Attachment

UTILITY COMMITTEE AGENDA FEBRUARY 11, 2013 - 5:00 P.M. CITY HALL COUNCIL CHAMBERS 15 LOOCKERMAN PLAZA DOVER, DELAWARE Public comments are welcomed on any item and will be permitted at appropriate times. When possible, please notify the City Clerk (736-7008 or e-mail at CityClerk@dover.de.us) should you wish to be recognized. AGENDA ADDITIONS/DELETIONS 1. Request for Alley Abandonment (Paper) - 235 (Case), 239 (McCabe-Cort), and 243 (Marami Partners) Bayard Avenue (Staff Recommends: (1) Abandonment of the Alley with Conveyance of Seven Feet (7’) to 235 (Case), 239 (McCabe-Cort), and 243 (Marami Partners) Bayard Avenue, in Conjunction with the Provision of a Public Utility Easement for Each Parcel and, (2) Adoption of a Resolution Setting a Public Hearing Regarding the Proposed Abandonment for March 11, 2013) 2. Quarterly Review of Utility Related Capital Investment Plan (CIP) (Electric and Water/Wastewater) (October, November, and December) (Committee Action is Not Required for this Item) 3. TEA/NAES Report (November) (Staff Recommends Acceptance of the Report) 4. Updates A. Green Energy Funding and Programming (Committee Action is Not Required for this Item) B. National Pollution Discharge Elimination System (NPDES) Municipal Separate Storm Sewer Systems (MS4) Permit (Committee Action is Not Required for this Item) C. Solar Park (Committee Action is Not Required for this Item) D. Calpine (Committee Action is Not Required for this Item) 5. Adjournment by 5:55 P.M. /tm S:\AGENDAS-MINUTES-PACKETS\Committee-Agendas\2013\02-11-2013 UTILITY.wpd THE AGENDA ITEMS AS LISTED MAY NOT BE CONSIDERED IN SEQUENCE. THIS AGENDA IS SUBJECT TO CHANGE TO INCLUDE THE ADDITION OR THE DELETION OF ITEMS, INCLUDING EXECUTIVE SESSIONS.

ACTION FORM PROCEEDING: Utility Committee AGENDA ITEM: DEPARTMENT OF ORIGIN: Public Works DATE SUBMITTED: 1/9/2013 PREPARED BY: Sharon J. Duca, P.E., Public Works Director / City Engineer SUBJECT: Request for Alley Abandonment (paper) – 235, 239 and 243 Bayard Avenue REFERENCE: N/A RELATED PROJECT: N/A APPROVALS: City Manager EXHIBITS: Attachment A – Map EXPENDITURE REQUIRED: $ N/A AMOUNT BUDGETED: $ N/A FUNDING SOURCE (Dept./Page in CIP & Budget): N/A TIMETABLE: The references alley shall be abandoned upon approval by City Council. RECOMMENDED ACTIONS: The following actions are recommended should the Committee be in favor: (1) Abandonment of the subject alley with conveyance of seven feet (7’) of said alley to 235, 239 and 243 Bayard Avenue, currently owned by Ms. Joan Case, Ms. Claudia McCabe-Cort and Marami Partners, respectively, in conjunction with the provision of a public utility easement for each parcel. (2) Adoption of a resolution by Council setting a public hearing regarding the proposed abandonment for March 11, 2013. BACKGROUND AND ANALYSIS The City Clerk’s Office received a request from Ms. Joan Case for the abandonment of an alley located behind her property on Bayard Avenue. A letter was subsequently sent to all adjacent property owners to determine their interest in participating in the abandonment and having a portion of the alley conveyed to them. Two (2) additional property owners expressed interest in participating. The names of interested property owners and the addresses of their affected properties are as follows: Ms. Joan Case 235 Bayard Avenue Ms. Claudia McCabe-Cort 239 Bayard Avenue Marami Partners 243 Bayard Avenue Public Works staff has confirmed that the alley is unimproved. Electric utility infrastructure and storm drainage infrastructure are located within the alley; therefore, public utility easements will be required. The alley is fourteen feet (14’) wide. Half of the alley, or seven feet (7’), would be conveyed to the requesting parties. The Department of Public Works has no objection to the abandonment of the subject alley. The Department recommends conveyance of seven feet (7’) of said alley to only 235, 239 and 243 Bayard Avenue and in conjunction with the provision of a public utility easement for each parcel. Conveyance shall be in proportions complimentary to the existing lot widths of these parcels.

