43 as of december 31 , 2012 , power had incurred approximately $ 85 million in costs related to superstorm sandy , primarily comprised of repairs at certain generating stations and damage to materials and supplies , both at our fossil fleet . all the costs were recognized in operation and maintenance expense , offset by $ 19 million of a pending future recovery of insurance proceeds . power estimates that it will incur additional future costs primarily relating to repairs to , and replacement of , equipment and property up to approximately $ 215 million . as of december 31 , 2012 , pse & g had incurred approximately $ 295 million of costs to restore service to pse & g 's distribution and transmission systems and $ 5 million to repair its infrastructure and return it to pre-storm conditions . of the costs incurred , approximately $ 40 million was recognized in operation and maintenance expense , $ 75 million was recorded as property , plant and equipment and $ 180 million was recorded as a regulatory asset because such costs were deferred as approved by the bpu under an order received in december 2012. pse & g recognized $ 6 million of insurance proceeds . we are working with our insurance carriers with regard to other losses and expenses due to the storm but no assurances can be given relative to the timing or amount of insurance recovery . for additional information on the impacts of superstorm sandy , see item 8. financial statements and supplementary data-note 13. commitments and contingent liabilities . there have also been significant regulatory and legislative developments during the year which may affect our operations and financial results in the future as new rules and regulations are developed . competitive wholesale power market design is of particular importance to our results . through litigation and the regulatory processes , we advocated for policies and rules in response to subsidized generation and procurement activities in new jersey in connection with the long-term capacity agreement pilot program ( lcapp ) , and in maryland through the maryland public service commission 's request for proposal . after a favorable stakeholder vote , pjm filed proposed modifications to the minimum offer price rule ( mopr ) with the ferc . in february 2013 , the ferc issued a deficiency letter to pjm seeking additional information regarding the proposed mopr changes . if the ferc approves the proposal , these modifications should significantly improve the mopr rules and appropriately reduce the ability for subsidized generation assets to artificially suppress wholesale market prices . litigation with respect to the new jersey lcapp and maryland 's efforts to subsidize new generation and challenges to the bpu 's implementation of lcapp continues . see item 1. business , federal regulation , ferc - capacity market issues for further information . we continued to monitor and advocate for the development and implementation of fair and reasonable rules by the u.s. environmental protection agency ( epa ) . the epa is proceeding to implement its regulatory initiatives but the outcome of judicial review remains uncertain . the epa 's 316 ( b ) rule on cooling water intake could adversely impact future nuclear and fossil operations and costs . however , we believe our generation business remains well-positioned for clean air act regulations , if and when they are implemented . for additional information on the potential impacts of the 316 ( b ) rule , see item 8. financial statements and supplementary data-note 13. commitments and contingent liabilities . another regulatory development in 2012 that could have a material impact on our business are ferc rules under order 1000 , which altered the right of first refusal previously held by incumbent utilities to build all transmission within their respective service territories . we are opposing these rules in litigation and have worked with pjm to develop implementing rules that mitigate the impact of order 1000. we can not predict the final outcome or impact on us ; however , specific implementation of order 1000 within our service territory may expose us to competition for certain types of transmission projects , while at the same time affording us opportunities to construct transmission outside of our service territory . see item 1. business , federal regulation , ferc -transmission regulation . we are making progress in addressing these challenges , but regulatory uncertainty remains a concern . in 2012 , our continued focus on operational excellence provided the foundation for our financial strength , in turn enabling us to invest in a disciplined way for growth , providing value for our customers , employees and shareholders and allowing us to best succeed in a sustained low electricity price environment . some specific highlights in the areas of operational excellence , financial strength and disciplined investment in 2012 are discussed in more detail below . operational excellence we seek to emphasize operational performance while developing opportunities in our competitive and regulated businesses . low commodity prices continue to stress margins , but the flexibility of our generating fleet has allowed us to take