 653,571
Other capitalized costs 3,334,630
Accumulated depreciation, depletion and amortization (229,406)
--------------------
$ 42,802,405
====================
F-14
BMB MUNAI, INC
(A DEVELOPMENT STAGE ENTITY)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2005
- --------------------------------------------------------------------------------
12. OTHER FIXED ASSETS, NET
Constructions Machinery
and equipment equipment Vehicles Office Other Total
---------------- ------------ -------------- ---------------- ------------ -------------
Cost
at April 1, 2004 $ 62,583 $ 114,650 $ 46,450 $ 33,286 $ 7,442 $ 264,411
Additions 23,622 119,550 266,757 95,697 31,074 536,700
Disposals - - - - (95) (95)
---------------- ------------ -------------- ---------------- ------------ -------------
at March 31, 2005 86,205 234,200 313,207 128,983 38,421 801,016
------------------------------ -------------- ---------------------------------------------
Accumulated depreciation
at April 1, 2004 - 1,261 2,289 1,039 169 4,758
Charge for the period 10,789 17,025 56,577 22,795 5,708 112,894
Disposals - - - - (95) (95)
---------------- ------------ -------------- ---------------- ------------ -------------
at March 31, 2005 10,789 18,286 58,866 23,834 5,782 117,557
---------------- ------------ -------------- ---------------- ------------ -------------
Net book value at March
31, 2004 62,583 113,389 44,161 32,247 7,273 259,653
================ ============ ============== ================ ============ =============
Net book value at March
31, 2005 $ 75,416 $ 215,914 $ 254,341 $ 105,149 $ 32,639 $ 683,459
================ ============ ============== ================ ============ =============
In accordance with FAS No. 19, Financial Accounting and Reporting by Oil
and Gas Producing Companies, depreciation related to support equipment and
facilities used in exploration and development activities in amount of $
49,764 was capitalized to oil and gas properties.
13. INTANGIBLE ASSETS, NET
2005
Cost
Beginning balance $ 5,411
Additions 12,345
----------------
Ending balance 17,756
Accumulated depreciation
Beginning balance -
Amortization for the period 3,321
----------------
Ending balance 3,321
----------------
Net book value $ 14,435
================
14. LONG TERM LIABILITIES
a) Due to reservoir consultants
The amount of $222,000 due to reservoir consultants represents a part of
$700,000 contract with PGS Reservoir Consultants payable during 2006. The
Company paid to PGS Reservoir Consultants $200,000 during 2004 and will
pay $278,000 in 2005.
F-15
BMB MUNAI, INC
(A DEVELOPMENT STAGE ENTITY)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2005
- --------------------------------------------------------------------------------
b) Liquidation fund
Under the laws of the Republic of Kazakhstan, the Company is obligated to
set aside funds for required environmental remediation. As of March 31,
2005 the Company contributed $60,973 to the Liquidation Fund.
15. MINORITY INTEREST
Minority interest represents interest of 30% shareholder of Emir Oil. On
May 24, 2004, the Company agreed to purchase the remaining 30% interest of
its minority interest partner in Emir Oil in exchange for 3,500,000 shares
of restricted Company common stock. On August 6, 2004, the Company issued
the 3,500,000 shares to its minority partner in Emir Oil (see Notes 3 and
16).
2005
Beginning balance $ 82,134
Share of minority for net loss -
Share capital portion of minority -
Recovery of minority interest after purchase of
remaining interest (82,134)
-------------
Ending balance $ -
=============
16. SHARE AND ADDITIONAL PAID IN CAPITALS
Common and preferred stock as of March 31 are as following:
2005 2004
Preferred stock, $0.001 par value
Authorised 20,000,000 20,000,000
Issued and outstanding - -
Common stock, $0.001 par value
Authorised 100,000,000 100,000,000
Issued and outstanding 30,513,761 20,429,421
Reverse merger
During the year ended March 31, 2004, the Company completed a reverse
merger with BMB Holding, Inc. Additionally the Company:
a) Completed a private placement for the total amount of $11,113,562.
b) Converted a $2,000,000 debt to the shareholders of BMB Holding, Inc.
into equity.
c) Issued 200,000 shares of stock upon exercise of stock option worth
$200,000.
d) Completed a 10 for 1 reverse stock split.
