allowances and the CSAPR.
The book value of each of Ameren’s, Ameren Missouri’s, and Genco’s CAIR emission allowances was less than $1 million at December 31, 2011.
The book value of Ameren’s, Ameren Missouri’s, and Genco’s CAIR emission allowances was $7 million, $2 million, and $3 million, at December 31, 2010, respectively.
Renewable energy credits and emission allowances are charged to purchased power expense and fuel expense, respectively, as they are used in operations.
The following table presents amortization expense based on usage of renewable energy credits and emission allowances, net of gains from sales, for Ameren, Ameren Missouri, Ameren Illinois, and Genco during the years ended December 31, 2011, 2010, and 2009.
The table below does not include the intangible asset impairment charges referenced above.
## Table 0 ##
(a) Less than $1 million.
(b) Includes allowances consumed that were recorded through purchase accounting.
(c) Consists of renewable energy credit expense for Marketing Company and emission allowances expense for AERG.
Impairment of Long-lived Assets We evaluate long-lived assets classified as held and used for impairment when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable.
Whether impairment has occurred is determined by comparing the estimated undiscounted cash flows attributable to the assets with the carrying value of the assets.
If the carrying value exceeds the undiscounted cash flows, we recognize an impairment charge equal to the carrying value of the assets in excess of estimated fair value.
In the period in which we determine an asset meets the held for sale criteria, we record an impairment charge to the extent the book value exceeds its fair value less cost to sell.
See Note 17 – Goodwill, Impairment and Other Charges for information about Ameren’s, Ameren Missouri’s and Genco’s impairments.
Investments Ameren and Ameren Missouri evaluate for impairment the investments held in Ameren Missouri’s nuclear decommissioning trust fund.
Losses on assets in the trust fund could result in higher funding requirements for decommissioning costs, which Ameren Missouri believes would be recovered in electric rates paid by its customers.
Accordingly, Ameren and Ameren Missouri recognize a regulatory asset on their balance sheets for losses on investments held in the nuclear decommissioning trust fund.
See Note 9 – Nuclear Decommissioning Trust Fund Investments for additional information.
Environmental Costs Liabilities for environmental costs are recorded on an undiscounted basis when it is probable that a liability has been incurred and the amount of the liability can be reasonably estimated.
Costs are expensed or deferred as a regulatory asset when it is expected that the costs will be recovered from customers in future rates.
If environmental expenditures are related to facilities currently in use, such as pollution control equipment, the cost is capitalized and depreciated over the expected life of the asset.
Unamortized Debt Discount, Premium, and Expense Discount, premium, and expense associated with longterm debt are amortized over the lives of the related issues.
Revenue Operating Revenues Ameren Missouri, Ameren Illinois and Genco record operating revenue for electric or natural gas service when it is delivered to customers.
We accrue an estimate of electric and natural gas revenues for service rendered but unbilled at the end of each accounting period.
Trading Activities We present the revenues and costs associated with certain energy derivative contracts designated as trading on a net basis in “Operating Revenues – Electric” and “Operating Revenues – Other.
” Nuclear Fuel Ameren Missouri’s cost of nuclear fuel is capitalized and then amortized to fuel expense on a unit-of-production basis.
Spent fuel disposal cost is based on net kilowatthours generated and sold, and that cost is charged to expense.
Purchased Gas, Power and Fuel Rate-adjustment Mechanisms Ameren’s utility subsidiaries have various rateadjustment mechanisms in place that provide for the recovery of purchased natural gas and electric fuel and purchased power costs.
See Note 2 – Rate and Regulatory Matters for the regulatory assets and liabilities recorded at December 31, 2011, and 2010, related to the rateadjustment mechanisms discussed below.
In Ameren Missouri’s and Ameren Illinois’ retail natural gas utility jurisdictions, changes in natural gas costs are generally reflected in billings to their natural gas utility customers through PGA clauses.
The difference between actual natural gas costs and costs billed to customers in a given period are deferred as regulatory assets or liabilities.
The deferred amounts are either billed or refunded to natural gas utility customers in a subsequent period.
markets operated by MISO.
The power and related procurement costs incurred by Ameren Illinois are passed directly to its customers through a cost recovery mechanism.
