NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)

1.

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (All Companies)

A.

Presentation

Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with accounting principles generally accepted in the United States of America have been omitted pursuant to the rules and regulations of the Securities and Exchange Commission (SEC).  The accompanying unaudited condensed consolidated financial statements should be read in conjunction with the entirety of this Quarterly Report on Form 10-Q, the first quarter 2008 Quarterly Report on Form 10-Q and the Annual Reports of Northeast Utilities (NU or the company), The Connecticut Light and Power Company (CL&P), Public Service Company of New Hampshire (PSNH), and Western Massachusetts Electric Company (WMECO), which were filed with the SEC as part of the Northeast Utilities and subsidiaries combined 2007 Annual Report on Form 10-K (NU 2007 Form 10-K).  The accompanying condensed consolidated financial statements contain, in the opinion of management, all adjustments (including normal, recurring adjustments) necessary to present fairly NU's and the above companies' financial position at June 30, 2008 and December 31, 2007, the results of operations for the three and six months ended June 30, 2008 and 2007 and cash flows for the six months ended June 30, 2008 and 2007.  The results of operations and cash flows for the six months ended June 30, 2008 and 2007 are not necessarily indicative of the results expected for a full year.  

The condensed consolidated financial statements of NU and its subsidiaries, as applicable, include the accounts of all their respective subsidiaries.  Intercompany transactions have been eliminated in consolidation.

The preparation of condensed consolidated financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent liabilities at the date of the condensed consolidated financial statements and the reported amounts of revenues and expenses during the reporting period.  Actual results could differ from those estimates.

Certain reclassifications of prior period data included in the accompanying condensed consolidated financial statements have been made to conform with the current period's presentation.

NU's condensed consolidated statements of income for the three and six months ended June 30, 2007 classify activity related to the following subsidiaries as discontinued operations:

·

Northeast Generation Company (NGC),

·

The Mt. Tom generating plant (Mt. Tom) previously owned by Holyoke Water Power Company (HWP), and

·

Select Energy Contracting, Inc. (including Reeds Ferry Supply Co., Inc.) (SECI).  

For the three and six months ended June 30, 2007, portions of SECI that were included in continuing operations have been reclassified to discontinued operations in the condensed consolidated statements of income as a result of winding down SECI operations in 2007.  The amounts of these reclassifications are as follows:

For further information regarding discontinued operations, see Note 7, "Discontinued Operations," to the condensed consolidated financial statements.  

6

B.

Regulatory Accounting

The accounting policies of the regulated companies conform to accounting principles generally accepted in the United States of America applicable to rate-regulated enterprises and historically reflect the effects of the rate-making process in accordance with Statement of Financial Accounting Standards (SFAS) No. 71, "Accounting for the Effects of Certain Types of Regulation."

The transmission and distribution segments of CL&P, PSNH and WMECO, along with PSNH's generation segment and Yankee Gas Service Company's (Yankee Gas) distribution segment, continue to be cost-of-service, rate regulated.  Management believes that the application of SFAS No. 71 to those segments continues to be appropriate.  Management also believes it is probable that NU's regulated companies will recover their investments in long-lived assets, including regulatory assets.  All material net regulatory assets are earning an equity return, except for securitized regulatory assets and the majority of deferred benefit costs, which are not supported by equity.  Amortization and deferrals of regulatory assets/(liabilities) are included on a net basis in amortization expense on the accompanying condensed consolidated statements of income.  

Regulatory Assets:  The components of regulatory assets are as follows:  

For information regarding regulatory assets offsetting regulated company derivative liabilities, see Note 2, "Derivative Instruments," to the condensed consolidated financial statements.  

Included in NU's other regulatory assets are the regulatory assets associated with the implementation of Financial Accounting Standards Board (FASB) Interpretation No. (FIN) 47, "Accounting for Conditional Asset Retirement Obligations - an interpretation of FASB Statement No. 143," totaling $43 million at June 30, 2008 and $40.6 million at December 31, 2007.  Management believes that recovery of these regulatory assets is probable.  

Additionally, the regulated companies had $2.8 million and $11.9 million of regulatory costs at June 30, 2008 and December 31, 2007, respectively, that were included in deferred debits and other assets - other on the accompanying condensed consolidated balance sheets.  These amounts represent regulatory costs that have not yet been approved for recovery by the applicable regulatory agency.  Management believes these costs are recoverable in future cost-of-service regulated rates.

