FORM 10-Q
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
|X| QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE
ACT OF 1934
For the quarterly period ended September 30, 2005.
OR
|_| TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
For the transition period from ________________ to ________________.
Commission File Number: 0 - 7261
CHAPARRAL RESOURCES, INC.
-------------------------
(Exact Name of Registrant as Specified in Its Charter)
Delaware 84-0630863
------------------------------- ------------------------------------
(State or Other Jurisdiction of (I.R.S. Employer Identification No.)
Incorporation or Organization)
2 Gannett Drive, Suite 418
White Plains, New York 10604
----------------------------
(Address of Principal Executive Offices)
Registrant's telephone number, including area code: (866) 559-3822
Indicate by check mark whether the Registrant: (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Securities Exchange Act of
1934 during the preceding 12 months, and (2) has been subject to such filing
requirements for the past 90 days.
YES |X| NO |_|
Indicate by check mark whether the Registrant is an accelerated filer (as
defined in Rule 12b-2 of the Exchange Act).
YES |_| NO |X|
As of November 9, 2005 the Registrant had 38,209,502 shares of its common
stock, par value $0.0001 per share, issued and outstanding.
CHAPARRAL RESOURCES, INC.
FORM 10-Q
SEPTEMBER 30, 2005
TABLE OF CONTENTS
PAGE
----
PART I. FINANCIAL INFORMATION
Item l. Financial Statements
Consolidated Condensed Balance Sheets as of September 1
30, 2005 and December 31, 2004
Consolidated Condensed Statements of Operations for 3
the Three Months Ended September 30, 2005 and 2004
and Consolidated Condensed Statements of Operations
for the Nine Months Ended September 30, 2005 and 2004
Consolidated Condensed Statements of Cash Flows for 4
the Nine Months Ended September 30, 2005 and 2004
Notes to Consolidated Condensed Financial Statements 6
Item 2. Management's Discussion and Analysis of Financial Condition 14
and Results of Operations
Item 3. Quantitative and Qualitative Disclosures About Market Risk 19
Item 4. Controls and Procedures 20
PART II. OTHER INFORMATION
Item 6. Exhibits 21
Signatures 22
Part I - Financial Information
Item 1 - Financial Statements
Chaparral Resources, Inc.
Consolidated Condensed Balance Sheets
September 30, December 31,
2005 2004
(Unaudited)
------------- ------------
$000 $000
Assets
Current assets:
Cash and cash equivalents 3,360 9,611
Accounts receivable:
Oil sales receivable 22,241 316
VAT receivable 6,950 2,212
Other receivables from affiliates 5 1,002
Prepaid expenses 5,283 3,472
Current portion of deferred financing charges 1,274 --
Crude oil inventory 78 36
--------- ---------
Total current assets 39,191 16,649
Deferred financing charges 514 --
Materials and supplies 6,999 5,238
Other 1,962 336
Property, plant and equipment:
Oil and gas properties, full cost 174,687 153,001
Other property, plant and equipment 11,529 10,974
--------- ---------
186,216 163,975
Less - accumulated depreciation, depletion and amortization (80,746) (62,495)
--------- ---------
Property, plant and equipment, net 105,470 101,480
--------- ---------
Total assets 154,136 123,703
========= =========
See accompanying notes.
1
Chaparral Resources, Inc.
Consolidated Condensed Balance Sheets (continued)
September 30, December 31,
2005 2004
(Unaudited)
------------- ------------
$000 $000
Liabilities and Stockholders' equity
Current liabilities:
Accounts payable 6,244 8,540
Advances received -- 387
Prepaid sales 513 6,590
Accrued liabilities:
Accrued compensation 256 241
Accrued interest payable 110 713
Other accrued liabilities 3,761 1,822
Current income tax liability 12,907 2,052
Current portion of loans payable 7,725 19,778
-------- --------
Total current liabilities 31,516 40,123
Accrued production bonus 367 299
Loans payable 12,278 12,000
Deferred tax liability 940 3,258
Minority interest 29,074 12,099
Asset retirement obligation 1,517 1,232
Stockholders' equity:
Common stock - authorized, 100,000,000
shares of $0.0001 par value; issued and outstanding,
38,209,502 shares as of September 30, 2005 and
December 31, 2004 4 4
Capital in excess of par value 107,226 107,226
Preferred stock - 1,000,000 shares authorized, 925,000 shares
undesignated. Issued and outstanding - none -- --
Accumulated deficit (28,786) (52,538)
-------- --------
Total Stockholders' equity 78,444 54,692
-------- --------
Total liabilities and Stockholders' equity 154,136 123,703
======== ========
See accompanying notes.
2
Chaparral Resources, Inc.
Consolidated Condensed Statements of Operations (Unaudited)
For the Three Months Ended For the Nine Months Ended
-------------------------------- --------------------------------
September 30, September 30, September 30, September 30,
2005 2004 2005 2004
------------- ------------- ------------- -------------
$000 (except share data) $000 (except share data)
Revenue 50,437 22,078 107,924 55,158
Costs and expenses:
Transportation costs 4,969 3,327 12,513 9,546
Operating expenses 4,046 1,762 11,439 5,661
Marketing fee 143 114 401 153
Depreciation and depletion 7,440 4,276 18,287 12,813
Management fee 193 157 586 257
Advisory fee -- -- -- 100
Accretion expense 36 21 110 67
General and administrative 1,673 1,447 4,719 5,204
----------- ----------- ----------- -----------
Total costs and expenses 18,500 11,104 48,055 33,801
----------- ----------- ----------- -----------
Income from operations 31,937 10,974 59,869 21,357
Other income/(expense):
Interest income 14 9 157 63
Interest expense (1,050) (1,263) (3,331) (3,761)
Currency exchange loss (174) (197) (157) (354)
Minority interest (9,113) (2,840) (16,975) (5,663)
Loss on disposition of assets (19) (2) (20) (2)
----------- ----------- ----------- -----------
Income before income taxes 21,595 6,681 39,543 11,640
Income tax expense (8,280) (3,122) (15,791) (6,147)
----------- ----------- ----------- -----------
Net income available to common Stockholders 13,315 3,559 23,752 5,493
=========== =========== =========== ===========
Basic earnings per share:
Net income per share $ 0.35 $ 0.09 $ 0.62 $ 0.14
Weighted average number of shares
outstanding (basic) 38,209,502 38,209,502 38,209,502 38,209,502
Diluted earnings per share:
Net income per share $ 0.33 $ 0.09 $ 0.59 $ 0.14
Weighted average number of shares
outstanding (diluted) 40,475,014 38,209,502 39,959,617 38,209,502
The dilution of earnings per share is due to the dilutive effect of the warrant, described in note 6, on the number of
shares outstanding.
See accompanying notes.
3
Chaparral Resources, Inc.
