Eversource 2014 Annual Report Download - page 104

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included in the Company's reserve for environmental costs, the $12.2 million accrual ($1.4 million for CL&P, $1.1 million for NSTAR Electric, $5
million for PSNH, and $0.2 million for WMECO) represents management's best estimate of the liability and no additional loss is anticipated.
 Of the total environmental sites, 9sites (1for CL&P, 3for NSTAR Electric and 3for PSNH) are superfund sites under the federal
Comprehensive Environmental Response, Compensation and Liability Act of 1980 (CERCLA) and its amendments or state equivalents for which the
Company has been notified that it is a potentially responsible party but for which the site assessment and remediation are not being managed by the
Company. As of December 31, 2014, a liability of $0.7 million accrued on these sites represents management's best estimate of its potential
remediation costs with respect to these superfund sites.
 PSNH, NSTAR Gas and Yankee Gas have rate recovery mechanisms for MGP related environmental costs. CL&P
recovers a certain level of environmental costs currently in rates but does not have an environmental cost recovery tracking mechanism.
Accordingly, changes in CL&P's environmental reserves impact CL&P's Net Income. NSTAR Electric and WMECO do not have a separate
regulatory mechanism to recover environmental costs from its customers, and changes in NSTAR Electric's and WMECO's environmental reserves
impact Net Income.
B. Long-Term Contractual Arrangements

The estimated future annual costs of significant long-term contractual arrangements as of December 31, 2014 are
as follows:
NU
 2015 2016 2017 2018 2019 Thereafter Total
Supply and Stranded Cost $196.6 $169.2 $101.9 $65.3 $38.1 $82.4 $653.5
Renewable Energy 204.3 240.5 239.6 204.2 202.9 1,994.6 3,086.1
Peaker CfDs 26.3 25.4 10.5 - - - 62.2
Natural Gas Procurement
133.7 116.3 45.6 31.9 25.8 85.1 438.4
Coal, Wood and Other 99.0 25.2 5.0 5.0 1.9 15.0 151.1
Transmission Support Commitments 25.9 21.6 19.0 21.2 21.3 21.3 130.3
Total $685.8 $598.2 $421.6 $327.6 $290.0 $2,198.4 $4,521.6
CL&P
 2015 2016 2017 2018 2019 Thereafter Total
Supply and Stranded Cost $134.3 $136.8 $79.0 $42.0 $25.0 $43.6 $460.7
Renewable Energy 61.2 70.3 71.3 72.1 72.1 715.9 1,062.9
Peaker CfDs 26.3 25.4 10.5 - - - 62.2
Transmission Support Commitments 10.2 8.5 7.5 8.4 8.4 8.4 51.4
Yankee Billings 1.4 0.8 0.8 0.9 0.9 11.8 16.6
Total $233.4 $241.8 $169.1 $123.4 $106.4 $779.7 $1,653.8
NSTAR Electric
 2015 2016 2017 2018 2019 Thereafter Total
Supply and Stranded Cost $34.3 $14.1 $4.8 $5.5 $5.5 $31.4 $95.6
Renewable Energy 85.4 99.9 96.9 59.6 57.7 319.8 719.3
Transmission Support Commitments 8.1 6.7 5.9 6.6 6.6 6.6 40.5
Yankee Billings 0.5 0.3 0.3 0.3 0.3 4.0 5.7
Total $128.3$121.0 $107.9 $72.0 $70.1 $361.8 $861.1
PSNH
 2015 2016 2017 2018 2019 Thereafter Total
Supply and Stranded Cost $28.0 $18.3 $18.1 $17.8 $7.6 $7.4 $97.2
Renewable Energy 57.7 67.9 69.0 70.1 70.7 932.4 1,267.8
Coal, Wood and Other 99.0 25.2 5.0 5.0 1.9 15.0 151.1
Transmission Support Commitments 5.5 4.6 4.0 4.5 4.5 4.5 27.6
Yankee Billings 0.4 0.3 0.3 0.3 0.3 4.7 6.3
Total $190.6 $116.3 $96.4 $97.7 $85.0 $964.0 $1,550.0
WMECO
 2015 2016 2017 2018 2019 Thereafter Total
Renewable Energy $- $2.4 $2.4 $2.4 $2.4 $26.5 $36.1
Transmission Support Commitments 2.1 1.8 1.6 1.7 1.8 1.8 10.8
Yankee Billings 0.3 0.2 0.2 0.2 0.2 3.0 4.1
Total $2.4 $4.4 $4.2 $4.3 $4.4 $31.3 $51.0
 CL&P, NSTAR Electric and PSNH have various IPP contracts or purchase obligations for electricity, including payment
obligations resulting from the buydown of electricity purchase contracts. Such contracts extend through 2024 for CL&P, 2030 for NSTAR Electric
and 2023 for PSNH.
In addition, CL&P, along with UI, has four capacity CfDs for a total of approximately 787 MW of capacity consisting of three generation projects
and one demand response project. The capacity CfDs extend through 2026 and obligate both CL&P and UI to make or receive payments on a
monthly basis to or from the generation facilities based on the difference between a set capacity price and the capacity market prices received by the
generation facilities in the ISO-NE capacity markets. CL&P has a sharing agreement with UI, whereby UI will share 20 percent of the costs and
benefits of these contracts. CL&P's portion of the costs and benefits of these contracts will be paid by or refunded to CL&P's customers.