advantage of market opportunities as we remain diligent in managing costs . in 2012 , we constructed approximately $ 656m million of gross plant additions to our transmission assets currently in service , continued to achieve high nuclear capacity factors , which averaged 91.1 % for our nuclear fleet in 2012 , improved fossil plant summer output , realized high combined cycle gas turbine fleet capacity utilization factors , 44 optimized fleet-switching from coal to gas to improve dispatch economics , extended collective bargaining agreements with four of our labor unions for four years , implemented more efficient plant staffing , were awarded the 2011 national reliability excellence award for “ demonstrating sustained leadership , innovation and achievement in the area of electric reliability , `` representing the fifth time in eight years we received this recognition , and eleven straight story_separator_special_tag interest expense decreased $ 41 million due primarily to a decrease of $ 55 million resulting primarily from the maturity of $ 606 million of 7.75 % senior notes in early april 2011 and the early redemption of $ 600 million of 6.95 % senior notes in december 2011 , partially offset by increases of $ 12 million due to two $ 250 million senior notes issuances in september 2011 and $ 3 million in higher interest costs since interest capitalization ceased for our kearny and new haven projects on their june 1 , 2012 in-service date . income tax expense decreased $ 252 million in 2012 due primarily to lower pre-tax income . income ( loss ) from discontinued operations in 2011 , we sold our two 1,000 mw combined-cycle generating facilities in texas in separate transactions . in march 2011 , we completed the sale of one plant for proceeds of $ 352 million at an after-tax gain of $ 54 million . in july 2011 , we completed the sale of the second plant for proceeds of $ 335 million at an after-tax gain of $ 25 million . the results of operations for both 51 plants for 2011 and 2010 , including the gains in 2011 on the sales of the plants , are included in this category . see item 8. financial statements and supplementary data—note 4. discontinued operations and dispositions for additional information . year ended december 31 , 2011 as compared to 2010 operating revenues decreased $ 415 million due to gas supply revenues decreased $ 290 million due primarily to a net decrease of $ 283 million in sales under the bgss contract , substantially comprised of lower average gas prices on lower volumes of sales in 2011 due to warmer average temperatures during the fourth quarter of 2011 , a net decrease of $ 7 million due primarily to lower average gas prices partially offset by higher sales volumes to third party customers . generation revenues decreased $ 143 million due primarily to a net decrease of $ 305 million due primarily to lower average pricing and lower volumes of electricity sold under our bgs contracts as a result of customer migration , a decrease of $ 70 million due primarily to lower capacity payments from the various power pools resulting from lower market prices , and a decrease of $ 8 million due to lower operating reserve revenue in 2011. these were partially offset by an increase of $ 136 million from new wholesale load contracts in the pjm and ne regions commencing in january 2011 and april 2011 , respectively , net of lower average realized prices in the ne region , and higher net revenues of $ 108 million due primarily to mtm gains on economic hedging activity of $ 228 million , partially offset by lower realized prices in the pjm and ny power pools and lower volumes of generation sold in the pjm and ne power pools of $ 120 million . trading revenues increased $ 18 million due primarily to lower net losses in 2011 on certain electric energy supply contracts as well as the discontinuation of trading activities in the second quarter of 2011. operating expenses energy costs represent the cost of generation , which includes fuel purchases for generation as well as purchased energy in the market , and gas purchases to meet power 's obligation under its bgss contract with pse & g . energy costs decreased $ 328 million due to gas costs decreased $ 282 million , principally related to obligations under the bgss contract , reflecting lower average gas inventory costs coupled with lower sales volumes in 2011 due to warmer average temperatures during the fourth quarter of 2011. generation costs decreased by $ 46 million due primarily to $ 211 million of lower fuel costs , including $ 251 million of lower fossil fuel costs primarily reflecting the utilization of lower volumes of both coal and oil , favorable results from our coal optimization efforts , and lower natural gas prices , partially offset by higher mtm losses and higher nuclear fuel costs in 2011. the decrease was also attributable to $ 16 million of lower emission charges , including $ 10 million of lower impairment charges related to excess so 2 emission allowances . these decreases were partially offset by an increase of $ 153 million in higher energy purchases in 2011 in the pjm and ne power pools as the result of lower generation and the need to meet higher load contract demand in 2011 and $ 23 million of higher operating reserve obligations in the pjm region . operation and maintenance increased $ 56 million due primarily to a net increase of $ 47 million due largely to planned outage costs , including hot gas path inspection outage costs at our bec and linden facilities as well as higher outage costs at our bergen , and keystone facilities , partially offset by higher outage and repair costs at certain of our other fossil plants in 2010 , $ 20 million of costs incurred for the cancellation and renegotiation of a major contractual agreement for parts and services for our combined cycle bethlehem energy ( bec ) facility in new york and linden and bergen facilities in new jersey , and 52 a net increase of $ 3 million due to refurbishment projects at our salem nuclear facilities , partially offset by a decrease of $ 13 million due to a decrease in pension and opeb costs tempered by higher labor costs and incentive awards . depreciation and amortization increased $ 49 million due primarily to a $ 37 million increase due to completion of installation of back-end technology at the end of 2010 at our mercer and hudson generating facilities , and a $ 12 million increase due to higher depreciable asset bases at nuclear and fossil . other income and ( deductions ) the

liquidity and capital resources the following discussion of our liquidity and capital resources is on a consolidated basis , noting the uses and contributions , where material , of our three direct operating subsidiaries . financing methodology we expect our capital requirements to be met through internally generated cash flows and external financings , consisting of short-term debt for working capital needs and long-term debt for capital investments . pse & g 's sources of external liquidity include a $ 600 million multi-year syndicated credit facility . pse & g 's commercial paper program is the primary vehicle for meeting seasonal , intra-month and temporary working capital needs . pse & g does not engage in any intercompany borrowing or lending . pse & g maintains back-up facilities in an amount sufficient to cover 100 % of commercial paper outstanding . pse & g 's dividend payments to pseg are consistent with its capital structure objectives which have been established to maintain investment grade credit ratings . pse & g 's long-term financing plan is designed to replace maturities , fund a portion of its capital program and manage short-term debt balances . generally , pse & g uses either secured medium-term notes or first mortgage bonds to raise long-term capital . pseg , power , energy holdings and pseg services corporation participate in a corporate money pool , an aggregation of daily cash balances designed to efficiently manage their respective short-term liquidity needs . pseg 's sources of external liquidity include multi-year syndicated credit facilities totaling $ 1 billion . these facilities are available to back-stop pseg 's commercial paper program , issue letters of credit and for general corporate purposes . these facilities may also be used to provide support to pseg 's subsidiaries .


 Write a concise suspicious activity report of the following text delimited by triple backquotes. Return your response as a formal report which covers the key points highlighting the location,dates,entity names and account holder information in chronological order of the text.
     ```liquidity and capital resources the following discussion of our liquidity and capital resources is on a consolidated basis , noting the uses and contributions , where material , of our three direct operating subsidiaries . financing methodology we expect our capital requirements to be met through internally generated cash flows and external financings , consisting of short-term debt for working capital needs and long-term debt for capital investments . pse & g 's sources of external liquidity include a $ 600 million multi-year syndicated credit facility . pse & g 's commercial paper program is the primary vehicle for meeting seasonal , intra-month and temporary working capital needs . pse & g does not engage in any intercompany borrowing or lending . pse & g maintains back-up facilities in an amount sufficient to cover 100 % of commercial paper outstanding . pse & g 's dividend payments to pseg are consistent with its capital structure objectives which have been established to maintain investment grade credit ratings . pse & g 's long-term financing plan is designed to replace maturities , fund a portion of its capital program and manage short-term debt balances . generally , pse & g uses either secured medium-term notes or first mortgage bonds to raise long-term capital . pseg , power , energy holdings and pseg services corporation participate in a corporate money pool , an aggregation of daily cash balances designed to efficiently manage their respective short-term liquidity needs . pseg 's sources of external liquidity include multi-year syndicated credit facilities totaling $ 1 billion . these facilities are available to back-stop pseg 's commercial paper program , issue letters of credit and for general corporate purposes . these facilities may also be used to provide support to pseg 's subsidiaries .
