ADVANCE AUTO PARTS, INC.  AND SUBSIDIARIES NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS – (Continued) December 29, 2007, December 30, 2006 and December 31, 2005 (in thousands, except per share data) 11.
Stock Repurchase Program: During fiscal 2007, the Company's Board of Directors authorized a new stock repurchase program of up to $500,000 of the Company's common stock plus related expenses.
The new program cancelled and replaced the remaining portion of the previous $300,000 stock repurchase program.
The program allows the Company to repurchase its common stock on the open market or in privately negotiated transactions from time to time in accordance with the requirements of the Securities and Exchange Commission.
During fiscal 2007, the Company repurchased 8,341 shares of common stock at an aggregate cost of $285,869, or an average price of $34.27 per share, of which 1,330 shares of common stock were repurchased under the previous $300,000 stock repurchase program.
As of December 29, 2007, 77 shares have been repurchased at an aggregate cost of $2,959 and remained unsettled.
During fiscal 2007, the Company retired 6,329 shares previously repurchased under the stock repurchase programs.
At December 29, 2007, the Company had $260,567 remaining under the current stock repurchase program.
Subsequent to December 29, 2007, the Company repurchased 4,563 shares of common stock at an aggregate cost of $155,350, or an average price of $34.04 per share.
During fiscal 2006, the Company retired 5,117 shares of common stock which were previously repurchased under the Company’s prior stock repurchase program.
These shares were repurchased during fiscal 2006 and fiscal 2005 at an aggregate cost of $192,339, or an average price of $37.59 per share.12.
Income Taxes: As a result of the adoption of FIN 48 on December 31, 2006, the Company recorded an increase of $2,275 to the liability for unrecognized tax benefits and a corresponding decrease in its balance of retained earnings.
The following ta
## Table 0 ##
As of December 29, 2007 the entire amount of unrecognized tax benefits, if recognized, would reduce the Company’s annual effective tax rate.
With the adoption of FIN 48, the Company provides for interest and penalties as a part of income tax expense.
During fiscal 2007, the Company accrued potential penalties and interest of $709 and $1,827, respectively, related to these unrecognized tax benefits.
As of December 29, 2007, the Company has recorded a liability for potential penalties and interest of $1,843 and $4,421, respectively.
Prior to the adoption of FIN 48, the Company classified interest associated with tax contingencies in interest expense.
The Company has not provided for any penalties associated with tax contingencies unless considered probable of assessment.
The Company does not expect its unrecognized tax benefits to change significantly over the next 12 months.
During the next 12 months, it is possible the Company could conclude on $2,000 to $3,000 of the contingencies associated with unrecognized tax uncertainties due mainly to settlements and expiration of statute of limitations (including tax benefits, interest and penalties).
The majority of these resolutions would be achieved through the completion of current income tax examinations.
## Table 1 ##
The following table presents the changes in Level 3 recurring fair value measurements for the year ended Dec.  31:
## Table 2 ##
Losses on Level 3 commodity derivatives recognized in earnings for the year ended Dec.  31, 2009, include $8.2 million of net unrealized gains relating to commodity derivatives held at Dec.  31, 2009.
Gains on Level 3 commodity derivatives recognized in earnings for the year ended Dec.  31, 2008, include $3.7 million of net unrealized gains relating to commodity derivatives held at Dec.  31, 2008.
Realized and unrealized gains and losses on commodity trading activities are included in electric revenues.
Realized and unrealized gains and losses on non-trading derivative instruments are recorded in OCI or deferred as regulatory assets and liabilities.
The classification as a regulatory asset or liability is based on the commission approved regulatory recovery mechanisms.
Realized and unrealized gains and losses on nuclear decommissioning fund investments are deferred as a component of a nuclear decommissioning regulatory asset.16.
Rate Matters NSP-Minnesota Pending and Recently Concluded Regulatory Proceedings — MPUC Base Rate NSP-Minnesota Electric Rate Case — In November 2008, NSP-Minnesota filed a request with the MPUC to increase Minnesota electric rates by $156 million annually.
This request was later modified to $136 million.
In September 2009, the MPUC voted to approve a rate increase of approximately $91.4 million.
As part of its decision, the MPUC approved a 10-year life extension of the Prairie Island nuclear plant for purposes of determining depreciation and decommissioning expenses, effective Jan.  1, 2009.
This decision reduced NSP-Minnesota’s overall
PSCo and SPS have various pay-for-performance contracts with expiration dates through the year 2033.
In general, these contracts provide for capacity payments, subject to meeting certain contract obligations, and energy payments based on actual power taken under the contracts.
Certain contractual payment obligations are adjusted based on indices.
However, the effects of price adjustments are mitigated through cost-of-energy rate adjustment mechanisms.
At Dec.  31, 2009, the estimated future payments for capacity, accounted for as executory contracts, that the utility subsidiaries of Xcel Energy are obligated to purchase, subject to availability, are as follows:
## Table 3 ##
Variable Interest Entities — Xcel Energy has certain long-term purchased power agreements with independent power producing entities that contain tolling arrangements under which Xcel Energy procures the fuel required to produce the energy purchased.
Xcel Energy enters into these agreements to meet electric system capacity and energy needs.
Xcel Energy is not subject to risk of loss from the operations of these entities.
Xcel Energy has evaluated such entities for possible consolidation and has concluded that these entities are not required to be consolidated in Xcel Energy’s consolidated financial statements.
The significant qualitative factors considered evaluating purchase power agreements under ASC 810 Consolidation include length and terms of the contract and operational, fuel price and financing risk.
When necessary, a quantitative analysis demonstrated that Xcel Energy would absorb less than 50 percent of the expected gains or losses.
