Edgar Filing: BUCKEYE TECHNOLOGIES INC

march3110-10q.htm

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark one)

x QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended March 31, 2010

¨ 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: 33-60032

Buckeye Technologies Inc.

(Exact name of registrant as specified in its charter)

Delaware

(State or other jurisdiction of incorporation)

IRS — Employer Identification No. 62-1518973

1001 Tillman Street, Memphis, TN 38112 901-320-8100

(Address of principal executive offices) (Zip Code) (Registrant’s telephone number,

including area code)

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

Yes x

No ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

Yes ¨

No ¨

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

Large accelerated filer ¨

Accelerated filer x

Non-accelerated filer ¨

Smaller reporting company ¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes ¨

No x

As of April 28, 2010, there were outstanding 39,241,498 Common Shares of the Registrant.

INDEX

BUCKEYE TECHNOLOGIES INC.

ITEM		PAGE

	PART I - FINANCIAL INFORMATION

1.	Financial Statements:

	Condensed Consolidated Statements of Operations for the Three and Nine Months Ended March 31, 2010 and 2009	3

	Condensed Consolidated Balance Sheets as of March 31, 2010 and June 30, 2009	4

	Condensed Consolidated Statements of Cash Flows for the Nine Months Ended March 31, 2010 and 2009	5

	Notes to Condensed Consolidated Financial Statements	6

2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	22

3.	Quantitative and Qualitative Disclosures About Market Risk	31

4.	Controls and Procedures	31


	PART II - OTHER INFORMATION

1A.	Risk Factors	32

6.	Exhibits	32

	SIGNATURES	33

PART I - FINANCIAL INFORMATION

Item 1.

Financial Statements

BUCKEYE TECHNOLOGIES INC.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

(In thousands, except per share data)

	Three Months Ended March 31						Nine Months Ended March 31
	2010			2009			2010			2009
Net sales	$	190,714		$	171,635		$	551,296		$	577,593
Cost of goods sold		157,567			147,765			463,028			495,253
Gross margin		33,147			23,870			88,268			82,340

Selling, research and administrative expenses		11,985			10,601			34,666			34,077
Amortization of intangibles and other		472			465			1,422			1,405
Goodwill impairment loss		-			-			-			138,008
Restructuring costs		2,395			-			3,209			-
Alternative fuel mixture credits		(4,762	)		-			(77,677	)		-
Other operating income		(633	)		-			(724	)		-
Operating income (loss)		23,690			12,804			127,372			(91,150	)

Net interest expense and amortization of debt costs		(3,920	)		(7,206	)		(13,830	)		(22,113	)
Gain (loss) on early extinguishment of debt		(1,537	)		-			(1,372	)		401
Gain (loss) on foreign exchange and other		(421	)		100			(720	)		(518	)

Income (loss) before income taxes		17,812			5,698			111,450			(113,380	)
Income tax expense (benefit)		(1,531	)		1,412			6,592			(1,532	)

Net income (loss)	$	19,343		$	4,286		$	104,858		$	(111,848	)

Earnings (loss) per share
Basic	$	0.50		$	0.11		$	2.71		$	(2.89	)
Diluted	$	0.49		$	0.11		$	2.66		$	(2.89	)

Weighted average shares for earnings per share
Basic		38,785			38,672			38,754			38,682
Effect of diluted shares		853			93			598			-
Diluted		39,638			38,765			39,352			38,682

See accompanying notes.

BUCKEYE TECHNOLOGIES INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands)

	March 31 2010			June 30 2009
	(Unaudited)
Assets
Current assets:
Cash and cash equivalents	$	26,935		$	22,061
Accounts receivable – net		126,981			111,292
Income tax and alternative fuel mixture credits receivable		73,809			9,374
Inventories – net		83,147			87,637
Deferred income taxes and other		6,166			6,507
Total current assets		317,038			236,871

Property, plant and equipment		1,130,402			1,091,313
Less accumulated depreciation		(604,201	)		(564,724	)
		526,201			526,589
Goodwill		2,425			2,425
Intellectual property and other, net		18,886			26,499
Total assets	$	864,550		$	792,384

Liabilities and stockholders’ equity
Current liabilities:
Trade accounts payable	$	32,814		$	30,882
Accrued expenses		43,190			40,804
Total current liabilities		76,004			71,686

Long-term debt		273,476			327,465
Accrued postretirement benefits		22,183			23,235
Deferred income taxes		48,120			48,399
Other liabilities		10,810			3,568
Stockholders’ equity		433,957			318,031
Total liabilities and stockholders’ equity	$	864,550		$	792,384

See accompanying notes.

BUCKEYE TECHNOLOGIES INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

(In thousands)

	Nine Months Ended March 31
	2010			2009
Operating activities
Net income (loss)	$	104,858		$	(111,848	)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation		34,324			36,593
Amortization		2,187			1,886
Loss (gain) on early extinguishment of debt		1,372			(401	)
Deferred income taxes and other		(597	)		(3,399	)
Goodwill impairment loss		-			138,008
Excess tax benefit from stock based compensation		(19	)		-
Changes in operating assets and liabilities:
Accounts receivable		(8,363	)		6,797
Income tax and alternative fuel mixture credits receivable		(64,435	)		-
Inventories		5,247			4,086
Other assets		960			1,189
Accounts payable and other current liabilities		(1,135	)		(23,100	)
Net cash provided by operating activities		74,399			49,811
Investing activities
Purchases of property, plant and equipment		(29,769	)		(34,005	)
Proceeds from State of Florida grant		7,381			-
Other		(311	)		(171	)
Net cash used in investing activities		(22,699	)		(34,176	)
Financing activities
Net borrowings under lines of credit		90,999			(114	)
Payments on long-term debt and other		(145,000	)		(5,358	)
Excess tax benefit from stock based compensation		19			-
Purchase of treasury shares		-			(494	)
Net proceeds from sale of equity interests		694			-
Net cash used in financing activities		(53,288	)		(5,966	)
Effect of foreign currency rate fluctuations on cash		6,462			(1,183	)
Decrease in cash and cash equivalents		4,874			8,486
Cash and cash equivalents at beginning of period		22,061			10,393
Cash and cash equivalents at end of period	$	26,935		$	18,879

See accompanying notes.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

(In thousands)

NOTE 1: BASIS OF PRESENTATION

Our accompanying unaudited condensed consolidated financial statements have been prepared in accordance with United States generally accepted accounting principles (“GAAP”) for interim financial information and with the instructions to Form 10-Q and Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. In the opinion of management, all adjustments (including normal recurring accruals) considered necessary for a fair presentation have been included. Operating results for the three and nine months ended March 31, 2010 are not necessarily indicative of the results that may be expected for the fiscal year ending June 30, 2010. All significant intercompany accounts and transactions have been eliminated in consolidation. For further information and a listing of our significant accounting policies, refer to the financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended June 30, 2009, which was filed with the Securities and Exchange Commission (“SEC”) on August 27, 2009 (“Annual Report”). Except as otherwise specified, references to a year indicate our fiscal year ending on June 30 of the year referenced and comparisons are to the corresponding period of the prior year.