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 Suspicious Activity Report : 43 as of december 31 , 2012 , power had incurred approximately $ 85 million in costs related to superstorm sandy , primarily comprised of repairs at certain generating stations and damage to materials and supplies , both at our fossil fleet . all the costs were recognized in operation and maintenance expense , offset by $ 19 million of a pending future recovery of insurance proceeds . power estimates that it will incur additional future costs primarily relating to repairs to , and replacement of , equipment and property up to approximately $ 215 million . as of december 31 , 2012 , pse & g had incurred approximately $ 295 million of costs to restore service to pse & g 's distribution and transmission systems and $ 5 million to repair its infrastructure and return it to pre-storm conditions . of the costs incurred , approximately $ 40 million was recognized in operation and maintenance expense , $ 75 million was recorded as property , plant and equipment and $ 180 million was recorded as a regulatory asset because such costs were deferred as approved by the bpu under an order received in december 2012. pse & g recognized $ 6 million of insurance proceeds . we are working with our insurance carriers with regard to other losses and expenses due to the storm but no assurances can be given relative to the timing or amount of insurance recovery . for additional information on the impacts of superstorm sandy , see item 8. financial statements and supplementary data-note 13. commitments and contingent liabilities . there have also been significant regulatory and legislative developments during the year which may affect our operations and financial results in the future as new rules and regulations are developed . competitive wholesale power market design is of particular importance to our results . through litigation and the regulatory processes , we advocated for policies and rules in response to subsidized generation and procurement activities in new jersey in connection with the long-term capacity agreement pilot program ( lcapp ) , and in maryland through the maryland public service commission 's request for proposal . after a favorable stakeholder vote , pjm filed proposed modifications to the minimum offer price rule ( mopr ) with the ferc . in february 2013 , the ferc issued a deficiency letter to pjm seeking additional information regarding the proposed mopr changes . if the ferc approves the proposal , these modifications should significantly improve the mopr rules and appropriately reduce the ability for subsidized generation assets to artificially suppress wholesale market prices . litigation with respect to the new jersey lcapp and maryland 's efforts to subsidize new generation and challenges to the bpu 's implementation of lcapp continues . see item 1. business , federal regulation , ferc - capacity market issues for further information . we continued to monitor and advocate for the development and implementation of fair and reasonable rules by the u.s. environmental protection agency ( epa ) . the epa is proceeding to implement its regulatory initiatives but the outcome of judicial review remains uncertain . the epa 's 316 ( b ) rule on cooling water intake could adversely impact future nuclear and fossil operations and costs . however , we believe our generation business remains well-positioned for clean air act regulations , if and when they are implemented . for additional information on the potential impacts of the 316 ( b ) rule , see item 8. financial statements and supplementary data-note 13. commitments and contingent liabilities . another regulatory development in 2012 that could have a material impact on our business are ferc rules under order 1000 , which altered the right of first refusal previously held by incumbent utilities to build all transmission within their respective service territories . we are opposing these rules in litigation and have worked with pjm to develop implementing rules that mitigate the impact of order 1000. we can not predict the final outcome or impact on us ; however , specific implementation of order 1000 within our service territory may expose us to competition for certain types of transmission projects , while at the same time affording us opportunities to construct transmission outside of our service territory . see item 1. business , federal regulation , ferc -transmission regulation . we are making progress in addressing these challenges , but regulatory uncertainty remains a concern . in 2012 , our continued focus on operational excellence provided the foundation for our financial strength , in turn enabling us to invest in a disciplined way for growth , providing value for our customers , employees and shareholders and allowing us to best succeed in a sustained low electricity price environment . some specific highlights in the areas of operational excellence , financial strength and disciplined investment in 2012 are discussed in more detail below . operational excellence we seek to emphasize operational performance while developing opportunities in our competitive and regulated businesses . low commodity prices continue to stress margins , but the flexibility of our generating fleet has allowed us to take advantage of market opportunities as we remain diligent in managing costs . in 2012 , we constructed approximately $ 656m million of gross plant additions to our transmission assets currently in service , continued to achieve high nuclear capacity factors , which averaged 91.1 % for our nuclear fleet in 2012 , improved fossil plant summer output , realized high combined cycle gas turbine fleet capacity utilization factors , 44 optimized fleet-switching from coal to gas to improve dispatch economics , extended collective bargaining agreements with four of our labor unions for four years , implemented