Acquisition
On May 24, 2004, the Company agreed to purchase the remaining 30% interest
of its minority interest partner in Emir Oil in exchange for 3,500,000
shares of restricted Company common stock. On August 6, 2004, the Company
issued the 3,500,000 shares to its minority partner in Emir Oil (see Note
3). The aggregate purchase price was determined to be $19,075,000 using a
price of the Company's common shares on OTCBB on August 6, 2004 of $5.45
per share. The entire purchase price has been allocated to oil and gas
properties in the accompanying Consolidated Balance Sheet.
F-16
BMB MUNAI, INC
(A DEVELOPMENT STAGE ENTITY)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2005
- --------------------------------------------------------------------------------
Private placements
On July 2, 2004, the Company sold an aggregate of 4,584,340 common shares
of the Company at $4.00 per share in a private placement offering. The
Company received $17,311,906 net of the agent fees and out of pocket
expenses.
On March 9, 2005, the Company sold an aggregate of 2,000,000 common shares
of the Company at $5.00 per share in a private placement offering. The
Company received $9,968,254 net of the agent fees and out of pocket
expenses.
On March 31, 2005, the Company issued for subscription an aggregate of
1,101,000 common shares of the Company at $5.00 per share in a private
placement offering.
Common stocks sold at private placements as of March 31 are as following:
Number of Share price Gross amount Net amount
shares sold raised received
2004
First private placement 4,830,494 $ 2.15-$ 2.50 $ 11,113,562 $ 9,935,874
----------------- ----------------- ------------------
4,830,494 11,113,562 9,935,874
2005
Second private placement 4,584,340 $ 4.00 18,337,360 17,311,906
Third private placement (first
closing) 2,000,000 $ 5.00 10,000,000 9,968,254
Third private placement (second
closing) 1,101,000 $ 5.00 - -
----------------- ----------------- ------------------
7,685,340 28,337,360 27,280,160
12,515,834 $ 39,450,922 $ 37,216,034
================= ================= ==================
The offerings were made only to accredited investors in the United States
under Regulation D and pursuant to Regulation S to non U.S. Persons.
Share-Based Compensation
On November 19, 2003, the Company granted options to the placement agent
for services rendered in connection with a private placement of the
Company's common stock in November 2003. The first option granted the
placement agent the right to purchase up to 200,000 common shares of the
Company at an exercise price of $1.00 per share. The placement agent
exercised this option and purchased 200,000 shares for $200,000 on
December 15, 2003. The second option grants the placement agent the right
to purchase up to 142,857 common shares of the Company at an exercise
price of $3.50 per share. This option expires on November 26, 2008.
In December 2003, the Company granted warrants to a placement agent in
connection with funds raised on the Company's behalf. These warrants grant
the placement agent the right to purchase up to 275,050 shares of the
Company's common stock at an exercise price of $2.15 and 208,000 shares of
the Company's common stock at an exercise price of $2.50 per share. The
warrants expire at the end of June 2005.
On July 2004, the Company granted warrants to a placement agent in
connection with funds raised on the Company's behalf. These warrants grant
the placement agents the right to purchase up to 458,434 shares of the
F-17
BMB MUNAI, INC
(A DEVELOPMENT STAGE ENTITY)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2005
- --------------------------------------------------------------------------------
Company's common stock at an exercise price of $4.00 per share. The
warrants expire at the first quarter of 2006 calendar year.
During the year ended March 31, 2005 the Board of Directors (the "Board")
of the Company approved an incentive stock option plan (the "plan") under
which directors, officers and key personnel may be granted options to
purchase common shares of the Company. The Company has reserved 5,000,000
common shares for issuance upon the exercise of options granted under the
terms of the plan. The Board determines the exercise price of each option,
provided that no option shall be granted with an exercise price at a
discount to market. The vesting periods established under the plan and the
term of the options are set by the Board. During the third quarter of the
year ended March 31, 2005 the Company granted stock options to its
corporate secretary for the past services rendered. These options grant
the employee the right to purchase up to 60,000 shares of the Company's
common stock at an exercise price of $4.00 per share. The options expire
in five years from the date of grant. Granted options vest immediately.