Translation adjustment

Management has determined that the local currency of our German, Canadian, and Brazilian subsidiaries is the functional currency, and accordingly, European euro, Canadian dollar, and Brazilian real denominated balance sheet accounts are translated into U.S. dollars at the rate of exchange in effect at the balance sheet date. Income and expense activity for the period is translated at the weighted average exchange rate during the period. Translation adjustments are included as a separate component of stockholders' equity.

Use of estimates

The preparation of the consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the amounts reported in the consolidated financial statements and accompanying notes. Actual results could differ from the estimates and assumptions used.

Changes in estimates are recognized in accordance with the accounting rules for the estimate, which is typically in the period when new information becomes available to management. Areas in which the nature of the estimate makes it reasonably possible that actual results could materially differ from amounts estimated include: impairment assessments on long-lived assets (including goodwill), allowance for doubtful accounts, inventory reserves, income tax liabilities and contingent liabilities.

Dilutive stock options

Stock options that could potentially dilute basic earnings per share in the future, which were not included in the fully diluted computation because the grant prices were greater than the average market price of common shares for the period, were 81,322 and 776,308 for the three and nine months ended March 31, 2010, respectively and 2,216,700 and 2,093,746 for the three and nine months ended March 31, 2009, respectively.

Reclassifications

Certain prior period amounts have been reclassified to conform to current period classifications.

NOTE 2: RECENT ACCOUNTING PRONOUNCEMENTS

In January 2010, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update 2010-06, “Fair Value Measures and Disclosures,” (“ASU 2010-06”). ASU 2010-06 amends the Codification to require new disclosures as follows: (1) Transfers in and out of Levels 1 and 2. (2) Activity in Level 3 fair value measurements. ASU 2010-06 further provides amendments to the Codification that clarify existing disclosures as follows: (1) Level of disaggregation. (2) Disclosures about inputs and valuation techniques. We adopted ASU 2010-06 and it did not have a material effect on our current financial statements.

In January 2010, the FASB issued Accounting Standards Update 2010-09, “Subsequent Events (Topic 855),” (“ASU 2010-09”). As a result of ASU 2010-09, SEC registrants will no longer disclose the date through which management evaluated subsequent events in the financial statements, either in originally issued financial statements or reissued financial statements. The guidance in ASU 2010-09 is effective immediately. We adopted ASU 2010-09 and it did not have a material effect on our current financial statements.

NOTE 3: SEGMENT INFORMATION

We report results for two segments, specialty fibers and nonwoven materials. The specialty fibers segment consists of our chemical cellulose, customized fibers and fluff pulp product lines which are cellulosic fibers based on both wood and cotton. The nonwovens materials segment consists of our airlaid plants and our converting plant. Management makes financial decisions and allocates resources based on the sales and operating income of each segment. We allocate selling, research, and administrative expenses to each segment and management uses the resulting operating income to measure the performance of the segments. The financial information attributed to these segments is included in the following tables:

Three Months Ended March 31		Specialty Fibers		Nonwoven Materials		Corporate			Total
Net sales	2010	$	137,049	$	59,922	$	(6,257	)	$	190,714
	2009		123,853		57,210		(9,428	)		171,635
Operating income (loss)	2010		20,345		3,347		(2	)		23,690
	2009		10,861		2,912		(969	)		12,804
Depreciation and amortization of	2010		7,393		3,653		926			11,972
intangibles	2009		7,793		3,577		919			12,289
Capital expenditures	2010		10,335		663		99			11,097
	2009		7,789		866		339			8,994

Nine Months Ended March 31		Specialty Fibers		Nonwoven Materials		Corporate			Total
Net sales	2010	$	388,793	$	182,891	$	(20,388	)	$	551,296
	2009		426,571		179,913		(28,891	)		577,593
Operating income (loss)	2010		45,943		13,051		68,378			127,372
	2009		42,271		7,948		(141,369	)		(91,150	)
Depreciation and amortization of	2010		21,844		11,128		2,776			35,748
intangibles	2009		24,201		11,119		2,678			37,998
Capital expenditures	2010		26,565		2,526		678			29,769
	2009		29,741		3,202		1,062			34,005

Management evaluates operating performance of the specialty fibers and nonwoven materials segments excluding amortization of intangibles, the impact of goodwill impairment loss, alternative fuel mixture credits, charges related to restructuring, unallocated at-risk compensation and unallocated stock-based compensation for executive officers and certain other employees. Therefore, the corporate column includes operating elements such as segment eliminations, amortization of intangibles, goodwill impairment loss, alternative fuel mixture credits, charges related to restructuring, unallocated at-risk compensation and unallocated stock-based compensation for executive officers and certain other employees. Corporate net sales represent the elimination of intersegment sales included in the specialty fibers reporting segment. We account for intersegment sales as if the sales were to third parties.

NOTE 4: RESTRUCTURING COSTS

During 2010, we entered into a restructuring program to sharpen our focus on key priorities which included restructuring our Ultra Fiber sales force, aligning capacity utilization with current market conditions at our Memphis Plant, and reducing selling, research and administrative expenses. The total cost of this program is estimated to be $3,337 and will be completed during the fourth quarter of 2010. The remaining accrual of $1,743 will be paid over the next nine months. As a result of this restructuring, 31 positions will be eliminated and 8 employees were transferred from selling, research and administrative positions to management positions at our Florida facility.

Restructuring expenses are included in “Restructuring costs” in our condensed consolidated statements of operations. The charges below reflect severance and employee benefits accrued over the retention period, relocation expenses and other miscellaneous expenses. Accrual balances are included in “Accrued expenses” in the balance sheet. The following table summarizes the expenses and accrual balances by reporting segment for the three months ended March 31, 2010.