more efficient plant staffing , were awarded the 2011 national reliability excellence award for “ demonstrating sustained leadership , innovation and achievement in the area of electric reliability , `` representing the fifth time in eight years we received this recognition , and eleven straight story_separator_special_tag interest expense decreased $ 41 million due primarily to a decrease of $ 55 million resulting primarily from the maturity of $ 606 million of 7.75 % senior notes in early april 2011 and the early redemption of $ 600 million of 6.95 % senior notes in december 2011 , partially offset by increases of $ 12 million due to two $ 250 million senior notes issuances in september 2011 and $ 3 million in higher interest costs since interest capitalization ceased for our kearny and new haven projects on their june 1 , 2012 in-service date . income tax expense decreased $ 252 million in 2012 due primarily to lower pre-tax income . income ( loss ) from discontinued operations in 2011 , we sold our two 1,000 mw combined-cycle generating facilities in texas in separate transactions . in march 2011 , we completed the sale of one plant for proceeds of $ 352 million at an after-tax gain of $ 54 million . in july 2011 , we completed the sale of the second plant for proceeds of $ 335 million at an after-tax gain of $ 25 million . the results of operations for both 51 plants for 2011 and 2010 , including the gains in 2011 on the sales of the plants , are included in this category . see item 8. financial statements and supplementary data—note 4. discontinued operations and dispositions for additional information . year ended december 31 , 2011 as compared to 2010 operating revenues decreased $ 415 million due to gas supply revenues decreased $ 290 million due primarily to a net decrease of $ 283 million in sales under the bgss contract , substantially comprised of lower average gas prices on lower volumes of sales in 2011 due to warmer average temperatures during the fourth quarter of 2011 , a net decrease of $ 7 million due primarily to lower average gas prices partially offset by higher sales volumes to third party customers . generation revenues decreased $ 143 million due primarily to a net decrease of $ 305 million due primarily to lower average pricing and lower volumes of electricity sold under our bgs contracts as a result of customer migration , a decrease of $ 70 million due primarily to lower capacity payments from the various power pools resulting from lower market prices , and a decrease of $ 8 million due to lower operating reserve revenue in 2011. these were partially offset by an increase of $ 136 million from new wholesale load contracts in the pjm and ne regions commencing in january 2011 and april 2011 , respectively , net of lower average realized prices in the ne region , and higher net revenues of $ 108 million due primarily to mtm gains on economic hedging activity of $ 228 million , partially offset by lower realized prices in the pjm and ny power pools and lower volumes of generation sold in the pjm and ne power pools of $ 120 million . trading revenues increased $ 18 million due primarily to lower net losses in 2011 on certain electric energy supply contracts as well as the discontinuation of trading activities in the second quarter of 2011. operating expenses energy costs represent the cost of generation , which includes fuel purchases for generation as well as purchased energy in the market , and gas purchases to meet power 's obligation under its bgss contract with pse & g . energy costs decreased $ 328 million due to gas costs decreased $ 282 million , principally related to obligations under the bgss contract , reflecting lower average gas inventory costs coupled with lower sales volumes in 2011 due to warmer average temperatures during the fourth quarter of 2011. generation costs decreased by $ 46 million due primarily to $ 211 million of lower fuel costs , including $ 251 million of lower fossil fuel costs primarily reflecting the utilization of lower volumes of both coal and oil , favorable results from our coal optimization efforts , and lower natural gas prices , partially offset by higher mtm losses and higher nuclear fuel costs in 2011. the decrease was also attributable to $ 16 million of lower emission charges , including $ 10 million of lower impairment charges related to excess so 2 emission allowances . these decreases were partially offset by an increase of $ 153 million in higher energy purchases in 2011 in the pjm and ne power pools as the result of lower generation and the need to meet higher load contract demand in 2011 and $ 23 million of higher operating reserve obligations in the pjm region . operation and maintenance increased $ 56 million due primarily to a net increase of $ 47 million due largely to planned outage costs , including hot gas path inspection outage costs at our bec and linden facilities as well as higher outage costs at our bergen , and keystone facilities , partially offset by higher outage and repair costs at certain of our other fossil plants in 2010 , $ 20 million of costs incurred for the cancellation and renegotiation of a major contractual agreement for parts and services for our combined cycle bethlehem energy ( bec ) facility in new york and linden and bergen facilities in new jersey , and 52 a net increase of $ 3 million due to refurbishment projects at our salem nuclear facilities , partially offset by a decrease of $ 13 million due to a decrease in pension and opeb costs tempered by higher labor costs and incentive awards . depreciation and amortization increased $ 49 million due primarily to a $ 37 million increase due to completion of installation of back-end technology at the end of 2010 at our mercer and hudson generating facilities , and a $ 12 million increase due to higher depreciable asset bases at nuclear and fossil . other income and ( deductions ) the