Compensation expense for options granted to a corporate secretary is
determined based on their fair values at the time of grant, the cost of
which in the amount of $81,000 is recognized in the Consolidated Statement
of Income and Consolidated Balance Sheet.
Stock options and warrants outstanding and exercisable as of March 31 are:
Weighted
Number Average Exercise
of shares price
----------------- -----------------
As of March 31, 2003 - $ -
Granted 825,907 2.19
Exercised (200,000) 1.00
-------------- -------------
As of March 31, 2004 625,907 2.57
Granted 518,434 4.00
-------------- -------------
As of March 31, 2005 1,144,341 $ 3.22
============== =============
Stock options and warrants as of March 31, 2005 are:
Options and Warrants outstanding Options and Warrants exercisable
---------------------------------------------------------------------- ------------------------------------
Range of Options and Weighted Weighted Options and Weighted Average
exercise price Warrants Average Average Warrants Exercise Price
Life (years) Exercise Price Contractual
------------------ ----------------- --------------- ---------------------------------- ------------------
$ 2.15 - $ 4.00 1,144,341 $ 3.22 2.20 1,144,341 $ 3.22
F-18
BMB MUNAI, INC
(A DEVELOPMENT STAGE ENTITY)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2005
- --------------------------------------------------------------------------------
The estimated fair value of the stock options and warrants issued were
determined using Black-Scholes option pricing model with the following
assumptions:
2005 2004
Risk-free interest rate 3.20% 2.00%
Expected option life 1 year 3 years
Expected volatility in the price of the Company's common shares 76% 246%
Expected dividends 0% 0%
Weighted average fair value of options and warrants granted
during the year $ 2.22 $ 3.81
17. EARNINGS PER SHARE (BASIC AND DILUTED)
The calculation of the basic and diluted earnings per share is based on
the following data:
2005 2004
Numerator
Net loss for basic and diluted loss per share 3,286,312 613,782
Denominator
Weighted average number of common shares for the purposes of
basic and diluted earnings per share 26,948,437 7,398,240
---------------- ----------------
Loss per share (basic and diluted) $ 0.122 $ 0.083
================ ================
The effect of the stock warrants and stock options is anti-dilutive.
18. RELATED PARTY TRANSACTIONS
2005 2004
Accounts payable $ 503,045 $ 103,231
Prepaid expenses 150,841 -
Services rendered 610,336 2,724,433
Operating lease of land, premises and warehouses 218,428 12,817
Loans received and repaid - 2,500,000
Guarantees received 600,000 -
On September 15, 2003 BMB Holding, Inc. obtained a short-term financing
for covering expenses related to the reverse merger and private placement
from one of its shareholders, Caspian Services Group, Ltd. The loan in the
amount of $500,000 was for a term of six months with the annual interest
rate of 16.5%. This loan was repaid in full on November 26, 2003 from the
proceeds of the private placement.
On May 25, 2004 the Company received a letter of guarantee for drilling of
exploratory wells from KazMorGeofizika CJSC. The letter of guarantee in
the amount of $1,000,000 for the period of drilling works was issued to
the supplier of drilling works and closed on February 15, 2005. On
February 15, 2005 the Company received a letter of guarantee in the amount
of $600,000 from KazMorGeofizika CJSC for drilling of another exploratory
well.
F-19
BMB MUNAI, INC
(A DEVELOPMENT STAGE ENTITY)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2005
- --------------------------------------------------------------------------------
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 in total amount of $ 5,994,200. When the Company applies
for and is granted commercial production rights for the ADE Block, the
Company will be required to begin repaying these historical investments to
the Government of the Republic of Kazakhstan. The terms of repayment will
be negotiated at the time the Company applies for commercial production
rights.