	Period Ended March 31, 2010
2010 Restructuring Program	Accrual Balance as of December 31, 2009		Additional Charges		Payments			Accrual Balance as of March 31, 2010		Program Charges to Date		Total Estimated Charges
Severance and employee benefits
Specialty fibers	$	134	$	182	$	(214	)	$	102	$	997	$	997
Corporate		-		1,364		(103	)		1,261		1,364		1,433
Other miscellaneous expenses
Specialty fibers		-		848		(468	)		380		848		907
Total 2010 Program	$	134	$	2,394	$	(785	)	$	1,743	$	3,209	$	3,337

NOTE 5: ALTERNATIVE FUEL MIXTURE CREDITS

The U.S. Internal Revenue Code of 1986, as amended (“the Code”) permitted a refundable excise tax credit under certain circumstances for the production and use of alternative fuels and alternative fuel mixtures in lieu of fossil-based fuels. The credit was equal to $.50 per gallon of alternative fuel contained in the mixture. We qualified for the alternative fuel mixture credit because we produce liquid fuels derived from biomass, byproducts of our wood pulping process, and utilize those fuels to power our Foley Plant in Perry, Florida.

On March 19, 2009 the U.S. Internal Revenue Service (“IRS”) accepted our application to be registered as an alternative fuel mixer. We began producing and consuming alternative fuel mixtures on February 12, 2009. We recorded $4,762 and $77,677 in alternative fuel mixture credits, which was net of expenses, in our consolidated statements of operations for the three and nine months ended March 31, 2010, respectively. During the three months ended March 31, 2010, a clarification of the rules by the IRS, allowed us to reverse reserves related to the inorganic content of the fuel mixture. During the nine months ended March 31, 2010 we received $2,868 in cash related to these credits and $5,581 related to prior period credits. Of the $75,224 in income tax credits accumulated in 2010, approximately $20,000 will be realized in the current fiscal year as an offset to taxes due on income earned in the U.S., eliminating the need for quarterly estimated federal tax payments this fiscal year. The remainder will be realized when we apply for our tax refund in the latter half of calendar year 2010. We have treated the credits received in cash as taxable income and the income tax credits as non-taxable income. The alternative fuel mixture credits are subject to audit by the IRS. The credit expired on December 31, 2009.

NOTE 6: MITIGATION BANK

In February 2002, we were issued a mitigation bank/environmental resource permit by the State of Florida to restore approximately 6,748 acres of property to wetlands. As the three phases of the project are completed under this permit, credits are released that can be sold under the mitigation bank and an obligation is created to maintain the property as wetlands in perpetuity.

In 2005, we began construction on the first phase of the mitigation bank. Since that time, we have completed two of the 3 phases covered under the permit. Phase III will not commence before 2013. During 2006 through 2009, we sold approximately 17 credits for $417. As of March 31, 2010 we have recorded a long-term asset of $565 for mitigation bank credits and a long-term perpetual maintenance liability of $157. The asset includes all costs associated with the construction required to return the property to wetlands, hydrologic monitoring, vegetation monitoring and the present value of the perpetual maintenance. During the three and nine months ended March 31, 2010, we recorded $633 and $724, respectively, which was net of expenses, in mitigation bank sales which are shown as other operating income on our consolidated statements of operations.

NOTE 7: INVENTORIES

Inventories are valued at the lower of cost or market. The costs of manufactured cotton-based specialty fibers and costs for nonwoven raw materials are generally determined on the first-in, first-out basis. Other manufactured products and raw materials are generally valued on an average cost basis. Manufactured inventory costs include material, labor and manufacturing overhead. Slash pine timber, cotton fibers and chemicals are the principal raw materials used in the manufacture of our specialty fiber products. Fluff pulp is the principal raw material used in our nonwoven materials products. We take physical counts of inventories at least annually, and we review periodically the provision for potential losses from obsolete, excess or slow-moving inventories.

The components of inventory consist of the following:

	March 31 2010		June 30 2009

Raw materials	$	19,563	$	20,004
Finished goods		38,444		42,599
Storeroom and other supplies		25,140		25,034
	$	83,147	$	87,637

NOTE 8: GOODWILL

In accordance with GAAP, we perform a goodwill impairment analysis on an annual basis and, if certain events or circumstances indicate that an impairment loss may have been incurred, on an interim basis. Goodwill is recognized for the excess of the purchase price over the fair value of tangible and identifiable intangible net assets of businesses acquired. Goodwill of businesses acquired is specifically identified to the reporting units to which the businesses belong. Goodwill is reviewed annually for impairment in the fourth fiscal quarter. We estimate fair value based on a combination of the income approach and the market approach. The income approach requires management to estimate future net cash flows, the timing of these cash flows and an appropriate discount rate (or weighted average cost of capital) representing the time value of money and the inherent risk and uncertainty of future cash flows. The discount rate is based on independently calculated beta risks for a composite group of companies, our target capital mix and an estimated market risk premium. The assumptions used in estimating future cash flows are consistent with the reporting unit’s internal planning. The market approach estimates the fair value of our reporting units on comparable market prices. Goodwill is measured at the reporting unit level by comparing the reporting unit’s carrying amount, including goodwill, to the fair market value of the reporting unit. The analysis of potential impairment of goodwill requires a two-step process. The first step is the estimation of fair value. If step one indicates that impairment potentially exists, the second step is performed to measure the amount of impairment, if any. Goodwill impairment exists when the implied fair value of goodwill is less than its carrying value.

During our quarter ended December 31, 2008, based on the economic environment at that time and the steep decline in the price of our stock, which created a significant gap between the book and market value of our equity, we concluded that there were sufficient indicators to require us to perform an interim goodwill impairment test as of December 31, 2008. As a result, during the three months ended December 31, 2008, we recorded an impairment charge of $138,008 which represented our best estimate of the resulting goodwill impairment. We engaged an independent valuation firm to assist with this impairment testing by expressing opinions as of December 31, 2008 of the fair values of the business enterprises of our four reporting units. The results of step one indicated goodwill was impaired at three of our reporting units as the estimated fair value was less than the carrying value of the reporting units. As such, step two of the goodwill impairment test was performed to determine the actual amount of goodwill impairment. In this step, we were required to allocate the fair value of the reporting unit, as determined in step one, to all of the reporting unit’s assets and liabilities in a hypothetical purchase price allocation as if these reporting units had been acquired on the date of the test. Upon completion of this step, our original estimate did not change and therefore no change was required to the $138,008 non-cash goodwill impairment charge estimated and recorded in the second quarter of 2009. We reviewed our long-lived tangible and intangible assets within the impaired reporting units and determined that the forecasted undiscounted cash flows related to these assets or asset groups were in excess of their carrying values, and therefore these assets were not impaired. There were no changes in the carrying amount of goodwill for the nine months ended March 31, 2010.