7

Regulatory Liabilities:  The components of regulatory liabilities are as follows:  

For information regarding regulatory liabilities offsetting regulated company derivative assets, see Note 2, "Derivative Instruments," to the condensed consolidated financial statements.

C.

Fair Value Measurements

On January 1, 2008, the company adopted SFAS No. 157, "Fair Value Measurements," which establishes a framework for defining and measuring fair value and requires expanded disclosures about fair value measurements.  SFAS No. 157:

·

Defines fair value as the price that would be received for the sale of an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (an exit price).

·

Establishes a three-level fair value hierarchy based upon the observability of inputs to the valuations of assets and liabilities.

·

Requires consideration of the company's own creditworthiness and risk of nonperformance when valuing its liabilities.

·

Requires prospective implementation with adjustments to fair value reflected in earnings, similar to a change in estimate, with exceptions including recognition of previously deferred initial gains or losses described below.  

·

Requires recognition in retained earnings of previously deferred initial gains or losses on derivative contracts whose estimated fair values are based on significant unobservable inputs.  Recognition of the initial gains or losses was previously prohibited under Emerging Issues Task Force Issue No. 02-3, " Issues Involved in Accounting for Derivative Contracts Held for Trading Purposes and Contracts Involved in Energy Trading and Risk Management Activities."  CL&P’s initial gains and losses on its contracts for differences (CfDs) that would have been recorded in retained earnings upon adoption were recorded as regulatory assets and liabilities because their costs or benefits are expected to be fully recovered from or refunded to customers.  

The company applied SFAS No. 157 to the regulated and unregulated companies' derivative contracts that are recorded at fair value and to the marketable securities held in NU's Rabbi Trust and WMECO's prior spent nuclear fuel trust.  SFAS No. 157 also applies to investment valuations for NU’s pension and other postretirement benefit plans beginning as of December 31, 2008, and beginning in 2009, to nonrecurring fair value measurements of non-financial assets and liabilities such as goodwill and asset retirement obligations.

As a result of adopting SFAS No. 157, the company recorded a pre-tax charge to earnings of $6.1 million as of January 1, 2008 related to derivative liabilities for its remaining unregulated wholesale marketing contracts.  For the three and six months ended June 30, 2008, the company recorded a $1 million and $2.2 million pre-tax benefit, respectively, to partially reverse the exit price impact recorded under SFAS No. 157 as the company served out rather than exited the contracts.  

The company also recorded changes in fair value of certain derivative contracts of CL&P.  Because CL&P is a cost-of-service, rate regulated entity, the cost or benefit of the contracts is expected to be fully recovered from or refunded to CL&P's customers and an offsetting regulatory asset or liability was recorded to reflect these changes.  As of January 1, 2008, implementing SFAS No. 157

8

resulted in a total increase to CL&P's derivative liabilities, with an offset to regulatory assets, of approximately $590 million, and a total decrease to derivative assets, with an offset to regulatory liabilities, of approximately $30 million.

Fair Value Hierarchy:  As required by SFAS No. 157, in measuring fair value the company uses observable market data when available and minimizes the use of unobservable inputs.  Unobservable inputs are needed to value certain derivative contracts due to complexities in contractual terms and the long duration of a contract.  SFAS No. 157 requires inputs used in fair value measurements to be categorized into three fair value hierarchy levels for disclosure purposes.  The entire fair value measurement is categorized based on the lowest level of input that is significant to the fair value measurement.  

The three levels of the fair value hierarchy are described below:

Level 1 - Inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities as of the reporting date.  Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  

Level 2 - Inputs are quoted prices for similar instruments in active markets, quoted prices for identical or similar instruments in markets that are not active, and model-derived valuations in which all significant inputs are observable.

Level 3 - Quoted market prices are not available.  Fair value is derived from valuation techniques in which one or more significant inputs or assumptions are unobservable.  Where possible, valuation techniques incorporate observable market inputs that can be validated to external sources such as industry exchanges, including prices of energy and energy-related products.  Significant unobservable inputs are used in the valuations, including items such as energy and energy-related product prices in future years for which observable prices are not yet available, future contract quantities under full-requirements or supplemental sales contracts, and market volatilities.  Items valued using these valuation techniques are classified according to the lowest level for which there is at least one input that is significant to the valuation.  Therefore, an item may be classified in Level 3 even though there may be some significant inputs that are readily observable.   