Consolidated Condensed Statements of Cash Flows (Unaudited)
For the Nine Months Ended
--------------------------------
September 30, September 30,
2005 2004
------------- -------------
$000 $000
Cash flows from operating activities
Net income 23,752 5,493
Adjustments to reconcile net income to net
cash provided by operating activities:
Depreciation, depletion and amortization 18,230 12,813
Deferred income taxes (2,318) 3,445
Accretion expense 110 67
Amortization of note discount 222 355
Currency exchange loss 157 354
Loss on disposition of assets 23 2
Amortization of deferred financing fees 338 --
Minority interest 16,975 5,663
Changes in assets and liabilities:
(Increase)/decrease in:
Accounts receivable (25,666) (1,636)
Prepaid expenses (1,810) 142
Crude oil inventory (21) 95
Increase/(decrease) in:
Accounts payable and accrued liabilities 9,969 (1,584)
Prepaid sales (6,077) --
Accrued interest payable (603) (86)
Other liabilities 68 90
------- -------
Net cash provided by operating activities 33,349 25,213
------- -------
Cash flows from investing activities
Additions to property, plant and equipment (575) (377)
Capital expenditures on oil and gas properties (21,511) (23,069)
Materials and supplies inventory (1,761) (754)
Other long-term assets (1,626) (287)
------- -------
Net cash used by investing activities (25,473) (24,487)
------- -------
4
Chaparral Resources, Inc.
Consolidated Condensed Statements of Cash Flows (Unaudited) (continued)
For the Nine Months Ended
------------------------------
September 30, September 30,
2005 2004
------------- -------------
$000 $000
Cash flows from financing activities
Proceeds from loans 37,000 7,000
Payment of finance fees (2,127) --
Payments on loans (49,000) (7,000)
------- -------
Net cash used by financing activities (14,127) --
------- -------
Net increase/(decrease) in cash and cash equivalents (6,251) 726
Cash and cash equivalents at beginning of period 9,611 2,639
------- -------
Cash and cash equivalents at end of period 3,360 3,365
======= =======
Supplemental cash flow disclosure
Interest paid 3,596 3,682
Income taxes paid 7,254 708
Supplemental schedule of non-cash investing and
financing activities
Non-cash additions to oil and gas properties 175 491
See accompanying notes.
5
Chaparral Resources, Inc.
Notes to Consolidated Condensed Financial Statements (Unaudited)
1. General
Chaparral Resources, Inc. ("Chaparral") was incorporated in the state of
Colorado on January 13, 1972, principally to engage in the exploration,
development and production of oil and gas properties. Chaparral focuses
substantially all of its efforts on the development of the Karakuduk Field, an
oil field located in the Central Asian Republic of Kazakhstan. In 1999,
Chaparral reincorporated from Colorado to Delaware.
The consolidated financial statements include the accounts of Chaparral and its
greater than 50% owned subsidiaries, Closed Type JSC Karakudukmunay ("KKM"),
Central Asian Petroleum (Guernsey) Limited ("CAP-G"), Korporatsiya Mangistau
Terra International ("MTI"), Road Runner Services Company ("RRSC"), Chaparral
Acquisition Corporation ("CAC"), and Central Asian Petroleum, Inc. ("CAP-D").
Chaparral owns 80% of the common stock of CAP-G directly and 20% indirectly
through CAP-D. Hereinafter, Chaparral and its subsidiaries are collectively
referred to as the "Company." All significant inter-company transactions have
been eliminated.
As of September 30, 2005, Chaparral owns a 60% interest in KKM, a Kazakhstan
Joint Stock Company of Closed Type. KKM was formed to engage in the exploration,
development, and production of oil and gas properties in the Republic of
Kazakhstan. KKM's only significant investment is in the Karakuduk Field, an
onshore oil field in the Mangistau region of the Republic of Kazakhstan. On
August 30, 1995, KKM entered into an agreement with the Ministry of Oil and Gas
Industry for Exploration, Development and Production of Oil in the Karakuduk Oil
Field in the Mangistau Region of the Republic of Kazakhstan (the "Agreement").
KKM's rights and obligations regarding the exploration, development, and
production of underlying hydrocarbons in the Karakuduk Field are determined by
the Agreement.
KKM's rights to the Karakuduk Field may be terminated under certain conditions
specified in the Agreement. The term of the Agreement is 25 years commencing
from the date of KKM's registration. The Agreement can be extended to a date
agreed between the Ministry of Energy and Mineral Resources and KKM as long as
production of petroleum and/or gas is continued in the Karakuduk Field.
KKM is owned jointly by CAP-G (50%), MTI (10%) and Nelson Resources Limited
("Nelson") (40%). Nelson bought its 40% share in December 2004 from KazMunayGas
JSC ("KMG"), the national petroleum company of Kazakhstan, owned by the
government of the Republic of Kazakhstan. Since May 2004, Nelson has owned
approximately 60% of the outstanding common stock of Chaparral. On October 14,
2005, approximately 65% of the outstanding share capital of Nelson was acquired
by LUKOIL Overseas Holding Ltd.
Certain information and footnote disclosures normally included in financial
statements prepared in accordance with accounting principles generally accepted
in the United States have been condensed or omitted. Reference should be made to
the relevant notes to the Company's financial statements included in the
Company's Annual Report on Form 10-K for the fiscal year ended December 31,
2004.
The unaudited information furnished herein was taken from the books and records
of the Company. However, such information reflects all adjustments which are, in
the opinion of management, normal recurring adjustments necessary for the fair
statement of the results for the interim periods presented. The results of
operations for the interim periods are not necessarily indicative of the results
to be expected for any future interim period or for the year.
Use of Estimates
Application of generally accepted accounting principles requires the use of
estimates, judgments and assumptions that affect the reported amounts of assets
and liabilities as of the date of the financial statements and revenues and
expenses during the reporting period. Actual results could differ from those
estimates. The determination of proved oil and gas reserve quantities and the
application of the full cost method of accounting for exploration and production
activities requires management to make numerous estimates and judgments.
6
Chaparral Resources, Inc.
Notes to Consolidated Condensed Financial Statements (Unaudited)
(continued)
2. Recent Accounting Pronouncements
In November 2004, the FASB issued SFAS 151, Inventory Costs, an Amendment of APB
Opinion No. 43, Chapter 4. SFAS 151 clarifies the accounting treatment for
various inventory costs and overhead allocations and is effective for inventory
costs incurred after July 1, 2005. It did not have a material impact on the
Company's financial statements when adopted.
In December 2004, the FASB issued SFAS 153, Exchanges of Non-monetary Assets, an
Amendment of APB Opinion No. 29. SFAS 153 specifies the criteria required to
record a non-monetary asset exchange using carryover basis and is effective for
non-monetary asset exchanges occurring after July 1, 2005. It did not have a
material impact on the Company's financial statements when adopted.
In December 2004, the FASB issued SFAS 123 (revised 2004) ("SFAS 123R"), Share
Based Payments. SFAS 123R requires that the cost from all share-based payment
transactions, including stock options, be recognized in the financial statements
at fair value and is effective for public companies in the first interim period
after June 15, 2005. It did not have a material impact on the Company's
financial statements when adopted.
3. Prepaid Expenses
The breakdown of Prepaid Expenses is as follows:
$000
----------------------------
September 30, December 31,
Description 2005 2004
----------- ------------- ------------
Prepaid transportation costs 1,751 1,151
Advanced payments for materials and supplies 2,869 1,461
Prepaid insurance 591 568
Other prepaid expenses 72 292
----- -----
Total prepaid expenses 5,283 3,472
===== =====
Prepaid transportation costs represent prepayments of export tariffs to CJSC
KazTransOil ("KTO"), a 100% subsidiary of KMG, necessary to sell oil on the
export market, which is expensed in the period the related oil revenue is
recognized. Advanced payments for materials and supplies represent prepayments
for general materials and supplies to be used in the development of the
Karakuduk Field.