Capital Commitments
Under the terms of its oil and gas contract, Emir Oil is required to spend
a total of $32 million in exploration and development activities on the
ADE Block. To retain its rights under the contract, the Company must spend
a minimum of $9.3 million in 2005, $6 million in 2006 and $4.5 million in
2007. The failure to make these minimum capital expenditures could result
in the loss of the contract.
Operating Environment
The Company's principal business unit, Emir Oil, operates within the
Republic of Kazakhstan. Laws and regulations affecting businesses
operating in the Republic of Kazakhstan are subject to rapid changes and
the Company's assets and operations could be at risk in the event of
negative changes in the political and business environment.
Government taxes and legislation in the Republic of Kazakhstan
The local and national tax environment in the Republic of Kazakhstan is
subject to change and inconsistent application, interpretation and
enforcement. Non-compliance with Kazakhstan laws and regulations can lead
to imposition of penalties and interest.
Environmental matters
The Company believes it is currently in compliance with all existing
Kazakhstan environmental laws and regulations. However, Kazakhstan
environmental laws and regulations may change in the future.
Pension and retirement plans
Employees of the Company receive pension benefits in accordance with the
laws and regulations of the respective countries. As of March 31, 2005 and
2004 the Company was not liable for any supplementary pensions,
post-retirement, health care, insurance benefits or retirement indemnities
to its current or former employees.
Other matters
In December 2003, a lawsuit was filed in Florida naming the Company as one
of the defendants. The claim of breach of contract, unjust enrichment,
breach of fiduciary duty, conversion and violation of a Florida trade
F-20
BMB MUNAI, INC
(A DEVELOPMENT STAGE ENTITY)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2005
- --------------------------------------------------------------------------------
secret statute in connection with a business plan for the development
Aksaz, Dolinnoe and Emir oil and gas fields owned by Emir Oil. The
plaintiffs seek unspecified compensatory and exemplary damages.
In April 2005, Sokol Holdings, Inc., filed a complaint in United States
District Court, Southern District of New York alleging that the Company
wrongfully induced Mr. Tolmakov, Director of Emir Oil, to breach a
contract under which Mr. Tolmakov had agreed to sell to Sokol 70% of his
90% interest in Emir Oil LLP. Sokol Holdings, Inc. seeks damages in an
unspecified amount exceeding $75,000 to be determined at trial, punitive
damages, specific performance in the form of an order compelling BMB to
relinquish its interest in Emir and the underlying interest in the ADE
fields to Sokol Holdings, Inc. and such other relief as the court finds
just and reasonable.
The Company is confident that the matters shall be resolved in the
Company's favor. The Company has retained legal counsels to protect its
interests. In the opinion of the Company's management and legal counsels,
the resolution of those lawsuits will not have a material adverse effect
on Company's financial condition, results of operations or cash flows.
20. FINANCIAL INSTRUMENTS
The nature of the Company's operations exposes the Company to fluctuations
in commodity prices, foreign currency exchange rates, credit risk and
country risk. The Company recognizes these risks and manages operations in
a manner such that exposure to these risks minimized to the extent
practical.
As of March 31, 2005 marketable securities of $788,921 are held in short
term repurchase agreements for securities issued by Kazakhstan banks and
Kazakhstan financial institutions. As of March 31, 2005 cash and cash
equivalents include deposits in Kazakhstan banks in the amount $9,090,276.
As of March 31, 2005 the Company made advance payments to Kazakhstan
companies and budget in the amount $4,301,342. As of March 31, 2005 trade
accounts receivable of $132,400 are with the Kazakhstan oil processing
plant. Restricted cash reflected in the long-term assets consists of
$60,973 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; an entity
formed under the laws of the Republic Kazakhstan.
21. SUBSEQUENT EVENTS
On March 31, 2005, the Company issued for subscription an aggregate of
1,101,000 common shares of the Company at $5.00 per share in a private
placement offering. Pursuant to the offering closing on April 12, 2005 the
Company raised total proceeds of $5,505,000 (see Note 16).