NOTE 9: DEBT

The components of long-term debt consist of the following:

	March 31 2010		June 30 2009

Senior Notes due 2013	$	165,000	$	200,000
Senior Subordinated Notes due 2010		-		110,444
Credit facility		108,476		17,021
	$	273,476	$	327,465

Senior Notes

Our 8.5% senior notes due October 1, 2013 (the “2013 Notes”) are unsecured obligations and are senior to any of our subordinated debt. The 2013 Notes are guaranteed by our direct and indirect domestic subsidiaries that are also guarantors on our credit facility. The 2013 Notes became redeemable at our option, in whole or part, at any time on or after October 1, 2008, at redemption prices varying from 104.25% to 100% of principal amount on or after October 1, 2011 (102.833% at March 31, 2010), together with accrued and unpaid interest to the date of redemption.

On June 30, 2009 we amended the 2013 Notes to permit the redemption, repurchase or retirement of subordinated indebtedness, including our 8% senior subordinated notes due 2010 (the “2010 Notes” and, with the 2013 Notes, the “Notes”), up to sixteen months prior to maturity, which represented an increase of four months compared to the prior terms of the indentures pursuant to which the Notes were issued. We paid a consent fee of $650 in the aggregate to all consenting holders. We recorded this consent fee as a deferred financing cost and will amortize it over the remaining term of the 2013 Notes using the effective interest rate method.

On January 4, 2010, we redeemed $35,000 of the 2013 Notes using a combination of $19,000 cash on hand and $16,000 in borrowings on our revolving credit facility. During the three months ended March 31, 2010, we recorded a $1,537 loss related to the extinguishment of this debt which included the redemption price premium of $992 and the write-off of the related deferred financing costs of $545.

On April 19, 2010, we redeemed $25,000 of the 2013 Notes using borrowings on our revolving credit facility. See Note 17.

Senior Subordinated Notes

On July 31, 2009 we redeemed the remaining $110,000 then outstanding of 2010 Notes using borrowings on our revolving credit facility. During the nine months ended March 31, 2010 we recorded a $165 gain related to the early extinguishment of this debt, which was the net of the write-off of the related deferred financing costs and the remaining unamortized interest rate swap early termination fee.

Revolving Credit Facility

Our $200,000 senior secured revolving credit facility (the “Credit Facility”) currently has a maturity date of July 25, 2012. The interest rate applicable to borrowings under the Credit Facility is the agent’s prime rate plus 0.25% to 1.00% or a LIBOR-based rate ranging from LIBOR plus 1.25% to LIBOR plus 2.00%. The Credit Facility is secured by substantially all of our assets located in the United States.

The Credit Facility contains covenants customary for financing of this type. The financial covenants include: maximum total leverage ratio of consolidated total debt to consolidated earnings before interest, taxes, depreciation and amortization (“EBITDA”), and minimum ratio of consolidated EBITDA to consolidated interest expense. At March 31, 2010, we were in compliance with the financial covenants under the Credit Facility.

At March 31, 2010, we had $26,935 of cash and cash equivalents and we had $86,606 borrowing capacity under the Credit Facility. The Credit Facility allows for a sublimit on letters of credit of $50,000. As of March 31, 2010, $45,082 of the sublimit was unused. The commitment fee on the unused portion of the revolving credit facility ranges from 0.25% to 0.40% per annum based on a grid related to our leverage ratio.

NOTE 10: FAIR VALUE MEASUREMENTS

For certain of our financial instruments, including cash and cash equivalents, accounts receivable, and accounts payable, the carrying amounts approximate fair value due to their short maturities. The fair value of our long-term public debt is based on an average of the bid and offer prices. The carrying value and fair value of long-term debt at March 31, 2010, were $273,476 and $277,395, respectively, and at June 30, 2009 were $327,465 and $311,362, respectively. The fair value of the Credit Facility approximates its carrying value due to its variable interest rate.

For the financial instruments disclosed below, fair value is determined at each balance sheet date using an income approach, which consists of a discounted cash flow model that takes into account the present value of future cash flows under the terms of the contracts using current market information as of the reporting date, such as prevailing interest rates and foreign currency spot and forward rates. The following table provides a summary of the inputs used to develop these estimates under the fair value hierarchy:

	Fair Value Measurements at March 31, 2010
	Total		Quoted prices in active markets for identical assets (Level 1)		Significant other observable inputs (Level 2)		Significant unobservable inputs (Level 3)
Assets:
Natural gas hedge	$	12	$	-	$	12	$	-
Total assets	$	12	$	-	$	12	$	-

Liabilities:
Natural gas hedge	$	80	$	-	$	80	$	-
Total liabilities	$	80	$	-	$	80	$	-

NOTE 11: FINANCIAL DERIVATIVE INSTRUMENTS

As part of our risk management program, we use a variety of financial instruments such as foreign currency forwards and options, interest rate swaps, and natural gas contracts as cash flow hedges to mitigate risk. We do not hold or issue derivative financial instruments for trading purposes.

Foreign Currency Hedging

We periodically use hedging to address the risk associated with non-functional currency (primarily Brazilian real and European euro) financial statement exposures. Fluctuations in exchange rates can change our foreign currency equivalent revenue and hence our foreign currency earnings. When conditions warrant, our foreign subsidiaries hedge a portion of forecasted U.S. dollar denominated sales/receivables utilizing foreign exchange forward and option contracts. These contracts are designated as cash flow hedges and accounting for these hedge instruments requires that they be recorded on the balance sheet as either an asset or a liability measured at fair value as of the reporting date. The effective portion of the hedge gain or loss is reported as a component of accumulated other comprehensive income (loss) and subsequently reclassified into gain (loss) on exchange rates when the hedged exposure affects earnings. Any ineffective portions of related gains or losses are recorded in the statements of operations immediately. In the event the underlying forecasted transaction does not occur, or it becomes probable that it will not occur, we will reclassify the gain or loss on the related cash flow hedge from accumulated other comprehensive income (loss) to gain (loss) on exchange rates on our consolidated statement of operations. As of June 30, 2009 we had a foreign currency contract that did not qualify for hedge accounting treatment with a value of $320 recorded in prepaid expenses and other on the balance sheet.