4. Asset Retirement Obligation
FASB No. 143 requires entities to record the fair value of the liability for
asset retirement obligations (ARO) in the period in which the liability is
incurred, if a reasonable estimate of fair value can be made. The associated
asset retirement costs are capitalized as part of the carrying amount of the
long-lived asset.
Since 1995, the core business of the Company has been the development of the
Karakuduk Field. The Company has developed an asset that is capable of
producing, processing and transporting crude oil to export markets. The field
still requires up to possibly 80 new wells, but the oil processing and
transportation infrastructure, apart from the obligatory gathering lines and up
to four more gathering stations, are in place. However, further infrastructure
development is planned to increase profitability of the operation, utilize gas
and to maximize oil and produced fluid processing. The Company is legally
required under the Agreement to restore the field to its original condition.
7
Chaparral Resources, Inc.
Notes to Consolidated Condensed Financial Statements (Unaudited)
(continued)
4. Asset Retirement Obligation (continued)
The following table shows movements in the Company's asset retirement obligation
liability:
$000
-----------------------------
September 30, September 30,
2005 2004
------------- -------------
Asset retirement obligation at beginning of period 1,232 804
Accretion expense 110 67
Additional provision for new wells 175 204
----- -----
Asset retirement obligation at end of period 1,517 1,075
===== =====
5. Change in Control
In May 2004, Nelson purchased from Central Asian Industrial Holdings, N.V.
("CAIH") 22,925,701 shares of Chaparral, representing approximately 60% of
Chaparral's issued and outstanding common stock. As part of the transaction, a
Stock Purchase Warrant exercisable for 3,076,923 shares of the Company's common
stock originally issued to CAIH, and a promissory note of the Company payable to
CAIH, with a principal amount of $4 million (see Note 6), were transferred by
CAIH to Nelson. The total purchase price was $23.9 million. On October 14, 2005,
approximately 65% of the outstanding share capital of Nelson was acquired by
LUKOIL Overseas Holding Ltd.
6. Loans
The Note
--------
In May 2002, the Company received a total equity and debt capital infusion of
$45 million, which was partially utilized to repay a substantial portion of the
Company's loan agreement with Shell Capital, Inc. (the "Shell Capital Loan").
The Company received a total investment of $12 million from CAIH, including $8
million in exchange for 22,925,701 shares, or approximately 60%, of the
Company's outstanding common stock, and $4 million in exchange for a three year
note bearing interest at 12% per annum (the "Note"). Along with the Note, CAIH
received a warrant to purchase 3,076,923 shares of the Company's common stock at
$1.30 per share (the "Warrant"). Additionally, Kazkommertsbank, an affiliate of
CAIH, provided KKM with a credit facility totaling $33 million (the "KKB Credit
Facility"), consisting of $28 million that was used to repay a portion of the
Shell Capital Loan and $5 million that was made available for KKM's working
capital requirements. The Company paid CAIH $1.79 million as a related
restructuring fee.
The Note was recorded net of a $2.47 million discount, based on the fair market
value of the Warrant issued in conjunction with the Note. The discount was
amortized using the effective interest rate over the original life of the Note.
The principal balance of the Note was originally due on May 10, 2005 and accrued
interest is payable quarterly. On March 24, 2005, Chaparral and CAP-G signed a
Promissory Note Amendment Agreement pursuant to which a $1 million prepayment of
the Note was made on March 31, 2005 and the maturity of the remaining balance of
the Note was extended to May 10, 2006 (see further discussion below).
In June 2002, the Company prepaid $2 million of the $4 million outstanding
principal balance of the Note. As a result, the Company recognized an
extraordinary loss on the early extinguishment of debt of $1.22 million from the
write-off of 50% of the unamortized discount on the Note. The extraordinary loss
was netted against the extraordinary gain from the restructuring of the Shell
Capital Loan. In March 2004, the Company re-borrowed the $2 million.
8
Chaparral Resources, Inc.
Notes to Consolidated Condensed Financial Statements (Unaudited)
(continued)
6. Loans (continued)
In May 2004, the CAIH shares, the Warrant and the Note were purchased by Nelson.
On March 24, 2005, Chaparral and CAP-G signed a Promissory Note Amendment
Agreement with Nelson. This provided for a prepayment of $1 million of the $4
million due to be repaid to Nelson on May 10, 2005 under the existing $4 million
loan note and the replacement of the existing loan note with a new loan note for
$3 million on substantially similar terms, but with an increase in the interest
rate from 12% to 14% from May 10, 2005 and an extension of the maturity date of
one year to May 10, 2006. On March 31, 2005 the $1 million prepayment was made,
the existing loan note was cancelled and the new loan note was signed.
KKB Credit Facility
-------------------
As mentioned above, in May 2002, KKM established the KKB Credit Facility, a
five-year, $33 million credit line with Kazkommertsbank. The KKB Credit Facility
consisted of a $30 million non-revolving line and a $3 million revolving line,
both of which were fully borrowed by KKM in May 2002. The Company recognized
$2.69 million and $1.71 million of interest expense on the KKB Credit Facility
for the nine months ended September 30, 2004 and 2005 respectively.
The non-revolving portion of the KKB Credit Facility accrued simple interest at
an annual rate of 14% and was repayable over a five-year period with final
maturity in May 2007. Accrued interest was payable quarterly, beginning in
December 2002, and KKM began making quarterly principal repayments in May 2003.
The revolving portion of the KKB Credit Facility accrued simple interest at an
annual rate of 14%. The revolver was loaned to KKM for short-term periods up to
one year, but KKM had the right to re-borrow the funds through May 2006 with
final repayment due in May 2007. On December 30, 2003, Kazkommertsbank increased
the revolving portion of the KKB Credit Facility from $3 million to $5 million.
On the same date, KKM borrowed the additional $2 million to finance ongoing
operations. The additional $2 million accrued interest at 14%. Accrued interest
on the revolving loan was payable at maturity.
The original KKB Credit Facility included repayment terms of three years and
four years for the non-revolving and revolving portions, respectively, with an
option to extend the final maturity date for repayment of the entire KKB Credit
Facility to five years. KKM exercised the option as of May 2002.
On July 1, 2005, the total outstanding principal of $21 million of the KKB
Credit Facility, together with outstanding interest, was repaid. The BNP/KBC
Credit Facility (see below) provided the funds for this repayment.
BNP/KBC Credit Facility
-----------------------
On March 24, 2005, KKM signed a $40 million Structured Crude Oil Pre-export
Credit Facility Agreement with BNP Paribas (Suisse) SA ("BNP") and KBC Bank N.V.
(the "BNP/KBC Credit Facility"). On June 30, 2005, $32 million was drawn down
from this facility. For six months from 30 June, 2005 the facility is a
revolving credit, after which the amount outstanding becomes a term loan
repayable in 36 equal monthly installments commencing on December 30, 2005. The
purpose of the loan is to refinance the KKB Credit Facility, fund future
development costs and fund fees related to the facility.
Each year the lenders may propose, but are under no obligation to do so, an
extension of the facility by one year, for an agreed fee, and/or an increase of
the facility amount for an agreed fee. Each month during the term loan period,
KKM may make full or partial prepayments of the facility at no extra cost.
Partial prepayments must be for amounts of $2 million or more.
9
Chaparral Resources, Inc.