On April 12, 2005, the Company granted warrants to placement agents in
connection with funds raised on the Company's behalf. These warrants grant
the placement agents the right to purchase up to 110,100 shares of the
Company's common stock at an exercise price of $5.00 per share. The
warrants expire on April 11, 2006.
In May and June 2005 a party exercised stock warrants for 275,050 shares
at the exercise price of $2.15 and stock warrants for 109,030 shares at
the exercise price of $2.50.
On May 27, 2005 the Company made a cash contribution of $250,000 to Astana
Fund as a part of the social program of investing activity of the Company
(see Note 10).
F-21
BMB MUNAI, INC
(A DEVELOPMENT STAGE ENTITY)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2005
- --------------------------------------------------------------------------------
22. SUPPLEMENTARY FINANCIAL INFORMATION ON OIL AND NATURAL GAS EXPLORATION
DEVELOPMENT AND PRODUCTION ACTIVITIES (unaudited)
This footnote provides unaudited information required by SFAS No. 69,
"Disclosures about Oil and Natural Gas Producing Activities." The
Company's oil and natural gas properties are located in the Republic of
Kazakhstan, which constitutes one cost center.
Capitalized Costs - Capitalized costs and accumulated depletion,
depreciation and amortization relating to our oil and natural gas
producing activities, all of which are conducted in the Republic of
Kazakhstan, are summarized below:
2005 2004
--------------------------- ---------------------------
Developed oil and natural gas properties $ 43,031,811 $ 6,495,186
Unevaluated oil and natural gas properties - -
Accumulated depletion, depreciation and
amortization (229,406) -
--------------------------- ---------------------------
Net capitalized cost $ 42,802,405 $ 6,495,186
=========================== ===========================
Costs Incurred - Costs incurred in oil and natural gas property
acquisition, exploration and development activities are summarized below:
2005 2004
--------------------------- ---------------------------
Acquisition costs:
Unproved properties $ - $ -
Proved properties 20,788,119 1,713,119
Exploration costs 3,373,092 2,659,872
Development costs 18,870,600 2,122,195
--------------------------- ---------------------------
Subtotal 43,031,811 6,495,186
Asset retirement costs - -
--------------------------- ---------------------------
Total costs incurred $ 43,031,811 $ 6,495,186
=========================== ===========================
Results of Operations - Results of operations for the Company's oil and
natural gas producing activities are summarized below:
F-22
BMB MUNAI, INC
(A DEVELOPMENT STAGE ENTITY)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2005
- --------------------------------------------------------------------------------
For the period from
For the year ended inception (May 6, 2003)
March 31, 2005 to March 31, 2004
--------------------------- ---------------------------
Oil and natural gas revenues $ 973,646 $ -
Operating expenses:
Oil and natural gas operating expenses
and ad valorem taxes 197,697 -
Production taxes - -
Accretion expense - -
Depletion expense 229,406 -
--------------------- ---------------------
Results of operations from oil and gas
producing activities $ 546,543 $ -
===================== =====================
Reserves - Proved reserves are estimated quantities of oil and natural
gas, which geological and engineering data demonstrate with reasonable
certainty to be, recoverable in future years from known reservoirs under
existing economic and operating conditions. Proved developed reserves are
proved reserves that can reasonably be expected to be recovered through
existing wells with existing equipment and operating methods. Proved oil
and natural gas reserve quantities and the related discounted future net
cash flows before income taxes (see Standardized Measure) for the periods
presented are based on estimates prepared by Chapman Petroleum Engineering
Ltd., independent petroleum engineers. Such estimates have been prepared
in accordance with guidelines established by the SEC.
The Company's net ownership in estimated quantities of proved oil and
natural gas reserves, and changes in net proved reserves, all of which are
located in the Republic of Kazakhstan, are summarized below:
Natural Gas
(Mcf)
---------------------------------------------------------
For the period from
For the year ended inception (May 6, 2003) to
March 31, 2005 March 31, 2004 (1)
------------------------- ----------------------------
Proved developed and undeveloped
reserves
Beginning of the year - -
Revisions of previous estimates - -
Purchase of oil and gas properties - -
Extensions and discoveries - -
Sales of natural gas properties - -
Production - -
------------------------- ----------------------------
End of year - -
========================= ============================
Proved developed reserves at year end - -
========================= ============================
- -------------------
(1) The Company acquired the ADE Block during the period from inception through
March 31, 2004. During that period, however, the Company had insufficient
geological and engineering data to demonstrate proved reserves with
reasonable certainty during that period.