Interest Rate Swaps

In May 2001, we entered into an interest rate swap relative to $100,000 of our 2010 notes. The swap converted interest payments from a fixed rate to a floating rate of LIBOR plus 1.97%. This arrangement qualified as a fair value hedge. As such, the net effect from the interest rate swap was recorded as part of interest expense. On October 15, 2003, the swap counter party exercised its right to terminate the swap and paid us $4,000 as an early termination fee, which was being amortized as a reduction to interest expense through October 15, 2010. At June 30, 2009, the unamortized portion of the termination fee was recorded as an increase in debt of $541. On July 31, 2009, the remaining $506 was recorded as a gain on early extinguishment of debt when we redeemed the remaining 2010 Notes. During the three and nine months ended March 31, 2009, the swap reduced our interest expense by $105 and $358, respectively.

On September 17, 2007 we entered into an interest rate swap agreement that matured on September 19, 2009 relative to $30,000 of debt under our Credit Facility. The swap involved the exchange of interest payments from a floating-rate three month LIBOR plus the applicable margin on the revolving credit facility to a fixed rate of 4.79% plus the same applicable margin. This arrangement qualified as a cash flow hedge; therefore, the net effect from the interest rate swap was recorded as interest expense. On June 17, 2009 we retired the $30,000 of variable rate debt that had been hedged. As a result of the extinguishment of the underlying debt, hedge accounting on the interest rate swap was no longer appropriate. During the three and nine months ended March 31, 2009, the swap increased our interest expense by $226 and $544, respectively.

Commodity Hedging

We have entered into contracts for the purchase of natural gas at a fixed rate to manage the price risk associated with a portion of our forecasted purchases. The objective of these hedges is to provide supply assurance for contracted volumes at a pre-determined price; provide a systemic method of purchasing commodities which enables us the opportunity to take advantage of forward price trends based on historical data; provide a methodology to bring price stability that will contribute to improved price forecasting and budgeting assumptions; and reduce the variability of cash flows associated with the purchase of natural gas at certain plants. These contracts are designated as cash flow hedges. As of March 31, 2010 and June 30, 2009 we had contracts in place to purchase186,532 MMBTUs and 359,220 MMBTUs of natural gas at various fixed prices through December 2010, respectively. Additionally, as of March 31, 2010 we had options in place to purchase 132,000 MMBTUs of natural gas at prices ranging from $6 to $7 per MMBTU through November 2010.

Fair Value of Derivative Instruments

In the next twelve months, we intend to reclassify into earnings $68 in net losses in respect of cash flow hedges.

All cash flows associated with purchasing and selling derivatives are classified as operating cash flows in the unaudited condensed consolidated statements of cash flows. The following table presents the location of all assets and liabilities associated with our hedging instruments within the unaudited condensed consolidated balance sheets:

		Asset Derivatives				Liability Derivatives
Derivatives designated as hedging instruments	Balance Sheet Location	Fair Value at 3/31/10		Fair Value at 6/30/09		Fair Value at 3/31/10		Fair Value at 6/30/09
Natural gas hedges	Accrued expenses	$	12	$	-	$	80	$	234
Interest rate swap	Accrued expenses		-		-		-		320
Total derivatives designated as hedging instruments		$	12	$	-	$	80	$	554

The following tables present the impact of derivative instruments, net of tax, and their location within the unaudited condensed consolidated statements of operations:

Derivatives in Cash Flow Hedging Relationships:
	Amount of (Gain) Loss Recognized in AOCI on Derivative (Effective Portion)					Amount of (Gain) Loss Reclassified from AOCI into Income (Effective Portion)(a)						Amount of (Gain) Loss Recognized in Income on Derivatives (Ineffective Portion)
	Nine months ended March 31,					Nine months ended March 31,						Nine months ended March 31,
	2010		2009			2010			2009			2010		2009
Natural gas hedges	$	263	$	1,032		$	(351	)	$	(735	)	$	-	$	-
Interest rate swap		-		(482	)		-			441			-		-
Total	$	263	$	550		$	(351	)	$	(294	)	$	-	$	-
(a) Amounts related to natural gas contracts are included in cost of goods sold and amounts related to interest rate swaps are included in net interest expense and amortization of debt costs.

Derivatives not Designated as Cash Flow Hedges:
		Nine months ended March 31,
	Classification of (gains) or losses	2010			2009
Foreign currency swap	Foreign exchange and other	$	(287	)	$	-

NOTE 12: COMPREHENSIVE INCOME

The components of comprehensive income consist of the following:

	Three Months Ended March 31						Nine Months Ended March 31
	2010			2009			2010		2009

Net income	$	19,343		$	4,286		$	104,858	$	(111,848	)
Foreign currency translation adjustments – net		(4,624	)		(3,764	)		8,359		(65,304	)
Unrealized gains (losses) on hedging activities - net		(60	)		(2	)		88		(256	)
Comprehensive income (loss), net of tax	$	14,659		$	520		$	113,305	$	(177,408	)

For the three and nine months ended March 31, 2010, the change in the foreign currency translation adjustment was due to fluctuations in the exchange rate of the U.S. dollar against the euro of $(6,178) and $(4,444), the Brazilian real of $(221) and $6,324 and the Canadian dollar of $1,775 and $6,479, respectively.

For the three and nine months ended March 31, 2009, the change in the foreign currency translation adjustment was due to fluctuations in the exchange rate of the U.S. dollar against the euro of $(3,793) and $(15,261), the Brazilian real of $1,235 and $(22,879) and the Canadian dollar of $(1,206) and $(27,164), respectively.

A rollforward of the amounts included in Accumulated Other Comprehensive Income, net of taxes is shown below:

		Hedging Activities		Foreign Currency Translation		Post-Employment Healthcare			Accumulated Other Comprehensive Income
Balance at June 30, 2009	$	(147	)	$	35,637	$	(1,789	)	$	33,701
Changes in value		(263	)		8,359		-			8,096
Reclassification into earnings		351			-		-			351
Balance at March 31, 2010	$	(59	)	$	43,996	$	(1,789	)	$	42,148

NOTE 13: INCOME TAXES

We file income tax returns with federal, state, local and foreign jurisdictions. As of March 31, 2010, we remain subject to examinations of our U.S. federal and state income tax returns for 2002 through 2009, Canadian income tax returns for 2002 through 2009 and German tax filings for 2004 through 2009.