Notes to Consolidated Condensed Financial Statements (Unaudited)
(continued)
6. Loans (continued)
The interest rate applicable under the facility is LIBOR plus 3.25% in the first
year and LIBOR plus 4.00% thereafter. Interest is payable monthly. Fees paid by
KKM include a 1.75% arrangement fee, a 1.65% p.a. commitment fee on the unused
commitment during the revolving credit period, $100,000 for the lenders' legal
costs and $15,000 for agency and technical bank fees. Fees payable include
$15,000 per quarter in advance for agency and technical bank fees. A total of
$0.8 million has been accrued for the arrangement fee and legal costs which is
being amortized over the life of the facility.
As part of the BNP/KBC Credit Facility conditions, an Offtake Agreement was
signed in June 2005 with Vitol Central Asia S.A. ("Vitol") whereby KKM is
obligated to sell to Vitol, and Vitol is obligated to buy, all of KKM's crude
oil production available for export at international market prices for five
years from July 1, 2005, with step-in rights in favor of the lenders. In
accordance with the BNP/KBC Credit Facility conditions, accounts receivable from
Vitol are pledged as collateral for the loan. In addition, a performance and
financial guarantee was issued by Nelson (the "Nelson Guarantee") in support of
all amounts owing by KKM under the BNP/KBC Credit Facility. Under a separate
agreement, in consideration for issuing the Nelson Guarantee, KKM will pay
Nelson, annually in advance, a fee of 2.5% p.a. on the facility amount of $40
million for the first six months and on the daily principal amount of the loan
outstanding during the term period. An amount of $1.0 million, which was paid in
July for the estimated first years guarantee fee, has been accrued in June and
is being amortized over twelve months.
A further condition of the BNP/KBC Credit Facility is that KKM enter into a
Crude Oil Hedging Agreement before the end of August 2005. Nelson entered into
such a hedging agreement with BNP, for the benefit of KKM, in April 2005, and
this agreement was novated in favor of KKM during the quarter. Under this
agreement, KKM has the option each month, from April 2005 to December 2005, to
require BNP to pay it an amount per barrel of specified monthly amounts of crude
oil equivalent to the excess of $33.00 per barrel over the monthly average for
that month of dated Brent. The crude oil amounts specified are 75,000 barrels
per calendar month during the second quarter of 2005, 160,000 barrels per
calendar month during the third quarter of 2005 and 170,000 barrels per calendar
month during the last quarter of 2005. Nelson paid BNP $267,300 as
consideration, equivalent to $0.22 per barrel.
KKM is subject to certain pledges, covenants, and other restrictions under the
BNP/KBC Credit Facility, including, but not limited to, the following:
(i) KKM has signed an Offtake Agreement for 100% of its export production,
with step-in rights in favor of the lenders;
(ii) Nelson has provided a written guarantee to the lenders that it will
repay the BNP/KBC Credit Facility in the event KKM fails to do so;
(iii) KKM may not incur additional indebtedness or pledge its assets to
another party without the written consent of the lenders;
(iv) Subordination of existing loans, including inter-company, and any
additional loans;
(v) KKM may not pay dividends without the written consent of the lenders;
(vi) Nelson to maintain a controlling interest in KKM; and
(vii) A requirement to maintain a minimum credit balance in a "Collection
Account". This balance should always exceed $1.5 million.
The BNP/KBC Credit Facility stipulates certain events of default, including, but
not limited to, KKM's inability to meet the terms of the BNP/KBC Credit Facility
and the Offtake Agreement, default by KKM or Nelson under any other agreements
and material litigation involving Nelson or KKM. If an event of default does
occur and is not waived by the lenders, they can require KKM to immediately
repay the full amount outstanding under the facility and may enforce the Nelson
Guarantee and their step-in rights under the Offtake Agreement.
10
Chaparral Resources, Inc.
Notes to Consolidated Condensed Financial Statements (Unaudited)
(continued)
6. Loans (continued)
The maturity schedule of the Company's indebtedness under the BNP/KBC Credit
Facility as of September 30, 2005, is as follows:
Date Principal Amount Due
---- --------------------
$000
2005 472
2006 5,667
2007 5,667
2008 5,194
--------------------
Total principal due 17,000
====================
The loans are shown in the balance sheet net of the loan discount, which was nil
at September 30, 2005 and $222,000 at December 31, 2004.
7. Income Taxes
Income tax expense as reported relates entirely to foreign income taxes provided
on the Company's operations within the Republic of Kazakhstan. KKM's principal
agreement with the government of the Republic of Kazakhstan for the exploration,
development and production of oil in the Karakuduk Field specifies the income
taxes and other taxes applicable to KKM, which is subject to the tax laws of the
Republic of Kazakhstan. The Company has used the best estimates available to
determine its current and deferred tax liabilities within Kazakhstan.
8. Capital Commitments
On December 31, 2004, the Company's contract with KazMunayGas-Drilling ("KMGD"),
an affiliate of KMG, for one development drilling rig currently operating in the
Karakuduk Field, expired. The same rig is now contracted through Oil and Gas
Drilling and Exploration of Kracow ("OGEC") for a one year term to December 31,
2005. The minimum payments under the drilling contract with OGEC for 2005 are
$4.50 million. The Company's other drilling and operations related contracts can
either be cancelled within 30 days or are on a call-off (as required) basis.
During the third quarter the Company entered into contracts with two local
contractors in connection with the construction of the rail oil loading facility
at Station 6 between Sai-Utes and Beynu approximately 30 km from the field. The
first contract with Temir Zholly Service is for construction of approximately 5
km of rail line and associated infrastructure for a total of $1.46 million. The
second is with Akmaral for the construction of a tank farm with a volume of
14,000 tonnes. This contract has a value of $1.70 million.
The Company has no other significant commitments other than those incurred
during the normal performance of the work program to develop the Karakuduk
Field.
11
Chaparral Resources, Inc.
Notes to Consolidated Condensed Financial Statements (Unaudited)
(continued)
9. Related Party Transactions
In August 2004, the Company approved a two-year agreement with Nelson to provide
corporate administrative services and financial advisory services (the "Service
Agreement") to support its business activities. The Service Agreement is
effective as of June 1, 2004 and can be terminated upon 30 days written notice
by either party. In consideration for these services Nelson will receive a fixed
monthly fee of $20,000 for administrative services and $25,000 for financial
advisory services (the "Management Fee"). As part of the Service Agreement,
Nelson is also required to provide personnel to cover Chaparral's executive and
managerial needs. The cost of executive and managerial personnel will be
allocated on the basis of the cost of personnel involved and on the percentage
of time actually spent by such personnel on matters related to Chaparral, as
mutually agreed by the parties from time to time. In addition, Nelson will use
its greater buying power to obtain more favorable rates for goods and services,
including insurance coverage, for Chaparral. These expenditures will be passed
to Chaparral at cost with a ten percent mark-up. For the nine months to
September 30, 2005, the Company has booked $585,500 for the Management Fee, the
executive and managerial cost, insurance coverage and the mark-up under the
Service Agreement.