F-23
BMB MUNAI, INC
(A DEVELOPMENT STAGE ENTITY)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2005
- --------------------------------------------------------------------------------
Oil, Condensate and Natural Gas Liquids
(MBbls)
---------------------------------------------------------
For the period from
For the year ended inception (May 6, 2003) to
March 31, 2005 March 31, 2004 (1)
------------------------- ----------------------------
Proved developed and undeveloped
reserves
Beginning of the year - -
Revisions of previous estimates - -
Purchase of oil and gas properties - -
Extensions and discoveries 13,228,755 -
Sales of natural gas properties - -
Production 68,755 -
------------------------- ----------------------------
End of year 13,160,000 -
========================= ============================
Proved developed reserves at year end 10,580,000 -
========================= ============================
- -------------------
(1) The Company acquired the ADE Block during the period from inception through
March 31, 2004. During that period, however, the Company had insufficient
geological and engineering data to demonstrate proved reserves with
reasonable certainty during that period.
Standardized Measure - The Standardized Measure of Discounted Future Net
Cash Flows relating to the Company's ownership interests in proved oil and
natural gas reserves for the period from inception (May 6, 2003) through
March 31, 2004 and for the fiscal year ended March 31, 2005 are shown
below:
For the period from
For the year ended inception (May 6, 2003)
March 31, 2005 to March 31, 2004
--------------------------- ---------------------------
Future cash inflows $ 274,607,000 $ -
Future oil and natural gas operating
expenses 46,442,000 -
Future development costs 7,750,000 -
Future income tax expense 43,216,000 -
--------------------------- ---------------------------
Future net cash flows 177,199,000 -
10% discount factor 77,278,000 -
--------------------------- ---------------------------
Standardized measure of discounted future
net cash flows $ 99,921,000 $ -
=========================== ===========================
Our standardized measure of discounted future net cash flows relating to
proved oil and natural gas reserves were prepared in accordance with the
provisions of SFAS 69. Future cash inflows are computed by applying year
end prices of oil and natural gas to year end quantities of proved oil and
F-24
natural gas reserves. Future oil and natural gas production and
development costs are computed by estimating the expenditures to be
incurred in producing and developing the proved oil and natural gas
reserves at year end, based on year end costs and assuming continuation of
existing economic condition.
Future income tax expenses are calculated by applying appropriate year end
tax rates to future pre-tax net cash flows relating to proved oil and
natural gas reserves, less the tax basis of properties involved. Future
income tax expenses give effect to permanent differences, tax credits and
loss carryforwards relating to the proved oil and natural gas reserves.
Future net cash flows are discounted at a rate of 10% annually to derive
the standardized measure of discounted future net cash flows. The
Standardized Measure of Discounted Future Net Cash Flows is not intended
to represent the replacement cost or fair market value of the Company's
oil and natural gas properties.
Changes in Standardized Measure - Changes in Standardized Measure of
Discounted Future Net Cash Flows relating to proved oil and gas reserves
are summarized below:
For the period from
For the year ended March inception (May 6, 2003)
31, 2005 to March 31, 2004
---------------------------- ---------------------------
Changes due to current year operations:
Sales of oil and natural gas, net of oil
and natural gas operating expenses - -
Sales of oil and natural gas properties - -
Purchase of oil and gas properties - -
Extensions and discoveries $ 228,165,000 -
Changes due to revisions of standardized - -
variables
Prices and operating expenses - -
Revisions to previous quantity estimates - -
Estimated future development costs 7,750,000 -
Income taxes 43,216,000 -
Accretion of discount 77,278,000 -
Production rates (timing) and other - -
---------------------------- ---------------------------
Net Change 99,921,000 -
Beginning of year - -
---------------------------- ---------------------------
End of year $ 99,921,000 $ -
============================ ===========================
Sales of oil and natural gas, net of oil and natural gas operating
expenses are based on historical pre-tax results. Sales of oil and natural
gas properties, extensions and discoveries, purchases of minerals in place
and the changes due to revisions in standardized variables are reported on
a pre-tax discounted basis, while the accretion of discount is presented
on an after tax basis.