During the nine months ended March 31, 2010, we claimed the alternative fuel mixture credits for the period July 1, 2009 to the credit expiration date of December 31, 2009 as cash refunds through the filing of periodic excise tax refund claims and as income tax credits on the federal income tax return to be filed for 2010. For purposes of calculating federal and state income taxes, we treat the credits claimed as cash refunds of excise tax as taxable income and the credits claimed on the federal income tax return as non-taxable income. During the three and nine months ended March 31, 2010, we recorded a tax benefit of $1,093 and $26,300, respectively, due to the non-taxable nature of the alternative fuel mixture credits claimed on the federal income tax return.

The American Recovery and Reinvestment Act of 2009 expanded the IRC Section 48 energy investment tax credit to include qualified property for facilities producing electricity using open-loop biomass. During the three months ended March 31, 2010, new information and better insight obtained from an energy tax specialist and an engineering firm enabled management to evaluate the qualification for the tax credit and to make a decision to elect Section 48 energy investment credit for qualified expenditures. The company calculated the energy investment tax credit on qualified capital expenditures as follows:

Expenditures prior to June 30, 2009	$	5,415
Expenditures subsequent to June 30, 2009		2,025
Total energy investment tax credit	$	7,440

The company is accounting for the investment tax credit as a reduction of federal income taxes in the year in which the credit arises by utilizing the flow-through method of accounting.

Our effective tax rates for the three and nine month periods ended March 31, 2010 were (8.6)% and 5.9%, respectively. Our effective tax rates for the same periods in 2009 were 24.8% and 1.4%, respectively. We recorded a $138,008 goodwill impairment charge in the nine months ended March 31, 2009. Accordingly, we recognized a tax benefit of $10,410 in connection with the goodwill impairment charge. Our income tax expense differs from the amount computed by applying the statutory federal income tax rate of 35% to income before income taxes due to the following:

	Three Months Ended March 31						Nine Months Ended March 31
	2010			2009			2010			2009
Expected tax expense (benefit) at 35%	$	6,234		$	1,995		$	39,008		$	(39,682	)
Nondeductible goodwill impairment charge		-			-			-			37,892
Alternative fuel mixture credits		(1,093	)		-			(26,300	)		-
Energy investment tax credits		(7,440	)		-			(7,440	)		-
Effect of foreign operations		775			42			1,534			1,209
Other		(7	)		(625	)		(210	)		(951	)
Income tax expense (benefit)	$	(1,531	)	$	1,412		$	6,592		$	(1,532	)

NOTE 14: EMPLOYEE BENEFIT PLANS

We provide medical, dental and life insurance postretirement plans covering certain U.S. employees who meet specified age and service requirements. Effective January 1, 2006, Medicare eligible retirees age 65 or older are no longer covered under the self-funded plan. Instead, they are provided a subsidy towards the purchase of supplemental insurance. The components of net periodic benefit costs are as follows:

	Three Months Ended March 31						Nine Months Ended March 31
	2010			2009			2010			2009
Service cost for benefits earned	$	101		$	121		$	303		$	362
Interest cost on benefit obligation		350			374			1,050			1,121
Amortization of unrecognized prior service cost		(247	)		(251	)		(741	)		(753	)
Actuarial loss		31			69			93			208
Total cost	$	235		$	313		$	705		$	938

On July 1, 2008, we changed our measurement date of the plan’s funded status to be the same as our fiscal year end. The change in the measurement date resulted in a decrease in accrued postretirement benefits of $1,175, an increase in deferred tax liabilities of $433, an increase in accumulated other comprehensive income of $882 and a decrease in the opening balance of retained earnings of $140.

NOTE 15: STATE OF FLORIDA GRANT

On August 11, 2009 we announced that we had qualified to receive up to $7,381 from the State of Florida Quick Action Closing Fund. This performance-based incentive provides up-front cash for approved economic development projects. On September 30, 2009, we received the $7,381 as an incentive to complete our $45,000 Foley Energy Project which had been suspended in March 2009. We have committed to invest $32,300 on this and other related energy projects after the date of the grant, and to maintain at least 555 jobs, at a specified average wage, at our Florida facility. We are required to make the investment by December 31, 2012 and to maintain the jobs and specified wage level through December 31, 2015. If we fail to make at least 80% of the investment or if we fall below the 555 jobs or specified wage level in any of the next six years, we would be required to repay a prorated portion of the award. We have recorded this cash incentive in the long-term liability section of our condensed consolidated balance sheets. As we invest in the Foley Energy Project, we are reclassifying this liability as a reduction in the cost of equipment. For the three and nine months ended March 31, 2010 we have reclassified $745 and $2,274, respectively. When the project is complete, we will amortize the $7,381 over the life of the equipment.

NOTE 16: CONTINGENCIES

Our operations are subject to extensive general and industry-specific federal, state, local and foreign environmental laws and regulations, particularly those relating to air and water quality, waste disposal and the cleanup of contaminated soil and groundwater. We devote significant resources to maintaining compliance with these laws and regulations. Such environmental laws and regulations at the federal level include the Comprehensive Environmental Response, Compensation and Liability Act of 1980, as amended, the Clean Air Act of 1990, as amended, the Clean Water Act of 1972, as amended, the Resource Conservation and Recovery Act of 1976, as amended, the Toxic Substances Control Act of 1976, as amended, and the Safe Drinking Water Act of 1974, as amended. These environmental regulatory programs are primarily administered by the U.S. Environmental Protection Agency (“EPA”). In addition, the individual states and foreign countries in which we operate have adopted and may adopt in the future equivalent or more stringent environmental laws and regulations or have enacted their own parallel environmental programs. We closely monitor our compliance with current environmental requirements and believe that we are in substantial compliance.

We expect that, due to the nature of our operations, we will be subject to increasingly stringent environmental requirements, including standards applicable to wastewater discharges and air emissions, such as emissions of greenhouse gases, and general permitting requirements for our manufacturing facilities. We also expect that we will continue to incur substantial costs to comply with such requirements. Any failure on our part to comply with environmental laws or regulations could subject us to penalties or other sanctions that could materially affect our business, results of operations or financial condition. We cannot currently assess, however, the impact that more stringent environmental requirements may have on our operations or capital expenditure requirements.