Significant assumptions used in the quantitative analysis by Xcel Energy, to determine the primary beneficiary, include an inflation rate equal to the Bureau of Labor Statistics 10 year average, estimated future fuel and electricity prices, future operating cash flows, an incremental borrowing rate, the expected life of the plant and a debt to equity financing ratio.
Leases — Xcel Energy and its subsidiaries lease a variety of equipment and facilities used in the normal course of business.
Three of these leases qualify as capital leases and are accounted for accordingly.
The assets and liabilities acquired under capital leases are recorded at the lower of fair market value or the present value of future lease payments and are amortized over their actual contract term in accordance with practices allowed by regulators.
In 1999, WYCO was formed as a joint venture with CIG to develop and lease natural gas pipeline, storage, and compression facilities.
Xcel Energy has a 50 percent ownership interest in WYCO.
In 2009, WYCO’s Totem gas storage facilities were placed in service.
WYCO leases the facilities to CIG, and CIG operates the facilities, providing natural gas storage services to PSCo under a service arrangement that commenced on July 1, 2009.
PSCo accounts for its Totem natural gas storage service arrangement with CIG as a capital lease in accordance with the authoritative guidance on lease accounting.
As a result, PSCo has a $141.1 million capital lease obligation recorded for the arrangement as of Dec.  31, 2009, 50% of which is eliminated in Xcel Energy’s consolidated balance sheet along with an equal amount of Xcel Energy’s equity investment in WYCO.
WYCO is expected to incur approximately $14 million of additional construction costs, 50 percent of which will be paid by Xcel Energy, to finalize construction and make Totem operational at full storage capacity.
Following is a summary of property held under capital leases:

<table><tr><td>Balance at December 31, 2006</td><td>$ 16,453</td></tr><tr><td>Gross increases related to prior period tax positions</td><td>1,279</td></tr><tr><td>Gross decreases related to prior period tax positions</td><td>-1,853</td></tr><tr><td>Gross increases related to current period tax positions</td><td>5,340</td></tr><tr><td>Settlements</td><td>-539</td></tr><tr><td>Expiration of statute of limitations</td><td>-271</td></tr><tr><td>Balance at December 29, 2007</td><td>$ 20,409</td></tr></table>
<table><tr><td> </td><td colspan="5"> Dec. 31, 2008</td></tr><tr><td> </td><td> Level 1</td><td> Level 2</td><td> Level 3</td><td>Counterparty Netting</td><td> Net Balance</td></tr><tr><td> </td><td colspan="5"> (Thousands of Dollars) </td></tr><tr><td> Assets</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Cash equivalents</td><td>$—</td><td>$50,000</td><td>$—</td><td>$—</td><td>$50,000</td></tr><tr><td>Nuclear decommissioning fund</td><td></td><td></td><td></td><td></td><td>—</td></tr><tr><td>Cash equivalents</td><td>—</td><td>8,449</td><td>—</td><td>—</td><td>8,449</td></tr><tr><td>Debt securities</td><td>—</td><td>491,486</td><td>109,423</td><td>—</td><td>600,909</td></tr><tr><td>Equity securities</td><td>465,936</td><td>—</td><td>—</td><td>—</td><td>465,936</td></tr><tr><td>Commodity derivatives</td><td>—</td><td>29,648</td><td>39,565</td><td>-16,245</td><td>52,968</td></tr><tr><td>Total</td><td>$465,936</td><td>$579,583</td><td>$148,988</td><td>$-16,245</td><td>$1,178,262</td></tr><tr><td> Liabilities</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Commodity derivatives</td><td>$600</td><td>$78,714</td><td>$16,344</td><td>$-41,351</td><td>$54,307</td></tr><tr><td>Interest rate derivatives</td><td>—</td><td>8,503</td><td>—</td><td>—</td><td>8,503</td></tr><tr><td>Total</td><td>$600</td><td>$87,217</td><td>$16,344</td><td>$-41,351</td><td>$62,810</td></tr></table>
<table><tr><td></td><td colspan="2">2009</td><td colspan="2">2008</td></tr><tr><td></td><td>Commodity Derivatives, Net</td><td>Nuclear Decommissioning Fund</td><td>Commodity Derivatives, Net</td><td>Nuclear Decommissioning Fund</td></tr><tr><td></td><td colspan="4">(Thousands of Dollars)</td></tr><tr><td>Balance at Jan. 1</td><td>$23,221</td><td>$109,423</td><td>$19,466</td><td>$108,656</td></tr><tr><td>Purchases, issuances, and settlements, net</td><td>-4,143</td><td>-28,356</td><td>-5,981</td><td>12,198</td></tr><tr><td>Transfers into (out of) Level 3</td><td>1,280</td><td>—</td><td>-3,962</td><td>—</td></tr><tr><td>(Losses) gains recognized in earnings</td><td>-581</td><td>—</td><td>2,129</td><td>—</td></tr><tr><td>Gains (losses) recognized as regulatory assets and liabilities</td><td>8,265</td><td>12,040</td><td>11,569</td><td>-11,431</td></tr><tr><td>Balance at Dec. 31</td><td>$28,042</td><td>$93,107</td><td>$23,221</td><td>$109,423</td></tr></table>
<table><tr><td> </td><td> (Millions of Dollars)</td></tr><tr><td>2010</td><td>$486.8</td></tr><tr><td>2011</td><td>477.1</td></tr><tr><td>2012</td><td>404.3</td></tr><tr><td>2013</td><td>340.9</td></tr><tr><td>2014</td><td>287.0</td></tr><tr><td>2015 and thereafter</td><td>1,298.2</td></tr><tr><td>Total</td><td>$3,294.3</td></tr></table>

Question: What was the total amount of Commodity Derivatives, Net in 2009? (in thousand)