F-25
BMB MUNAI, INC
(A DEVELOPMENT STAGE ENTITY)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2005
- --------------------------------------------------------------------------------
23. RESTATEMENT OF FINANCIAL STATEMENTS
In response to comments raised by the staff of the Securities and Exchange
Commission, the Company commenced a re-evaluation of its estimated proved
reserves. Based on the Company's internal review, and after consultation
with the Audit Committee of the Company's Board of Directors and
independent registered public accounting firm, on March 22, 2006, the
Company determined it was necessary to restate its Consolidated Balance
Sheet as of March 31, 2005, Consolidated Statements of Loss for the year
ended March 31, 2005 and for the period from inception (May 6, 2003) to
March 31, 2005 and the Supplementary disclosure information on oil and
natural gas exploration development and production activities to
Consolidated Financial Statements for the year ended March 31, 2005.
The primary effect of the correction discussed above resulted in the
Company reducing the long-term asset "Oil and Gas Properties, Full Cost
Method, Less Accumulated Depreciation" by $161,954 on its Consolidated
Balance Sheet as of March 31, 2005 and additional accrual of depletion
expense by $161,954 on its Consolidated Statement of Loss for the year
ended March 31, 2005 and for the period from inception (May 6, 2003) to
March 31, 2005. The correction also resulted in the Company reducing its
proved developed reserves of natural gas by $15,917,000, proved developed
reserves of oil, condensate and natural gas liquids by $3,034,000 and its
standardized measure of discounted future net cash flows by $15,164,000.
Following is a summary of the effects of these adjustments on the
Company's Consolidated Balance Sheet as of March 31, 2005 and Consolidated
Statements of Loss for the year ended March 31, 2005 and the period from
inception (May 6, 2003) to March 31, 2005:
Balance sheet/Statement of loss items As restated As previously reported
March 31, 2005
Oil and Gas Properties, Full Cost Method,
Less Accumulated Depreciation $ 42,802,405 $ 42,964,359
Total non-current assets 43,561,272 43,723,226
Total assets 61,871,927 62,033,881
Deficit accumulated during the development
stage (3,900,094) (3,738,140)
Total shareholders' equity 54,590,940 54,752,894
Total liabilities and shareholders' equity 61,871,927 62,033,881
For the year ended March 31, 2005:
Production expenses $ (427,103) $ (265,149)
Total expenses (4,761,445) (4,599,491)
Loss from operations (3,787,799) (3,625,845)
Loss before income taxes (3,285,969) (3,124,015)
Loss before minority interest (3,286,312) (3,124,358)
Net loss (3,286,312) (3,124,358)
Loss per common share (basic and diluted) 0.122 0.116
F-26
BMB MUNAI, INC
(A DEVELOPMENT STAGE ENTITY)
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2005
- --------------------------------------------------------------------------------
For the period from inception
(May 6, 2003) to March 31, 2005:
Production expenses $ (427,103) $ (265,149)
Total expenses (5,547,960) (5,386,006)
Loss from operations (4,574,314) (4,412,360)
Loss before income taxes (3,817,767) (3,655,813)
Loss before minority interest (3,818,110) (3,656,156)
Net loss (3,900,094) (3,738,140)
Following is a summary of the effects of this revision on the Company's
Supplementary disclosure information on oil and natural gas exploration
development and production activities to Consolidated Financial Statements
for the year ended March 31, 2005:
Disclosure item As restated As previously reported
March 31, 2005:
Proved developed reserves of natural gas - 15,917,000
Proved developed reserves of oil, condensate
and natural gas liquids 10,580,000 13,614,000
Standardized measure of discounted future
net cash flows 99,921,000 115,085,000
F-27