The Foley Plant, located in Perry, Florida, discharges treated wastewater into the Fenholloway River. Under the terms of an agreement with the Florida Department of Environmental Protection (“FDEP”), approved by the EPA in 1995, we agreed to a comprehensive plan to attain Class III (“fishable/swimmable”) status for the Fenholloway River under applicable Florida law (the “Fenholloway Agreement”). The Fenholloway Agreement established a schedule for the filing of necessary permit applications and approvals to implement the following activities, among others: (i) make process changes within the Foley Plant to reduce the coloration of its wastewater discharge, (ii) restore certain wetlands areas, (iii) install a pipeline to relocate the wastewater discharge point into the Fenholloway River to a point closer to the mouth of the river, and (iv) provide oxygen enrichment to the treated wastewater prior to discharge at the new location. We have completed the process changes within the Foley Plant as required by the Fenholloway Agreement. In making these in-plant process changes, we incurred significant capital expenditures. Based on the anticipated permit conditions, we expect to incur significant additional capital expenditures once final permits are issued.

In August 2005, FDEP drafted a proposed renewal of the Buckeye National Pollutant Discharge Elimination System (“NPDES”) permit. The FDEP completed the required public notice, review and comment process and issued the formal Notice of Intent to Issue Permit in November 2005. The proposed permit was challenged by some members of the public. In January 2008, the pending administrative hearing was dismissed due to anticipated revisions to the permit based on additional studies and development of a total maximum daily load (“TMDL”) for the Fenholloway River. The development of the TMDL is necessary because the EPA and FDEP have listed the Fenholloway River as an impaired water (not meeting all water quality standards) under the Clean Water Act for certain pollutants. In addition, we also have filed petitions with the FDEP for the establishment of Site-Specific Alternative Water Quality Criteria (“SSAC”), which petitions must be approved by the EPA. The additional studies necessary to support revisions to the permit have been completed. The revised draft NPDES permit to be issued by FDEP will be based upon modeling performed in conjunction with the EPA and the FDEP, will address the TMDL established for the Fenholloway River by the EPA and will also contain Water Quality Based Effluent Limits. When the FDEP issues the revised draft permit it will be subject to public comment and opportunity for requesting a hearing.

We expect to incur additional capital expenditures related to our wastewater treatment and discharge of between $40 million and $60 million over at least five years, possibly beginning as early as 2012. The amount and timing of these capital expenditures may vary depending on a number of factors including when the final NPDES permit is issued and its final terms and conditions.

On November 4, 2009, our Americana, Brazil facility received an Infraction Document from the São Paulo State Tax Authority related to Brazilian state value-added taxes (“ICMS Taxes”) for the period of January 1, 2005 through December 31, 2008. On December 4, 2009, we filed our objection to 2,624 real ($1,473 at March 31, 2010 exchange rates) of the taxes and penalties that were assessed. The process for defending our objection will involve a lengthy appeals process and it could be several years before we reach resolution. We believe we have meritorious defenses to this assessment and intend to defend our position vigorously.

We are involved in certain legal actions and claims arising in the ordinary course of business. In the opinion of management, however, based upon information currently available, the ultimate liability with respect to these actions will not materially affect our consolidated results of operations or financial position. We review outstanding claims and proceedings internally and with external counsel as necessary to assess probability of loss and for the ability to estimate loss. These assessments are re-evaluated each quarter or as new information becomes available to determine whether a reserve should be established or if any existing reserve should be adjusted. The actual cost of resolving a claim or proceeding ultimately may be substantially different than the amount of the recorded reserve. In addition, because it is not permissible under GAAP to establish a litigation reserve until the loss is both probable and estimable, in some cases there may be insufficient time to establish a reserve prior to the actual incurrence of the loss (upon verdict and judgment at trial, for example, or in the case of a quickly negotiated settlement).

NOTE 17: SUBSEQUENT EVENT

On April 19, 2010, we redeemed $25,000 of the 2013 Notes using borrowings on our revolving credit facility. We recorded a $1,233 loss related to the extinguishment of this debt which included the redemption price premium of $708 and the write-off of the related deferred financing costs of $525.

NOTE 18: CONDENSED CONSOLIDATING FINANCIAL STATEMENTS

The guarantor subsidiaries presented below represent our subsidiaries that are subject to the terms and conditions outlined in the indenture governing the 2013 Notes and that guarantee the 2013 Notes, jointly and severally, on a senior unsecured basis. The non-guarantor subsidiaries presented below represent the foreign subsidiaries that do not guarantee the 2013 Notes. Each subsidiary guarantor is 100% owned directly or indirectly by us and all guarantees are full and unconditional.

The supplemental financial information for our guarantor subsidiaries and non-guarantor subsidiaries for the 2013 Notes is presented in the following tables.

CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS

Three Months Ended March 31, 2010

	Buckeye Technologies Inc.			Guarantors US Subsidiaries			Non- Guarantor Subsidiaries				Consolidating Adjustments			Consolidated
Net sales	$	24,233		$	135,302			$	38,250		$	(7,071	)	$	190,714
Cost of goods sold		19,689			108,681				36,104			(6,907	)		157,567
Gross margin		4,544			26,621				2,146			(164	)		33,147

Selling, research and administrative expenses, and other		(2,692	)		12,092				2,424			-			11,824
Alternative fuel mixture credits		-			(4,762	)			-			-			(4,762	)
Restructuring costs		2,395			-				-			-			2,395

Operating income (loss)		4,841			19,291				(278	)		(164	)		23,690

Other income (expense):
Net interest income (expense) and amortization of debt costs		(4,295	)		359				16			-			(3,920	)
Other income (expense), including equity in income (loss) in affiliates		100,355			6				(492	)		(101,827	)		(1,958	)
Intercompany interest income (expense)		6,838			(6,860	)			22			-			-

Income (loss) before income taxes		107,739			12,796				(732	)		(101,991	)		17,812

Income tax expense (benefit)		88,396			(48,117	)			414			(42,224	)		(1,531	)

Net income (loss)	$	19,343		$	60,913			$	(1,146	)	$	(59,767	)	$	19,343

CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS

Nine Months Ended March 31, 2010

	Buckeye Technologies Inc.			Guarantors US Subsidiaries			Non- Guarantor Subsidiaries				Consolidating Adjustments			Consolidated
Net sales	$	64,906		$	386,142			$	123,438		$	(23,190	)	$	551,296
Cost of goods sold		56,615			315,694				113,153			(22,434	)		463,028
Gross margin		8,291			70,448				10,285			(756	)		88,268

Selling, research and administrative expenses, and other		(10,190	)		37,849				7,705			-			35,364
Alternative fuel mixture credits		-			(77,677	)			-			-			(77,677	)
Restructuring costs		3,209			-				-			-			3,209