Alley Adjacent to 235, 239 & 245 Bayard Avenue Proposed Alley Abandonment !Ò§ !Ò§ Ò 505 516 ! 554 § t × nS 514 a e rm 512 ck Ò§ !Ò! L oo × § E 508 !Ò§ Ò ! § . ! !Ò§ 506 §Ò ! Ò ! § 222 221 . ! × 456 Ò ! § !Ò§Ò§ ! 225 !Ò§ ya !Ò§ 216 Ba 229 rd e !Ò§ Ò ! § Av 235 222 !Ò§ !Ò§ × 239 Ò ! § 232 Ò ! § 236 !Ò§ 243 Ò !Ò§ 391 ! § Ò ! § !Ò§ 240 . ! !Ò§ Ò! 244 × § !Ò§ 413 250 340 Ò !Ò§ 258 ! § 0 50 100 200 Feet Legend Hydrants Ò × ! § Ò ! ¯ § Overhead Electric Pole Underground Electric Lines Date Printed: February 1, 2013 Overhead Electric Lines Water Main File: m:\gis_data\projects/tech_mxds Hydrant Line \st_abandonment_map_235_bayard_ave . Manholes ! Department: Public Works GIS Sewer Line City of Dover, Delaware Bayard Avenue Alley Dover Parcels

1 of 5 City of Dover Capital Investment Plan Project Tracking Report December 31, 2012 Points to Remember - * Original Project Budget = Original Total Project Budget initially included in approved annual budget. * Latest Project Budget = Revised Total Project Budget included in most recent approved annual budget or one of the following: bond resolution, revolving fund loan agreement, Council approved budget amendment, or City Manager approved amendment as per the Budget Amendment Procedure. * Current Fiscal Year - Revised Fiscal Year Budget = Current Year approved project budgets plus carry forward balances of unspent budgets in the prior fiscal year. Project Carry Forward balances will be submitted to City Council for amendment in January 2010. Can also be amended with City Manager approval per the Budget Amendment Procedure. * Water Quality, Inflow/Infiltration, Distribution Upgrades and New Development projects are budgeted as a blanket project and once individual projects are identified and estimated they are created using an allocation of the overall budgeted amount. * Status and Comments provided by City Manager. * For Finance purposes projects are considered completed when placed in service and all charges have been processed. Community Water & Total Current Year Budget Funding Sources General Transportation Wastewater Electric CIP Budget Balance $ 62,000 $ 171,400 $ 4,508,500 $ 534,700 $ 5,276,600 Restricted MSA (non Public Safety) 132,200 - - - 132,200 Library Funding - FY11 Budget Balance (95,500) - - - (95,500) Federal and/or State Grants 1,746,000 - - - 1,746,000 Transfer from Library Foundation 71,000 - - - 71,000 Friends of the Library Donation 102,400 - - - 102,400 Kent County Library Contribution 250,000 - - - 250,000 Sale of Assets - Library 1,200,000 - - - 1,200,000 Debt Financing - Green Energy Components 648,500 - - - 648,500 Community Transportation Fund - FY11 Balances - 1,630,050 - - 1,630,050 Debt Financing 2,000,000 - 4,000,000 - 6,000,000 Other State/Federal Grants 324,700 - - - 324,700 Police Grants 33,800 - - - 33,800 