In June 2004, KKM entered into a three year agency agreement with Nelson (the
"Marketing Agreement"), whereby Nelson becomes the duly authorized, exclusive
agent for the purpose of marketing crude oil, and is empowered to represent the
interests of KKM in relations with governmental authorities and commercial
organizations and also enter into contracts and agreements and any other
documents necessary for and related to the marketing of crude oil. The Marketing
Agreement is effective as of June 1, 2004 and can be terminated upon 90 days
written notice by either party. As consideration for the services provided under
the Marketing Agreement, KKM shall pay Nelson a fixed fee of $20,000 per month
and a variable fee of five US cents per barrel of total production in a
reporting calendar month, if the amount of supplies to the local market in that
month is more than 10% of the total amount of production, or eight US cents per
barrel of total production in a reporting calendar month, if the amount of
supplies to the local market in that month is less than 10% of the total amount
of production (the "Marketing Fee"). For the period ending September 30, 2005,
$400,500 was accrued under the Marketing Agreement.
In 2003, the Company approved a one-year agreement with OJSC Kazkommerts
Securities ("KKS"), an affiliate of Kazkommertsbank. The agreement was effective
as of January 7, 2003 and provided for KKS to assist the Company's senior
management with financial advisory and investment banking services. In
consideration for these services KKS received a monthly fee of $25,000 (the
"Advisory Fee"). The agreement with KKS was cancelled as of April 30, 2004.
Kazkommerts Policy, an affiliate of Kazkommertsbank, is the major insurer of
KKM's oil and gas activities.
KKM has a contract to transport 100% of its oil sales through the pipeline owned
and operated by KTO, a wholly owned subsidiary of KMG, the 40% minority
shareholder in KKM until December 2004. The rates for transportation are in
accordance with those approved by the government of the Republic of Kazakhstan.
Currently, the use of the KTO pipeline system is the only viable method of
exporting KKM's production. As KTO notifies KKM of the export sales allocated to
KKM on a monthly basis, KTO controls transportation of export sales.
KKM makes a prepayment for crude transportation costs based upon the allocation
of export sales received from the Ministry of Energy and Mineral Resources of
the Republic of Kazakhstan. This prepayment includes pipeline costs charged by
the operators of the pipeline systems outside Kazakhstan and is dependent upon
the point of sale of KKM's exports. For the nine months ended September 30,
2005, KKM incurred $11.6 million for transportation costs with KTO. As of
September 30, 2005, KKM had a prepayment balance of $1.3 million with KTO in
respect of sales to be made in October 2005 and a further $0.4 million in
respect of sales to be made in November 2005. Comparably, for the nine months
ended September 30, 2004, KKM incurred $8.3 million for transportation costs
with KTO. As of December 31, 2004, KKM had a prepayment balance of $1.2 million
with KTO in respect of sales that were not completed until January 2005.
12
Chaparral Resources, Inc.
Notes to Consolidated Condensed Financial Statements (Unaudited)
(continued)
9. Related Party Transactions (continued)
KTO charges KKM for associated costs of oil storage within their pipeline
system, sales commission, customs clearance fees in respect of export sales and
for water through the Volga Water pipeline. Amounts recognized for these
services during the nine months ended September 30, 2005 and 2004 were $346,472
and $185,000, respectively.
The total amounts of the transactions with the above related companies for the
nine months ended September 30, 2005 and 2004 are as follows:
$000
---------------
2005 2004
------ ------
Nelson 1,684 1,236
KKS -- 100
Kazkommerts Policy 345 539
KTO 11,977 9,594
KMGD 191 4,624
Accounts payable balance to affiliates as at September 30, 2005 and December 31,
2004 are as follows:
$000
---------------
2005 2004
------ ------
Nelson 357 --
Kazkommerts Policy -- 195
KTO 198 8
KMGD -- 371
------ ------
555 574
====== ======
The loans with Kazkommertsbank and Nelson are disclosed in Note 6.
10. Contingencies
Taxation
--------
The existing legislation with regard to taxation in the Republic of Kazakhstan
is constantly evolving as the Government manages the transition from a command
to a market economy. Tax and other laws applicable to the Company are not always
clearly written and their interpretation is often subject to the opinions of the
local or main State Tax Service. Instances of inconsistent opinions between
local, regional and national tax authorities are not unusual.
Basis of Accounting
-------------------
KKM maintains its statutory books and records in accordance with U.S. generally
accepted accounting principles and calculates taxable income or loss using the
existing Kazakh tax legislation in effect on August 30, 1995, the date the
Agreement was signed. The Company considers these accounting methods correct
under the terms of the Agreement. The Republic of Kazakhstan currently requires
companies to comply with Kazakh accounting regulations and to calculate tax
profits or losses in accordance with these regulations as well as the prevailing
tax law.
13
Item 2 - Management's Discussion and Analysis of Financial Condition and Results
of Operations
1. Liquidity and Capital Resources
General Liquidity Considerations
--------------------------------
Going Concern
-------------
Our financial statements have been presented on the basis that the Company is a
going concern, which contemplates the realization of assets and satisfaction of
liabilities in the normal course of business. Until recently, Chaparral had a
working capital deficiency. In addition, we have experienced limitations in
obtaining 100% export quota for the sale of our hydrocarbons. Previously these
conditions raised substantial doubt about our ability to continue as a going
concern. However, due to recently completed refinancing of the Company's debt
(see below), we now expect to be able to meet all expenditure and cash flow
requirements through the next twelve months.
Chaparral stabilized the export sales/local market deliveries ratio in 2004,
which had significantly improved from 2002 to 2003. For the year ended December
31, 2004, Chaparral sold approximately 2,544,000 barrels, or 92% of total sales
(2003: 2,591,000 barrels, 96%), at world market prices and 214,000 barrels, or
8% (2003: 103,000 barrels, 4%), at domestic market prices. During the nine
months to September 30, 2005, exports accounted for 93% of total sales volume.
On March 24, 2005, KKM signed a $40 million Structured Crude Oil Pre-export
Credit Facility Agreement with BNP Paribas (Suisse) S.A. and KBC Bank N.V. (the
"BNP/KBC Credit Facility"). On June 30, 2005, $32 million of funds from this
facility were drawn down. On July 1, 2005, the total outstanding principal of
$21 million of the KKM Credit Facility, together with outstanding interest, was
repaid. See Item 1 Note 6 for further details of the BNP/KBC Credit Facility. In
addition, on March 24, 2005, Chaparral and CAP-G signed a Promissory Note
Amendment Agreement with Nelson (the "Amendment Agreement"). This provided for a
prepayment of $1 million of the $4 million due to be repaid to Nelson on May 10,
2005 under the existing $4 million loan note and the replacement of the existing
loan note with a new loan note for $3 million on substantially similar terms,
but with an increase in the interest rate from 12% to 14% from May 10, 2005 and
an extension of the maturity date of one year to May 10, 2006. On March 31, 2005
the $1 million prepayment was made, the existing loan note was cancelled and the
new loan note was signed. See Item 1 Note 6. The BNP/KBC Credit Facility and
Amendment Agreement significantly improve the Company's financial position,
enabling it to meet all its current financial obligations and continue with
field development.
Liquidity and Capital Resources
-------------------------------
We are presently engaged in the development of the Karakuduk Field, which
requires substantial cash expenditures for drilling, well completions,
workovers, oil storage and processing facilities, pipelines, gathering systems,
water injection facilities, plant and equipment (pumps, transformer sub-stations
etc.), a rail loading facility and gas utilization. We have invested
approximately $177 million in the development of the Karakuduk Field and have
drilled 63 new wells and re-completed 13 of the pre-existing wells at the field
by September 30, 2005. Total capital expenditures for the nine months to
September 30, 2005 were approximately $22 million. Capital expenditures are
estimated to be at least $140 million from 2005 through 2009, including the
drilling of up to 110 more wells over this period. This is higher than
previously stated since in 2005 the Company has commissioned and received a new
field development project that was prepared after the state reserves committee
of the Republic of Kazakhstan approved a higher than previously reported
reserves estimate for the Karakuduk field. We anticipate 2005 capital
expenditures of approximately $35 million.