Determination of Fair Value:  The following is a description of the valuation techniques utilized in our fair value measurements:

Derivative contracts:   Many of the company's derivative positions that are recorded at fair value are classified as Level 3 within the fair value hierarchy and are valued using models that incorporate both observable and unobservable inputs.  Fair value is modeled using techniques such as discounted cash flow approaches adjusted for assumptions relating to exit price and the Black-Scholes option pricing model, incorporating the terms of the contracts.  Significant unobservable inputs utilized in the valuations include energy and energy-related product prices for future years for long-dated derivative contracts, future contract quantities under full requirements and supplemental sales contracts, and market volatilities.  Discounted cash flow valuations incorporate estimates of premiums or discounts that would be required by a market participant to arrive at an exit price, using available historical market transaction information.  Valuations of derivative contracts also reflect nonperformance risk, including credit.  The derivative contracts classified as Level 3 include NU Enterprises, Inc.'s (NU Enterprises) remaining wholesale marketing contract and its related supply contracts, CL&P's CfDs, CL&P's contracts with certain independent power producers (IPPs) and regulated company options and financial transmission rights (FTRs).

Other derivative contracts recorded at fair value are classified as Level 2 within the fair value hierarchy.  An active market for the same or similar contracts exists for these contracts, which include regulated company forward contracts to purchase energy and interest rate swap agreements for the regulated companies and NU parent.  For these contracts, valuations are based on quoted prices in the market and include some modeling using market-based assumptions.  

For further information on derivative contracts, see Note 2, "Derivative Instruments," to the condensed consolidated financial statements.

Marketable securities:  The company holds in trust marketable securities, which include equity securities, mutual funds and cash equivalents, and fixed maturity securities.

Equity securities, mutual funds and cash equivalents are classified as Level 1 in the fair value hierarchy.  These investments are traded in active markets and quoted prices are available for identical investments.

Fixed maturity securities classified as Level 2 within the fair value hierarchy include U.S. Treasury securities, corporate bonds, collateralized mortgage obligations, U.S. pass-through bonds, asset-backed securities, commercial mortgage-backed securities, and commercial paper.  The fair value of these instruments is estimated using pricing models, quoted prices of securities with similar characteristics or discounted cash flows.  The pricing models utilize observable inputs such as recent trades for the same or similar instruments, yield curves, discount margins and bond structures.  

9

For further information see Note 3, "Fair Value Measurements," to the accompanying condensed consolidated financial statements.

D.

Allowance for Funds Used During Construction

The allowance for funds used during construction (AFUDC) is included in the cost of the regulated companies' utility plant and represents the cost of borrowed and equity funds used to finance construction.  The portion of AFUDC attributable to borrowed funds is recorded as a reduction of other interest expense, and the AFUDC related to equity funds is recorded as other income on the accompanying condensed consolidated statements of income:

The regulated companies' average AFUDC rate is based on a Federal Energy Regulatory Commission (FERC) prescribed formula that produces an average rate using the cost of a company's short-term financings as well as a company's capitalization (preferred stock, long-term debt and common equity).  The average rate is applied to eligible construction work in progress (CWIP) amounts to calculate AFUDC.  Although AFUDC is recorded on 100 percent of CL&P's CWIP for its major transmission projects in southwest Connecticut, 50 percent of this AFUDC is being reserved as a regulatory liability to reflect current rate base recovery for 50 percent of the CWIP as a result of FERC approved transmission incentives.

E.

Sale of Customer Receivables

Prior to June 30, 2008, under the Receivables Purchase and Sale Agreement, CL&P Receivables Corporation (CRC), a consolidated, wholly-owned subsidiary of CL&P, purchased an undivided interest in CL&P's accounts receivable and unbilled revenues and could sell up to $100 million thereof to a financial institution.  At December 31, 2007, there were $20 million in such sales.  On June 30, 2008, there were no receivables sold under that facility, and CL&P chose to terminate the Receivables Purchase and Sale Agreement.   