Transfer from Capital Reserves - - - 550,000 550,000 Impact Fee Reserves - - 550,000 - 550,000 State Community Transportation Funds - 700,000 - - 700,000 Transfer Loan Proceeds to CT Fund - Street Program - 1,606,700 - - 1,606,700 Transfer from Operating Funds 613,400 - 2,900,000 3,500,000 7,013,400 Transfer from Future Capacity Reserve 2,000,000 - - - 2,000,000 Interest Income - - 25,000 40,700 65,700 Total Funding Sources (Unaudited) $ 9,088,500 $ 4,108,150 $ 11,983,500 $ 4,625,400 $ 29,805,550

City of Dover General Fund - Major CIP Projects 2 of 5 December, 2012 TOTAL PROJECT - PAST, CURRENT & FUTURE BUDGETS CURRENT FISCAL YEAR Original Latest Project Project Current Revised Fiscal Project Project Project To Date Budget % Budget Fiscal Year Fiscal Year YTD % Budget Code Type Description Budget Budget Expenses Balance Spent Budget Budget Expenses Spent Status Comments FY2009 LB0901 M/G/L New Library Project $ 18,200,000 $ 20,469,080 $ 19,390,564 $ 1,078,516 94.7% $ 2,535,000 $ 4,089,100 $ 3,101,784 75.9% In Process Overall project 80% Complete on 7/31/12 ST1203 Dump Truck Refurbishment 30,000 24,000 28,687 (4,687) 119.5% - 12,000 16,666 138.9% In Process FY12 MSA - Capital non-safety - 132,200 - 132,200 200.0% - 132,200 - 0.0% Restricted MSA Funding Totals - FY09 $ 18,230,000 $ 20,625,280 $ 19,419,251 $ 1,206,029 94.2% $ 2,535,000 $ 4,233,300 $ 3,118,450 73.7% FY2013 --- Vehicles & Equipment $ 399,900 $ 399,900 $ 187,702 $ 212,198 46.9% $ 399,900 $ 399,900 $ 187,702 46.9% --- Annual Fire Truck Payments 238,500 238,500 96,275 142,225 40.4% 238,500 238,500 96,275 40.4% Mayor Security Cameras 33,000 33,000 - 33,000 0.0% 33,000 33,000 - 0.0% FC1302 B/L City Hall Fire Suppression 288,000 288,000 - 288,000 0.0% 288,000 288,000 - 0.0% Financed by PNC Loan - FY12 FC1303 G City Hall Emergency Generator 93,000 93,000 - 93,000 0.0% 93,000 93,000 - 0.0% DEMA Grant funded IT1301 G Server & Backup Solution 57,000 57,000 - 57,000 0.0% 57,000 107,000 - 0.0% $15K is DEMA grant funded PR1301 Dover Park- Roof Replacement 30,000 30,000 - 30,000 0.0% 30,000 30,000 - 0.0% ST1303 B/L Salt Storage Facility-Schutte Park 50,000 50,000 - 50,000 0.0% 50,000 50,000 - 0.0% Financed by PNC Loan - FY12 ST1304 B/L Garrison Farm Improvements 1,924,000 1,924,000 4,043 1,919,957 0.2% 1,924,000 1,950,000 4,043 0.2% Financing to be determined PD1301 G Police Elec Breaker Replacement 33,800 33,800 - 33,800 0.0% 33,800 33,800 - 0.0% Police Grant funded PD1302 B/L Police Micro Seal Parking Lots 25,300 25,300 - 25,300 0.0% 25,300 25,300 - 0.0% Financed by PNC Loan - FY12 Totals - FY12 $ 2,501,100 $ 2,501,100 $ 4,043 $ 2,497,057 0.2% $ 3,172,500 $ 3,248,500 $ 288,020 8.9% Debt issuance cost - PNC/Other 56,000 56,000 - 56,000 0.0% 56,000 - - 0.0% Transfer to CT Fund - Streets 1,606,700 1,606,700 - 1,606,700 0.0% 1,606,700 