The IPA administers a RFP process that procures Ameren Illinois’ expected supply obligation.
Since the start of this process, the ICC has approved the outcomes of multiple electric power procurement RFPs for energy, capacity, and renewable energy credits covering different time periods.
A portion of the electric power supply required for Ameren Illinois to satisfy its distribution customers’ requirements is purchased in the RFP process administered by the IPA from Marketing Company on behalf of Genco and AERG.
In addition, as part of the 2007 Illinois Electric Settlement Agreement, Ameren Illinois entered into financial contracts with Marketing Company (for the benefit of Genco and AERG) to lock in energy prices for 400 to 1,000 megawatts annually of its round-the-clock power requirements during the period June 1, 2008, through December 31, 2012, at the market prices relevant at that time.
These financial contracts do not include capacity, are not load-following products, and do not involve the physical delivery of energy.
See Note 2 – Rate and Regulatory Matters, Note 14 – Related Party Transactions and Note 15 – Commitments and Contingencies under Part II, Item 8, of this report for additional information on power procurement in Illinois.
Merchant Generation Genco and AERG have entered into power supply agreements with Marketing Company whereby Genco and AERG sell, and Marketing Company purchases, all of the capacity and energy available from Genco’s and AERG’s generation energy centers and the associated energy.
These power supply agreements continue through December 31, 2022, and from year to year thereafter unless either party elects to terminate the agreement by providing the other party with no less than six months’ advance written notice.
EEI and Marketing Company have entered into a power supply agreement for EEI to sell all of its capacity and energy to Marketing Company.
This agreement expires on May 31, 2016.
All of Genco’s, AERG’s and EEI’s energy centers compete for the sale of energy and capacity in the competitive energy markets through Marketing Company.
See Note 14 – Related Party Transactions under Part II, Item 8, of this report for additional information.
POWER GENERATION The following table presents the source of electric generation, excluding purchased power, for the years ended December 31, 2011, 2010 and 2009:
## Table 1 ##
(a) Includes amounts for Ameren registrant and nonregistrant subsidiaries and intercompany eliminations.
(b) Less than 1% of total fuel supply.
As part of the acquisition of GFSI, we acquired gross net operating loss (“NOL”) carry forwards of $64,431; of which, only $34,592 are expected to be utilized due to the application of IRC Section 382.
Separately, as of June 30, 2010, we had state NOL carry forwards of $838.
These losses have varying expiration dates, ranging from 2012 to 2029.
Based on state tax rules which restrict our usage of these losses, we believe it is more likely than not that $306 of these losses will expire unutilized.
Accordingly, a valuation allowance of $306 has been recorded against these assets as of June 30, 2010.
The Company paid income taxes of $42,116, $62,965, and $51,709 in 2010, 2009, and 2008, respectively.
At June 30, 2009, the Company had $5,518 of unrecognized tax benefits.
At June 30, 2010, the Company had $7,187 of unrecognized tax benefits, of which, $4,989, if recognized, would affect our effective tax rate.
We had accrued interest and penalties of $890 and $732 related to uncertain tax positions at June 30, 2010 and 2009, respectively.
A reconciliation of the unrecognized tax benefits for the years ended June 30, 2010 and 2009 follows:
## Table 2 ##
During the fiscal year ended June 30, 2010, the Internal Revenue Service commenced an examination of the Company’s U. S.  federal income tax returns for fiscal years ended June 2008 through 2009.
The U. S.  federal and state income tax returns for June 30, 2007 and all subsequent years still remain subject to examination as of June 30, 2010 under statute of limitations rules.
We anticipate potential changes resulting from the expiration of statutes of limitations of up to $965 could reduce the unrecognized tax benefits balance within twelve months of June 30, 2010.
NOTE 8: INDUSTRY AND SUPPLIER CONCENTRATIONS The Company sells its products to banks, credit unions, and financial institutions throughout the United States and generally does not require collateral.
All billings to customers are due 30 days from date of billing.
Reserves (which are insignificant at June 30, 2010, 2009 and 2008) are maintained for potential credit losses.