At December 31, 2007, amounts totaling $308.2 million sold to CRC by CL&P but not sold to the financial institution were included in investments in securitizable assets on the accompanying condensed consolidated balance sheet.  These amounts would have been excluded from CL&P's assets in the event of bankruptcy by CL&P.  As of June 30, 2008, these amounts were no longer excludable from CL&P's assets in the event of bankruptcy and were no longer securitizable.  Since CL&P chose to terminate the Receivables Purchase and Sale Agreement at June 30, 2008, amounts held by CRC were included in accounts receivables and unbilled revenues on the accompanying condensed consolidated balance sheet.  

F.

Cash and Cash Equivalents

Cash and cash equivalents include cash on hand and short-term cash investments that are highly liquid in nature and have original maturities of three months or less.  At the end of each reporting period, any overdraft amounts are reclassified from cash and cash equivalents to accounts payable.

G.

Special Deposits and Counterparty Deposits

To the extent Select Energy, Inc. (Select Energy) requires collateral from counterparties, or the counterparties require collateral from Select Energy, cash held on deposit by Select Energy or with unaffiliated counterparties and brokerage firms as a part of the total collateral required based on Select Energy’s position in the transaction.  Select Energy's right to use cash collateral is determined by the terms of the related agreements.  Key factors affecting the unrestricted status of a portion of this cash collateral include the financial standing of Select Energy and of NU as its credit supporter.  

Special deposits paid to unaffiliated counterparties and brokerage firms totaled $18.9 million at December 31, 2007.  There were no special deposits as of June 30, 2008.  These amounts are recorded as current assets and are included in prepayments and other on the accompanying condensed consolidated balance sheets.  Balances collected from counterparties resulting from Select Energy’s credit management activities totaled $6.4 million at June 30, 2008.  There were no counterparty deposits for Select Energy as of December 31, 2007.  These amounts are recorded as current liabilities and are included in other current liabilities on the accompanying condensed consolidated balance sheets.  

10

CL&P and WMECO had $24.8 million and $9 million, respectively, of counterparty deposits at June 30, 2008 related to credit management activities.  These amounts were recorded as current liabilities - other on the accompanying condensed consolidated balance sheets.  There were no counterparty deposits for these companies as of December 31, 2007.

NU also had amounts on deposit related to special purpose entities used to facilitate the issuance of rate reduction bonds and certificates.  These amounts totaled $34.5 million and $43.5 million at June 30, 2008 and December 31, 2007, respectively.  These amounts totaled $8.9 million and $14.3 million for CL&P, $21.2 million and $24.4 million for PSNH, and $4.4 million and $4.8 million for WMECO at June 30, 2008 and December 31, 2007, respectively.  In addition, the company had $6.5 million and $6.4 million in other cash deposits held with unaffiliated parties at June 30, 2008 and December 31, 2007, respectively, primarily related to CL&P's transmission projects.  These amounts were included in deferred debits and other assets - other on the accompanying condensed consolidated balance sheets.

H.

Other Income, Net

The pre-tax components of other income/(loss) items are as follows:

11

Investment income for NU includes equity in earnings of regional nuclear generating and transmission companies of $0.3 million and $0.4 million for the three months ended June 30, 2008 and 2007, respectively, and $1 million and $1.1 million for the six months ended June 30, 2008 and 2007, respectively.  Equity in earnings relates to the company's investment in Connecticut Yankee Atomic Power Company (CYAPC), Maine Yankee Atomic Power Company, Yankee Atomic Electric Company and two regional transmission companies.

I.

Income Taxes

Tax Positions:   NU is currently working to resolve all open tax years.  It is reasonably possible that one or more of these open tax years could be resolved within the next twelve months.  NU has significantly advanced settlement positions with the Internal Revenue Service related to the timing of deducting expenses.  These settlement positions involve the 2002-2004 tax years, and if finally agreed upon, would result in a decrease in unrecognized tax benefits in the range of $20 million to $22 million, of which the tax impact on earnings is not expected to be material.  These ranges are $7 million to $8 million for CL&P, $9 million to $10 million for PSNH and $2 million to $3 million for WMECO.

J.