We expect to finance the continued development of the Karakuduk Field primarily
through cash flows from the sale of crude oil. During the third quarter of 2005,
KKM sold approximately 984,000 barrels of crude oil for $50 million, compared to
14
794,000 barrels for $33 million in the second quarter of 2005. As mentioned
above, KKM has recently secured $40 million of new funding with which it has
re-financed the loans provided by Kazkommertsbank. Current daily oil production
is in excess of 12,450 barrels per day. This is 40% higher than at the same time
last year.
During the remainder of 2005, KKM expects to further increase production by
drilling 3 more new wells, converting at least 6 more wells to artificial lift
and converting 2 more wells to water injection wells. Work on the utilization of
associated gas has resulted in the gas pipeline from the field to the export
point at Station 6 having been completed. In the final quarter of the year the
Company will add the necessary condensate traps to this line and source two high
capacity gas driven gas compressors from the United States. Construction of the
rail loading facility at station 6 commenced in late September and is
anticipated to be operational by August 2006.
In addition, our short and long-term liquidity is impacted by local oil sales
obligations imposed on oil and gas producers within Kazakhstan to supply local
energy needs, and our ability to obtain export quota necessary to sell our crude
oil production on the international market. Under the terms of the Agreement, we
have a right to export, and receive export quota for, 100% of the production
from the Karakuduk Field. The domestic market does not permit world market
prices to be obtained, resulting in, on average, $29 lower cash flow per barrel
sold into the local market in the nine months to September 30, 2005.
Furthermore, the Government has not allocated sufficient export quota to allow
us to sell all of our available crude oil production on the world market. We are
taking steps to reduce our local market obligations and to obtain an export
quota that will enable us to sell all of our crude oil production on the export
market. The Company has determined that it is no longer in its the best
interests to pursue arbitration proceedings in Switzerland for the breach of the
Agreement by the Government of Kazakhstan, instead we intend to seek an amicable
resolution of this matter. If the matter cannot be resolved in a satisfactory
manner, we have, however, reserved our right to commence formal arbitration
proceedings pursuant to our contractual arrangements with the Government.
No assurances can be provided, however, that an amicable resolution will be
reached, or that if arbitration is instituted, it will be successful or that if
successful, Chaparral will be able to enforce the award in Kazakhstan, or that
we will be able to export 100% or a significant portion of production or that we
will be able to obtain additional cash flow from operations to meet working
capital requirements in the future.
During the nine months to September 30, 2005 the Company continued with the
development of the Karakuduk Field. As of September 30, 2005 the total field
well count had risen to 76 compared to 66 on December 31, 2004. The producing
well count at the field as of September 30, 2005 was 58 wells compared to 45 at
the end of 2004. One producing well was converted to an injection well.
Production for the nine months to September 30, 2005 was 2.75 million barrels,
equivalent to 10,075 barrels of oil per day ("bopd"), compared to 2.19 million
barrels, or 7,993 bopd, for the nine months to September 30, 2004, an increase
of 26%. The Company sold 307,641 tonnes to export markets (93% of total sales)
and 22,000 tonnes locally during the nine months to September 30, 2005, compared
with 240,000 tonnes exported (91% of total sales) and 25,000 tonnes to the local
market in the nine months to September 30, 2004.
Drilling activity continued in the third quarter. The Company drilled 3 wells
(9,609 m) in the third quarter of 2005 compared to 3.6 wells (11,409m) in the
second quarter of the year. The reduction in meterage was due to the fact that
about 20 days were lost as the rig required essential maintenance and a
scheduled load test of the derrick.
During October our average production exceeded 12,000 bopd, and we expect that
this level of production will be maintained for the remainder of the year.
The Company will continue with the development of the Karakuduk Field throughout
the remainder of 2005. One drilling rig and two workover rigs will operate at
the field. At the beginning of the year, the Company forecasted that up to 13
wells would be drilled for the whole year, including one horizontal well, the
first such well to be drilled at Karakuduk. We will complete this programme as
we expect to drill a further 3 wells during this quarter and commence drilling
the horizontal well before the year end.
15
Capital Commitments and Other Contingencies
-------------------------------------------
On December 31, 2004, the Company's contract with KMGD, an affiliate of KMG, for
one development drilling rig currently operating in the Karakuduk Field,
expired. The same rig is now contracted through Oil and Gas Drilling and
Exploration of Kracow ("OGEC") for a one year term to December 31, 2005. The
minimum payments under the drilling contract with OGEC for 2005 are $4.50
million. The Company's other drilling and operations related contracts can
either be cancelled within 30 days or are on a call-off (as required) basis.
The Company has no other significant commitments other than those incurred
during the normal performance of the work program to develop the Karakuduk
Field.
Our operations may be subject to other regulations by the government of the
Republic of Kazakhstan or other regulatory bodies responsible for the area in
which the Karakuduk Field is located. In addition to taxation, customs
declarations and environmental controls, regulations may govern such things as
drilling permits and production rates. Drilling permits could become difficult
to obtain or prohibitively expensive. Production rates could be set so low that
they would make production unprofitable. These regulations may substantially
increase the costs of doing business and may prevent or delay the starting or
continuation of any given development project.
All regulations are subject to future changes by legislative and administrative
action and by judicial decisions. Such changes could adversely affect the
petroleum industry in general and us in particular. It is impossible to predict
the effect that any current or future proposals or changes in existing laws or
regulations may have on our operations.
2. Results of Operations
Results of Operations for the Three Months Ended September 30, 2005 Compared to
the Three Months Ended September 30, 2004
-------------------------------------------------------------------------------
Our operations for the three months ended September 30, 2005 resulted in a net
income of $13.32 million compared to a net income of $3.56 million for the three
months ended September 30, 2004. The $9.76 million increase in our net income is
primarily a result of higher crude prices and higher sales volumes.
Revenues. Revenues were $50.44 million for the third quarter of 2005 compared
with $22.08 million for the third quarter of 2004. The $28.36 million increase
is the result of higher crude prices and sales volumes achieved during the third
quarter of 2005 as compared to the same period of 2004. During the third quarter
of 2005, we sold approximately 984,000 barrels of crude oil, recognizing $50.44
million in revenue, or $51.24 per barrel after quality differential losses.
Comparably, we sold approximately 674,000 barrels of crude oil, recognizing
$22.08 million in revenue, or $32.74 per barrel, during the third quarter of
2004. The result is a positive price variance of $18.21 million and a positive
volume variance of $10.15 million.
Transportation and Operating Expenses. Transportation costs for the third
quarter of 2005 were $4.97 million, or $5.05 per barrel, and operating costs
associated with sales were $4.05 million, or $4.11 per barrel. Comparatively,
transportation costs for the third quarter of 2004 were $3.33 million, or $4.94
per barrel, and operating costs associated with sales were $1.76 million, or
$2.61 per barrel. The transportation cost per barrel during the third quarter of
2005 is similar to that of the 2004 third quarter. The main reason for the
increase in operating cost per barrel is changes in cost allocation procedures
resulting in a lower percentage of field expenditures being capitalized.