Operating income (loss)		15,272			110,276				2,580			(756	)		127,372

Other income (expense):
Net interest income (expense) and amortization of debt costs		(14,932	)		1,100				2			-			(13,830	)
Other income (expense), including equity in income (loss) in affiliates		181,698			37				(931	)		(182,896	)		(2,092	)
Intercompany interest income (expense)		20,538			(19,096	)			(1,442	)		-			-

Income (loss) before income taxes		202,576			92,317				209			(183,652	)		111,450

Income tax expense (benefit)		97,718			(20,817	)			1,316			(71,625	)		6,592

Net income (loss)	$	104,858		$	113,134			$	(1,107	)	$	(112,027	)	$	104,858

CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS

Three Months Ended March 31, 2009

	Buckeye Technologies Inc.			Guarantors US Subsidiaries			Non- Guarantor Subsidiaries				Consolidating Adjustments			Consolidated
Net sales	$	15,698		$	129,079			$	36,779		$	(9,921	)	$	171,635
Cost of goods sold		17,896			106,784				32,976			(9,891	)		147,765
Gross margin		(2,198	)		22,295				3,803			(30	)		23,870

Selling, research and administrative expenses, and other		(4,224	)		13,044				2,246			-			11,066

Operating income (loss)		2,026			9,251				1,557			(30	)		12,804

Other income (expense):
Net interest income (expense) and amortization of debt costs		(7,525	)		290				29			-			(7,206	)
Other income (expense), including equity income (loss) in affiliates		54,194			(67	)			176			(54,203	)		100
Intercompany interest income (expense)		7,674			(6,733	)			(941	)		-			-

Income (loss) before income taxes		56,369			2,741				821			(54,233	)		5,698

Income tax expense (benefit)		52,083			1,212				168			(52,051	)		1,412

Net income (loss)	$	4,286		$	1,529			$	653		$	(2,182	)	$	4,286

CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS

Nine Months Ended March 31, 2009

	Buckeye Technologies Inc.			Guarantors US Subsidiaries			Non- Guarantor Subsidiaries			Consolidating Adjustments			Consolidated
Net sales	$	78,383		$	406,420		$	124,327		$	(31,537	)	$	577,593
Cost of goods sold		77,352			334,909			114,873			(31,881	)		495,253
Gross margin		1,031			71,511			9,454			344			82,340

Selling, research and administrative expenses, and other		(11,889	)		39,792			7,579			-			35,482
Goodwill impairment loss		20,230			24,922			92,856			-			138,008

Operating income (loss)		(7,310	)		6,797			(90,981	)		344			(91,150	)

Other income (expense):
Net interest income (expense) and amortization of debt costs		(23,171	)		929			129			-			(22,113	)
Other income (expense), including equity income (loss) in affiliates		(144,671	)		(340	)		(268	)		145,162			(117	)
Intercompany interest income (expense)		23,111			(19,977	)		(3,134	)		-			-

Income (loss) before income taxes		(152,041	)		(12,591	)		(94,254	)		145,506			(113,380	)

Income tax expense (benefit)		(40,193	)		4,646			(3,817	)		37,832			(1,532	)

Net income (loss)	$	(111,848	)	$	(17,237	)	$	(90,437	)	$	107,674		$	(111,848	)

CONDENSED CONSOLIDATING BALANCE SHEETS

As of March 31, 2010

	Buckeye Technologies Inc.			Guarantors US Subsidiaries		Non- Guarantor Subsidiaries		Consolidating Adjustments			Consolidated
Assets
Current assets
Cash and cash equivalents	$	296		$	3	$	26,636	$	-		$	26,935
Accounts receivable, net		44,247			48,855		33,879		-			126,981
Income tax and alternative fuel mixture credits receivable		-			73,809		-		-			73,809
Inventories, net		10,143			53,900		19,594		(490	)		83,147
Other current assets		(224	)		4,571		1,819		-			6,166
Intercompany accounts receivable		-			227,052		-		(227,052	)		-
Total current assets		54,462			408,190		81,928		(227,542	)		317,038

Property, plant and equipment, net		56,589			338,632		130,980		-			526,201
Goodwill and intangibles, net		13,555			2,425		-		-			15,980
Intercompany notes receivable		363,717			-		-		(363,717	)		-
Other assets, including investment in subsidiaries		398,795			301,766		92,599		(787,829	)		5,331
Total assets	$	887,118		$	1,051,013	$	305,507	$	(1,379,088	)	$	864,550

Liabilities and stockholders’ equity
Current liabilities
Trade accounts payable	$	4,054		$	21,559	$	7,201	$	-		$	32,814
Other current liabilities		(55,060	)		94,430		3,821		(1	)		43,190
Intercompany accounts payable		225,408			-		1,644		(227,052	)		-
Total current liabilities		174,402			115,989		12,666		(227,053	)		76,004

Long-term debt		273,476			-		-		-			273,476
Deferred income taxes		(3,679	)		44,654		7,145		-			48,120
Other long-term liabilities		8,962			22,248		1,783		-			32,993
Intercompany notes payable		-			259,069		104,648		(363,717	)		-
Stockholders’/invested equity		433,957			609,053		179,265		(788,318	)		433,957
Total liabilities and stockholders’ equity	$	887,118		$	1,051,013	$	305,507	$	(1,379,088	)	$	864,550

CONDENSED CONSOLIDATING BALANCE SHEETS

As of June 30, 2009


	Buckeye Technologies Inc.			Guarantors US Subsidiaries		Non- Guarantor Subsidiaries		Consolidating Adjustments			Consolidated
Assets
Current assets
Cash and cash equivalents	$	1,138	$		4	$	20,919	$	-		$	22,061
Accounts receivable, net		18,644			63,522		29,126		-			111,292
Income tax and alternative fuel mixture credits receivable		9,374			-		-		-			9,374
Inventories, net		17,325			53,722		16,931		(341	)		87,637
Other current assets		332			5,156		1,019		-			6,507
Intercompany accounts receivable		-			131,302		-		(131,302	)		-
Total current assets		46,813			253,706		67,995		(131,643	)		236,871

Property, plant and equipment, net		58,821			336,836		130,932		-			526,589
Goodwill and intangibles, net		14,845			2,425		-		-			17,270
Intercompany notes receivable		363,717			-		-		(363,717	)		-
Other assets, including investment in subsidiaries		328,471			267,118		103,781		(687,716	)		11,654