Other Taxes

Certain excise taxes levied by state or local governments are collected by NU from its customers.  These excise taxes are accounted for on a gross basis with collections in revenues and payments in expenses.  For the three and six months ended June 30, 2008, gross receipts taxes, franchise taxes and other excise taxes of $27.4 million and $58.4 million, respectively, were included in operating revenues and taxes other than income taxes on the accompanying condensed consolidated statements of income.  For the three and six months ended June 30, 2007, these amounts totaled $26.3 million and $58 million, respectively.  Certain sales taxes are also collected by the regulated companies from their customers as agents for state and local governments and are recorded on a net basis with no impact on the accompanying condensed consolidated statements of income.  

2.

DERIVATIVE INSTRUMENTS (NU, Select Energy, CL&P, PSNH, Yankee Gas)

Contracts that are derivatives and do not meet the requirements to be treated as a cash flow hedge or normal purchase or normal sale are recorded at fair value with changes in fair value included in earnings.  For those contracts that meet the definition of a derivative and meet the cash flow hedge requirements, including those related to initial and ongoing documentation, the contract is recorded at fair value and the changes in the fair value of the effective portion of those contracts are recognized in accumulated other comprehensive income.  Cash flow hedges include forward interest rate swap agreements on proposed debt issuances.  When a cash flow hedge is settled, the settlement amount is recorded in accumulated other comprehensive income and is amortized into earnings over the term of the debt.  Cash flow hedges impact net income when the hedged items affect earnings, when hedge ineffectiveness is measured and recorded, or when the forecasted transaction being hedged is improbable of occurring.  Derivative contracts designated as fair value hedges and the items they are hedging are both recorded at fair value with changes in fair value of both items recognized in earnings.  Derivative contracts that meet the requirements of a normal purchase or sale, and are so designated, are recognized in revenues or expenses, as applicable, when the quantity of the contract is delivered.  

The fair value of the company's derivative contracts may not represent amounts that will be realized.  For further information on the fair value of derivative contracts, see Note 1C, "Summary of Significant Accounting Policies - Fair Value Measurements," and Note 3, "Fair Value Measurements," to the condensed consolidated financial statements.  On the accompanying condensed consolidated balance sheets at June 30, 2008 and December 31, 2007, these amounts are recorded as current or long-term derivative assets or liabilities and are summarized as follows:

12

For the regulated companies, except for existing interest rate swap agreements, offsetting regulatory assets or liabilities are recorded for the changes in fair value of their contracts, as these contracts were part of the stranded costs or are current regulated operating costs, and management believes that these costs will continue to be recovered or refunded in cost-of-service, regulated rates.

The business activities of NU Enterprises that result in the recognition of derivative assets also result in exposures to credit risk of energy marketing and trading counterparties.  At June 30, 2008, Select Energy had $44.6 million of derivative assets from wholesale activities that are exposed to counterparty credit risk, a significant portion of which is contracted with several creditworthy and rated public entities.

NU Enterprises - Wholesale:  Certain electric derivative contracts are part of NU Enterprises' remaining wholesale marketing business.  These contracts include short-term and long-term electric supply contracts and a contract to sell electricity to the New York Municipal Power Agency (NYMPA) (an agency that is comprised of municipalities) that expires in 2013.  The fair value of the contracts was determined using prices from external sources through 2011 for on-peak and off-peak periods and through 2012 for on-peak periods, except for one contract, under which a portion of the fair value is also determined from a model based on natural gas prices and a heat-rate conversion factor to electricity for off-peak periods in 2012 and for all periods in 2013.  The 2007 balances also included a full requirements contract and the related short-term supply contracts to sell electricity to a utility.  These contracts expired on May 31, 2008.  

Regulated Companies - Gas - Supply:  Yankee Gas's supply derivatives consist of peaking supply arrangements to serve winter load obligations and firm retail sales contracts with options to curtail delivery.  These contracts are subject to fair value accounting as these contracts are derivatives that cannot be designated as normal purchases and sales because of the optionality in the contract terms.  An offsetting regulatory liability/asset was recorded for these amounts as management believes that these costs will be refunded or recovered in rates.