1,606,700 - 0.0% PNC Loan for FY12/FY13 Street Program Grand Totals $ 22,393,800 $ 24,789,080 $ 19,423,294 $ 5,365,786 78.4% $ 7,370,200 $ 9,088,500 $ 3,406,470 37.5% 37.5% Legend M = Multi-year project - a project with a specific schedule to occur over multiple years. R = Recurring project - a project that begins and ends each fiscal year and is re-budgeted to start over each fiscal year. G = Grant funded project B/L = To be financed through bonds or commercial loan; Projects will be completed through CT Fund, therefore the loan proceeds will be transferred from Capital Fund into the Community Transportation Fund;

City of Dover Community Transportation & General Fund Street Funds - Major CIP Projects 3 of 5 December, 2012 Hide TOTAL PROJECT - PAST, CURRENT & FUTURE BUDGETS CURRENT FISCAL YEAR Original Latest Project Project Current Revised Fiscal Project Project Project To Date Budget % Budget Fiscal Year Fiscal Year YTD % Budget Code Type Description Budget Budget Expenses Balance Spent Budget Budget Expenses Spent Status Comments FY 2002 CT0212 North Street sidewalk $ 80,400 $ 80,400 $ - $ 80,400 0.0% $ - $ 80,400 $ - 0.0% Waiting on DDP improvements Totals $ 80,400 $ 80,400 $ - $ 80,400 0.0% $ - $ 80,400 $ - 0.0% FY 2009 CT0555 Little League Park paving $ 11,600 $ 11,600 $ - $ 11,600 0.0% $ - $ 11,600 $ - 0.0% Re-program for signage Totals $ 11,600 $ 11,600 $ - $ 11,600 0.0% $ - $ 11,600 $ - 0.0% FY 2007 CT0708 E. Water Street Brick $ 65,000 $ 65,000 $ - $ 65,000 0.0% $ - $ 65,000 $ - 0.0% Specialty contract needed Totals $ 65,000 $ 65,000 $ - $ 65,000 0.0% $ - $ 65,000 $ - 0.0% FY 2009 CT0977 M Schutte Parking Lot $ 21,950 $ 21,950 $ - $ 21,950 0.0% $ - $ 21,950 $ - 0.0% Deferred Totals $ 21,950 $ 21,950 $ - $ 21,950 0.0% $ - $ 21,950 $ - 0.0% FY2012 CT1201 M North Street Roundabout $ - $ 500,000 $ - $ 500,000 0.0% $ - $ 500,000 $ - 0.0% 35% Site work initiated CT1212 Stoney Creek Lighting - 40,000 8,696 31,304 21.7% - 40,000 8,696 21.7% TE0601 M Lincoln Park Center 900,000 1,423,500 518,069 905,431 36.4% - 911,100 5,741 0.6% Started Totals $ 900,000 $ 1,963,500 $ 526,765 $ 1,436,735 26.8% $ - $ 1,451,100 $ 14,437 0.0% FY2013 CTxxxx Unapplied CT Projects (placeholder) $ 700,000 $ 378,415 $ - $ 378,415 0.0% $ 700,000 $ 378,415 $ - 0.0% Future CT Agreements CT1295 Hazel Road - 61,056 - 61,056 0.0% - 61,056 - 0.0% CT1316 Robbins Hose Station 2 - 111,925 - 111,925 0.0% - 111,925 - 0.0% CT1317 Wesley College Phase I - 148,604 - 148,604 0.0% - 148,604 - 0.0% ST1301 FY13 Concrete Program 60,000 60,000 6,148 53,852 10.2% 60,000 60,000 6,148 10.2% Financed by PNC Loan - FY12 STxxxx Street & Alley Program 300,000 56,400 56,400 0.0% - 56,400 - 0.0% ST1305 White Oak Tax Ditch - 12,600 - 12,600 0.0% 12,600 - 0.0% MR1301 Security Cameras - 102,400 - 102,400 0.0% - 102,400 - 0.0% General