Depreciation and Depletion. Depreciation and depletion expense was $7.44 million
for the third quarter of 2005 compared with $4.28 million for the third quarter
of 2004. The $3.16 million increase is the result of higher sales volumes and a
higher effective depletion rate which is due to a proportionately higher
increase in future capital costs associated with increased reserves. During the
third quarter of 2005, the Company recognized a total depletion expense of $7.23
million or $7.09 per barrel produced, compared to $4.13 million or $5.41 per
barrel produced for the third quarter of 2004.
16
Estimates of our proved oil and gas reserves are prepared by an independent
engineering company in accordance with guidelines established by the Securities
and Exchange Commission ("SEC"). Those guidelines require that reserve estimates
be prepared under existing economic and operating conditions with no provisions
for increases in commodity prices, except by contractual arrangement. Estimation
of oil and gas reserve quantities is inherently difficult and is subject to
numerous uncertainties. Such uncertainties include the projection of future
rates of production, export allocation, and the timing of development
expenditures. The accuracy of the estimates depends on the quality of available
geological and geophysical data and requires interpretation and judgment.
Estimates may be revised either upward or downward by results of future
drilling, testing or production. In addition, estimates of volumes considered to
be commercially recoverable fluctuate with changes in commodity prices and
operating costs. Our estimates of reserves are expected to change as additional
information becomes available. A material change in the estimated volumes of
reserves could have an impact on the depletion rate calculation and the
financial statements.
Interest Expense. Interest expense was $1.05 million for the third quarter of
2005 compared to $1.26 million for the third quarter of 2004. The decrease is
primarily a result of lower average loan balances outstanding.
General and Administrative Expense. General and administrative costs increased
from $1.45 million for the three months ended September 30, 2004 to $1.67
million for the three months ended September 30, 2005. The increase of $0.22
million is primarily due to an accrual of $0.18 million for Kazakh withholding
tax payable on management fees charged by CAP-G to KKM.
Income Tax Expense. Income tax expense increased from $3.12 million for the
three months ended September 30, 2004 to $8.28 million for the three months
ended September 30, 2005, representing 47% and 38% respectively of pre-tax
income. The tax charge has increased as income has increased. The effective tax
rate has decreased largely because Chaparral parent company administrative
costs, which are not deductible against KKM's Kazakh taxable income, are smaller
relative to pre-tax income as KKM's profits rise.
Results of Operations for the Nine Months Ended September 30, 2005 Compared to
the Nine Months Ended September 30, 2004
------------------------------------------------------------------------------
Our operations for the nine months ended September 30, 2005 resulted in a net
income of $23.75 million compared to a net income of $5.49 million for the nine
months ended September 30, 2004. The $18.26 million increase in our net income
is primarily a result of higher crude prices.
Revenues. Revenues were $107.92 million for the nine months to September 30,
2005 compared with $55.16 million for the nine months to September 30, 2004. The
$52.76 million increase is the result of higher crude prices and sales volumes
achieved during the nine months to September 30, 2005 as compared to the same
period of 2004. During the nine months to September 30, 2005, we sold
approximately 2,377,000 barrels of crude oil, recognizing $107.92 million in
revenue, or $45.40 per barrel after quality differential losses. Comparably, we
sold approximately 2,029,000 barrels of crude oil, recognizing $55.16 million in
revenue, or $27.19 per barrel, for the nine months to September 30, 2004. The
result is a positive price variance of $43.30 million and a positive volume
variance of $9.46 million.
Transportation and Operating Expenses. Transportation costs for the nine months
to September 30, 2005 were $12.51 million, or $5.26 per barrel, and operating
costs associated with sales were $11.44 million, or $4.81 per barrel.
Comparatively, transportation costs for the nine months to September 30, 2004
were $9.55 million, or $4.71 per barrel, and operating costs associated with
sales were $5.66 million, or $2.79 per barrel. The increase in transportation
cost per barrel during the nine months to September 30, 2005 is the result of
higher tariffs imposed on the Company. The main reason for the increase in
operating cost per barrel is changes in cost allocation procedures resulting in
a lower percentage of field expenditures being capitalized.
17
Depreciation and Depletion. Depreciation and depletion expense was $18.29
million for the nine months to September 30, 2005 compared with $12.81 million
for the nine months to September 30, 2004. The $5.48 million increase is the
result of higher sales volumes and a higher effective depletion rate which is
due to a proportionately higher increase in future capital costs associated with
increased reserves. During the nine months to September 30, 2005, the Company
recognized a total depletion expense of $17.70 million or $6.44 per barrel
produced, compared to $12.35 million or $5.64 per barrel produced for the nine
months to September 30, 2004.
Interest Expense. Interest expense was $3.33 million for the nine months to
September 30, 2005 compared to $3.76 million for the nine months to September
30, 2004. Interest charges under the KKB Credit Facility were $0.62 million
lower due to reduction in principal outstanding, but this was partially offset
by no interest being capitalized within oil and gas assets in the nine months to
September 30, 2005 compared to $0.26 million in the nine months to September 30,
2004.
General and Administrative Expense. General and administrative costs decreased
from $5.20 million for the nine months ended September 30, 2004 to $4.71 million
for the nine months ended September 30, 2005. The decrease of $0.49 million is
primarily due to accrued severance costs for former executives in the nine
months to September 30, 2004, reductions in expatriate staff numbers and lower
salaries and wages, partially offset by an accrual of $0.76 million for Kazakh
withholding tax payable on management fees charged by CAP-G to KKM for the
period January 2004 to September 2005. This withholding tax liability has only
recently been identified due to a review of the treatment of management changes
in KKM's income tax returns.
Income Tax Expense. Income tax expense increased from $6.15 million for the nine
months ended September 30, 2004 to $15.79 million for the nine months ended
September 30, 2005, representing 53% and 40% respectively of pre-tax income. The
tax charge has increased as income has increased. The effective tax rate has
decreased largely because Chaparral parent company administrative costs, which
are not deductible against KKM's Kazakh taxable income, are smaller relative to
pre-tax income as KKM's profits rise. The tax charge for the quarter ended
September 30, 2005 is also reduced as a result of a favorable settlement of
KKM's 2004 tax returns.
3. Commodity Prices for Oil and Gas
Our revenues, profitability, growth and value are highly dependent upon the
price of oil. Market conditions make it difficult to estimate prices of oil or
the impact of inflation on such prices. Oil prices have been volatile, and it is
likely they will continue to fluctuate in the future. Various factors beyond our
control affect prices for oil, including supplies of oil available worldwide and
in Kazakhstan, the ability of OPEC to agree to maintain oil prices and
production controls, political instability or armed conflict in Kazakhstan or
other oil producing regions, the price of foreign imports, the level of consumer
demand, the price and availability of alternative fuels, the availability of
transportation routes and pipeline capacity, and changes in applicable laws and
regulations.
4. Inflation and Exchange Rates
We cannot control prices received from our oil sales and to the extent we are
unable to pass on increases in operating costs, we may be affected by inflation.
The devaluation of the Tenge, the currency of the Republic of Kazakhstan, could
significantly decrease the value of the monetary assets that we hold in
Kazakhstan as well as our assets in that country that are based on the Tenge.