Regulated Companies - Gas - Interest Rate Hedging:   Yankee Gas has a forward interest rate swap agreement to hedge the interest cash outflows associated with its planned $100 million debt issuance in September 2008.  The interest rate swap is based on a 10-year LIBOR swap rate and matches the index used for the debt issuance.  As a cash flow hedge, the fair value of the hedge is recorded as a derivative liability and derivative asset on the accompanying condensed consolidated balance sheets as of June 30, 2008 and December 31, 2007, respectively, with an offsetting amount, net of tax, included in accumulated other comprehensive income.  

13

Regulated Companies - Electric - Supply/Stranded Costs :  CL&P has contracts with two IPPs to purchase power that contain pricing provisions that are not clearly and closely related to the price of power and therefore do not qualify for the normal purchases and sales exception.  The fair values of these derivatives at June 30, 2008 included a derivative asset with a fair value of $381 million and a derivative liability with a fair value of $38.2 million.  An offsetting regulatory liability and an offsetting regulatory asset were recorded, as these contracts are part of stranded costs, and management believes that these costs will continue to be recovered or refunded in cost-of-service, regulated rates.  At December 31, 2007, the fair values of these derivatives included a derivative asset with a fair value of $311.2 million and a derivative liability with a fair value of $31.8 million.

CL&P has entered into FTR contracts and bilateral basis swaps to limit the congestion costs associated with its standard offer contracts.  An offsetting regulatory asset or liability has been recorded as management believes that these costs will be recovered or refunded in rates.  At June 30, 2008, the fair value of these contracts was recorded as a derivative asset of $3.2 million on the accompanying condensed consolidated balance sheets.  At December 31, 2007, the fair value of these contracts was recorded as a derivative asset of $1.4 million and a derivative liability of $1.3 million on the accompanying condensed consolidated balance sheets.  

Pursuant to Public Act 05-01, "An Act Concerning Energy Independence," in August 2007, the Connecticut Department of Public Utility Control (DPUC) approved two CL&P contracts associated with the capacity of two generating projects to be built or modified.  The DPUC also approved two capacity-related contracts entered into by The United Illuminating Company (UI), one with a generating project to be built and one with a new demand response project.  The total capacity of these four projects is expected to be approximately 787 megawatts (MW).  The contracts, referred to as CfDs, obligate the utilities' customers to pay the difference between a set capacity price and the forward capacity market price that the projects receive in the New England Independent System Operator (ISO-NE) capacity markets for periods of up to 15 years beginning in 2009.  As directed by the DPUC, CL&P has an agreement with UI under which it will share the costs and benefits of these four CfDs, with 80 percent to CL&P and 20 percent to UI.  The ultimate cost to CL&P under the contracts will depend on the capacity prices that the projects receive in the ISO-NE capacity markets.  At June 30, 2008, the fair value of the CL&P CfDs was recorded as a derivative liability of $689.5 million.  The fair values of UI's share of the CL&P's contracts and CL&P's share of UI's contracts were recorded as a derivative asset of $98.6 million.  An offsetting regulatory asset of $590.9 million was recorded, as management believes these amounts will be recovered from or refunded to customers in cost-of-service, regulated rates.  The value of CL&P's CfDs at June 30, 2008 included approximately $100 million of initial gains and losses, previously deferred due to the use of significant unobservable inputs in the valuation, that were recorded upon adoption of SFAS No. 157 on January 1, 2008.  At December 31, 2007, changes in CfD fair values since inception were recorded as a derivative liability of $107.1 million, and UI's share and one CL&P CfD were recorded as derivative assets of $20.8 million.  Offsetting regulatory assets of $86.7 million and regulatory liabilities of $0.4 million were also recorded at December 31, 2007.  A 2007 NRG Energy, Inc. (NRG) appeal of the DPUC's decision selecting the CfDs was taken into consideration in valuing the CfDs as of December 31, 2007, reducing the net negative derivative values by approximately $215 million.  In February 2008, the appeal was denied, which increased derivative liabilities in 2008.

PSNH has electricity procurement contracts that are derivatives.  The fair values of these contracts are calculated based on market prices and were recorded as derivative assets totaling $51.8 million at June 30, 2008.  At December 31, 2007, the fair value was recorded as a derivative asset of $1.5 million and a derivative liability of $2.5 million.  An offsetting regulatory liability/asset was recorded as management believes that these costs will be refunded or recovered in rates as the energy is delivered.