In addition, the Company purchases most of its computer hardware and related maintenance for resale in relation to installation of JHA software systems from two suppliers.
There are a limited number of hardware suppliers for these required items.
If these relationships were terminated, it could have a significant negative impact on the future operations of the Company.
NOTE 9: STOCK BASED COMPENSATION PLANS The Company previously issued options to employees under the 1996 Stock Option Plan (“1996 SOP”) and currently issues options to outside directors under the 2005 Non-Qualified Stock Option Plan (“2005 NSOP”).1996 SOP The 1996 SOP was adopted by the Company on October 29, 1996, for its employees.
Terms and vesting periods

<table><tr><td></td><td>2011</td><td> 2010</td><td> 2009</td></tr><tr><td>Ameren Missouri</td><td>$(a)</td><td>$6</td><td>$2</td></tr><tr><td>Ameren Illinois</td><td>3</td><td>7</td><td>9</td></tr><tr><td>Genco<sup>(b)</sup></td><td>2</td><td>18</td><td>24</td></tr><tr><td>Other<sup>(b)(c)</sup></td><td>1</td><td>4</td><td>5</td></tr><tr><td>Ameren<sup>(b)</sup></td><td>$6</td><td>$35</td><td>$40</td></tr></table>
<table><tr><td></td><td>Coal</td><td>Nuclear</td><td>Natural Gas</td><td>Renewables</td><td>Oil</td></tr><tr><td> Ameren:<sup>(a)</sup></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>2011</td><td>85%</td><td>12%</td><td>1%</td><td>2%</td><td>(b)%</td></tr><tr><td>2010</td><td>85</td><td>12</td><td>1</td><td>2</td><td>(b)</td></tr><tr><td>2009</td><td>83</td><td>13</td><td>1</td><td>3</td><td>(b)</td></tr><tr><td> Ameren Missouri:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>2011</td><td>77%</td><td>19%</td><td>1%</td><td>3%</td><td>(b)%</td></tr><tr><td>2010</td><td>77</td><td>19</td><td>1</td><td>3</td><td>-</td></tr><tr><td>2009</td><td>75</td><td>21</td><td>(b)</td><td>4</td><td>-</td></tr><tr><td> Merchant Generation:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>2011</td><td>98%</td><td>-%</td><td>2%</td><td>-%</td><td>(b)%</td></tr><tr><td>2010</td><td>98</td><td>-</td><td>2</td><td>-</td><td>(b)</td></tr><tr><td>2009</td><td>99</td><td>-</td><td>1</td><td>-</td><td>(b)</td></tr><tr><td> Genco:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>2011</td><td>99%</td><td>-%</td><td>1%</td><td>-%</td><td>(b)%</td></tr><tr><td>2010</td><td>99</td><td>-</td><td>1</td><td>-</td><td>(b)</td></tr><tr><td>2009</td><td>100</td><td>-</td><td>(b)</td><td>-</td><td>(b)</td></tr></table>
<table><tr><td></td><td>Unrecognized Tax Benefits</td></tr><tr><td>Balance at July 1, 2008</td><td>$ 4,055</td></tr><tr><td>Additions for current year tax positions</td><td>1,044</td></tr><tr><td>Additions for prior year tax positions</td><td>2,052</td></tr><tr><td>Reductions for prior year tax positions</td><td>-110</td></tr><tr><td>Settlements</td><td>-936</td></tr><tr><td>Reductions related to expirations of statute of limitations</td><td>-587</td></tr><tr><td>Balance at June 30, 2009</td><td>5,518</td></tr><tr><td>Additions for current year tax positions</td><td>691</td></tr><tr><td>Reductions for current year tax positions</td><td>-39</td></tr><tr><td>Additions for prior year tax positions</td><td>2,049</td></tr><tr><td>Reductions for prior year tax positions</td><td>-298</td></tr><tr><td>Settlements</td><td>-</td></tr><tr><td>Reductions related to expirations of statute of limitations</td><td>-734</td></tr><tr><td>Balance at June 30, 2010</td><td>$ 7,187</td></tr></table>

Question: if the companies accounting policy were to include accrued interest and penalties in utp , what would the balance be as of at june 30 2010?
Answer: 8077.0