KKM retains the majority of its cash and cash equivalents in U.S. dollars, but
KKM's statutory tax basis in its assets and VAT receivables are all denominated
in Tenge and subject to the effects of devaluation. Local tax laws allow basis
adjustments to offset the impact of inflation on statutory tax basis assets, but
there is no assurance that any adjustments will be sufficient to offset the
effects of inflation in whole or in part. If not, KKM may be subject to much
higher income tax liabilities within Kazakhstan due to inflation or devaluation
of the local currency. Additionally, devaluation may create uncertainty with
respect to the future business climate in Kazakhstan and to our investment in
that country. As of September 30, 2005, the exchange rate was 133.89 Tenge per
U.S. dollar compared to 130.00 as of December 31, 2004.
18
5. Critical Accounting Policies
The preparation of the Company's consolidated financial statements requires
management to make estimates, assumptions and judgments that affect the
Company's assets, liabilities, revenues and expenses and disclosure of
contingent assets and liabilities. Management bases these estimates and
assumptions on historical data and trends, current fact patterns, expectations
and other sources of information it believes are reasonable. Actual results may
differ from these estimates under different conditions. For a full description
of the Company's critical accounting policies, see Item 7, Management's
Discussion and Analysis of Financial Condition and Results of Operations in the
Company's 2004 Annual Report on Form 10-K.
6. Special Note Regarding Forward-Looking Statements
Some of the statements in this Quarterly Report on Form 10-Q constitute
"forward-looking statements." Forward-looking statements relate to future events
or our future financial performance. In some cases, you can identify
forward-looking statements by terminology such as "may," "will," "should,"
"expects," "plans," "estimates," "believes," "predicts," "potential," "likely,"
or "continue," or by the negative of such terms or comparable terminology.
Forward-looking statements are predictions based on current expectations that
involve a number of risks and uncertainties. Actual events may differ
materially. In evaluating forward-looking statements, you should consider
various factors, including the risks discussed above. These factors may cause
our actual results to differ materially from any forward-looking statement.
Although we believe that these statements are reasonable, we cannot guarantee
future results, levels of activity, performance or achievements, and you are
encouraged to exercise caution in considering such forward-looking statements.
Unless otherwise required by law, we are not under any duty to update any of the
forward-looking statements after the date of this Quarterly Report on Form 10-Q
to conform these statements to actual results.
Item 3 - Quantitative and Qualitative Disclosures About Market Risk
Foreign Currency
The functional currency is the U.S. dollar. All transactions arising in
currencies other than U.S. dollars, including assets, liabilities, revenue,
expenses, gains, or losses are measured and recorded in U.S. dollars using the
exchange rate in effect on the date of the transaction.
Cash and other monetary assets held and liabilities denominated in currencies
other than U.S. dollars are translated at exchange rates prevailing as of the
balance sheet date (133.89 and 130.00 Tenge per U.S. dollar as of September 30,
2005 and December 31, 2004, respectively). Non-monetary assets and liabilities
denominated in currencies other than U.S. dollars have been translated at the
estimated historical exchange rate prevailing on the date of the transaction.
Exchange gains and losses arising from translation of non-U.S. dollar amounts at
the balance sheet date are recognized as an increase or decrease in income for
the period. See Item 2 section 4 for discussion on inflation and exchange rate
risks.
The Tenge is not a convertible currency outside of the Republic of Kazakhstan.
The translation of Tenge denominated assets and liabilities in these financial
statements does not indicate Chaparral could realize or settle these assets and
liabilities in U.S. dollars.
19
Commodity Prices for Oil
Our revenues, profitability, growth and value are highly dependent upon the
price of oil. Market conditions make it difficult to estimate prices of oil or
the impact of inflation on such prices. Oil prices have been volatile, and it is
likely they will continue to fluctuate in the future. Various factors beyond our
control affect prices for oil, including supplies of oil available worldwide and
in Kazakhstan, the ability of OPEC to agree to maintain oil prices and
production controls, political instability or armed conflict in Kazakhstan or
other oil producing regions, the price of foreign imports, the level of consumer
demand, the price and availability of alternative fuels, the availability of
transportation routes and pipeline capacity, and changes in applicable laws and
regulations.
In addition, under the terms of our Agreement with the government of the
Republic of Kazakhstan, the Company has the right to export, and receive export
quota for, 100% of the production from the Karakuduk Field. However, oil
producers within Kazakhstan are required to supply a portion of their crude oil
production to the local market to meet domestic energy needs. Local market oil
prices are significantly lower than prices obtainable on the export market. For
the nine months ended September 30, 2005, the Company sold 160,000 barrels of
crude oil, or 7% of its total oil sales, to the local market, compared to
183,000 barrels, or 9%, during the nine months ended September 30, 2004. During
the nine months to September 30, 2005, local market prices obtained by the
Company were, on average, $29 per barrel below export market prices, net of
transportation costs. We have attempted, in accordance with the Agreement, to
effect the 100% export of all hydrocarbons produced from the Karakuduk Field,
through discussions with the government of the Republic of Kazakhstan. We plan
to continue to work with the government to increase our export quota and
minimize or eliminate future local sales requirements. In addition, we entered
into an agency agreement with Nelson to assist in reducing our local market
obligation (see Note 9 to the interim financial statements presented in Item 1).
However, no assurances can be provided that we will be able to export a higher
portion of our production and that our cash flow from operations will be
sufficient to meet working capital requirements in the future.
Item 4 - Controls and Procedures
Evaluation of Disclosure Controls and Procedures
We maintain disclosure controls and procedures designed to provide reasonable
assurance that information required to be disclosed in the periodic reports we
file with the SEC is recorded, processed, summarized and reported within the
time periods specified in the rules of the SEC. The Company carried out an
evaluation as of September 30, 2005, under the supervision and the participation
of our management, including our chief executive officer and chief financial
officer, of the design and operation of these disclosure controls and procedures
pursuant to Rules 13a-15(e) under the Securities Exchange Act of 1934. Based
upon that evaluation, our chief executive officer and chief financial officer
concluded that our disclosure controls and procedures are effective in timely
alerting them to material information required to be included in our periodic
SEC filings.
Changes in Internal Controls over Financial Reporting
As a result of the evaluation referred to in the preceding paragraph, there were
no changes that materially affected or are reasonably likely to materially
affect our internal control over financial reporting during the quarter ended
September 30, 2005.
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Part II- Other Information
Item 6 - Exhibits
*31.1 CEO Certification pursuant to Section 302 of the
Sarbanes-Oxley Act of 2002.
*31.2 CFO Certification pursuant to Section 302 of the
Sarbanes-Oxley Act of 2002.
*32.1 CEO Certification pursuant to Section 906 of the
Sarbanes-Oxley Act of 2002.
*32.2 CFO Certification pursuant to Section 906 of the
Sarbanes-Oxley Act of 2002.
* Filed herewith.
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Signatures
Pursuant to the requirements of the Securities Exchange Act of 1934, the
registrant has duly caused this report to be signed on its behalf by the
undersigned thereunto duly authorized.
Dated: November 9, 2005
Chaparral Resources, Inc.
By: /s/ Simon Gill
--------------------------------
Simon Gill
Chief Executive Officer
By: /s/ Charles Talbot
--------------------------------
Charles Talbot
VP Finance and Chief Financial
Officer (Principal Financial and
Accounting Officer)
22