Fund Appropriations ST1302 FY12/FY13 Street & Alley Program 1,546,700 1,546,700 - 1,546,700 0.0% 1,546,700 1,546,700 - 0.0% Financed by PNC Loan - FY12 $ 2,606,700 $ 2,478,100 $ 6,148 $ 2,471,952 0.2% $ 2,306,700 $ 2,478,100 $ 6,148 0.3% Grand Totals $ 3,593,650 $ 4,528,550 $ 532,913 $ 3,995,637 11.8% $ 2,306,700 $ 4,108,150 $ 20,585 0.9% Legend M = Multi-year project - a project with a specific schedule to occur over multiple years. R = Recurring project - a project that begins and ends each fiscal year and is re-budgeted to start over each fiscal year. C = Project funded by combination of CT Funds and General Fund B/L = To be financed through bonds or commercial loan; Projects will be completed through CT Fund, therefore the loan proceeds will be transferred from Capital Fund into the Community Transportation Fund

City of Dover Water/Wastewater Improvement & Extension Fund - Major CIP Projects 4 of 5 December, 2012 TOTAL PROJECT - PAST, CURRENT & FUTURE BUDGETS CURRENT FISCAL YEAR Original Latest Project Project % Approved Revised Fiscal % Status / Project Project Project To Date Budget Budget Fiscal Year Fiscal Year YTD Budget % Code Type Description Budget Budget Expenses Balance Spent Budget Budget Expenses Spent Complete Comments FY 2008 WD0804 M 1.0 MG Elevated Water Storage $ 4,196,600 $ 2,590,000 $ 24,540 $ 2,565,460 0.9% $ 2,000,000 $ 2,166,000 $ 11,615 0.5% Started Staff reviewing agreement docs WD0805 M Piney Point Well 398,800 665,000 47,840 617,160 7.2% 450,000 505,600 41,112 8.1% Started Staff reviewing RFP Totals - FY08 $ 4,595,400 $ 3,255,000 $ 72,381 $ 3,182,619 2.2% $ 2,450,000 $ 2,671,600 $ 52,728 2.0% FY2009 WQ0907 SL/C Rt. 13 Water Main 1,023,700 2,214,600 2,173,195 41,405 98.1% - 192,600 114,868 59.6% 100.0% Complete; Awaiting final charges FY2010 WW1007 M/SL Fox Hall Pump Station 427,900 358,900 273,226 85,674 76.1% - 144,800 59,139 40.8% 98.0% Final punch list items outstanding WW1010 I Tar Ditch Interceptor Upgrade 518,230 495,400 5,143 490,257 1.0% - 490,300 0.0% Started Easement request sent to residents Totals - FY10 $ 427,900 $ 358,900 $ 273,226 $ 85,674 76.1% $ - $ 635,100 $ 59,139 9.3% FY2011 WW1104 SL Lepore Road P/S Replacement 350,000 402,000 28,650 373,350 7.1% - 384,200 10,800 2.8% Started Contractor ordered Station Totals - FY11 $ 350,000 $ 402,000 $ 28,650 $ 373,350 7.1% $ - $ 384,200 $ 10,800 2.8% FY2012 WD1201 Pay-As-You-Go Water Station 30,200 30,200 - 30,200 0.0% - 30,200 - 0.0% Started Specs being developed WQ1202 WQI - New Street - 113,960 26,600 87,360 23.3% - 87,400 - 0.0% Started Project on hold - Design complete WQ1203 WQI - Silver Lake - 279,840 238,576 41,264 85.3% - 87,752 49,578 56.5% 100.0% Complete; Awaiting final charges WW1201 M/SL Inflow/Infiltration Removal (1) 1,000,000 971,900 55,075 916,825 5.7% - - - 0.0% See FY13 I & I Program; $916.800 WW1202 M SCADA Equipment Upgrade 84,900 84,900 76,389 8,511 90.0% 29,300 29,300 - 0.0% Started Awaiting delivery of materials WW1204 M Baltray Pump Station Replacement 125,000 125,000 20,874 104,126 16.7% 100,000 100,000 293 0.3% Started Project on hold - Bid specs ready WW1205 M Dover Brook Gardens Pump Station 65,000 65,000 12,194 52,806 18.8% 50,000 50,000 2,342 4.7% Started Project on hold - Bid specs ready WW1206 M Brandywine Pump Station Rplcmnt 402,000 402,000 33,875 368,125 8.4% 350,000 350,000 293 0.1% Started Project on hold - Bid specs ready WW1207 M McKee Pump Station Comm Rplcmt 55,000 55,000 7,724 47,276 14.0% 45,000 45,000 293 0.7% Started Project on hold - Bid specs ready Totals - FY12 $ 1,762,100 $ 2,127,800 $ 471,306 $ 1,656,494 88.8% $ 574,300 $ 779,652 $ 52,798 6.8% FY2013 --- Vehicles & Equipment $ 524,500 $ 524,500 $ - $ 524,500 0.0% $ 524,500 $ 527,548 $ - 0.0% Started All ordered or bid WW1301 M Hazlettville Road Interceptor 770,000 770,000 - 770,000 0.0% 30,000 30,000 - 0.0% Not started Project on hold WW1302 M Lakeview Drive PS Replacement 502,000 502,000 23,048.00 478,952 4.6% 52,000 52,000 23,048 44.3% Not started Project on hold WW1303 M Westover Pump Station 768,800 768,800 - 768,800 0.0% 65,000 65,000 - 0.0% Not started Project on hold WW1304 M Garrison Farm Improvements 1,828,000 1,828,000 670.90 1,827,329 0.0% 1,828,000 1,828,000 671 0.0% Started Pending Council approval 9/24 WD1302 M Garrison Farm Storage Tank 1,828,000 1,828,000 - 1,828,000 0.0% 1,828,000 1,828,000 - 0.0% Started Pending Council approval 9/24 WD1304 Future Columbia Well Design 55,000 55,000 - 55,000 0.0% 55,000 55,000 - 0.0% Not started Project on hold WD1301 R Wellhead Redevelopment 70,000 70,000 67,675 2,325 96.7% 70,000 70,000 67,675 0.0% 15.0% Contractor finishing Well 10 & 14 WQ1301 North Street WMR 45,000 45,000 47,691.41 (2,691) 106.0% - 45,000 47,691 0.0% N/A Water Quality Improvements 479,000 479,000 - 479,000 0.0% 479,000 479,000 - 0.0% Locations to be determined N/A I & I Improvements (1) 1,000,000 (14,500) - (14,500) 0.0% 1,000,000 902,300 - 0.0% Locations to be determined II1301 New/Reed Street - 330,000 310,493 - 330,000 310,493 0.0% 65.0% Contractor finishing New Street II1302 Fox Hall - 142,000 77,384 - 142,000 77,384 54.5% Scheduled II1303 Morris Estates - 276,000 190,733 - 276,000 190,733 69.1% Scheduled II1304 Wesley College - 10,000 7,200 - 10,000 7,200 72.0% Scheduled II1305 NRG sanitary sewer upgrade - 175,000 69 - 175,000 69 0.0% Not started Bids due 10/4/12 II1306 I & I Design - 40,000 18,524 - 40,000 18,524 46.3% In progress Staff reviewing consultant report II1307 Mifflin Road Sewer Rehab 3,500 3,500 - 3,500 3,500 II1308 Dunkin Donuts SSR - 38,000 - - 38,000 - WD1306 R Emergency Generators 80,000 80,000 - 80,000 0.0% 80,000 80,000 - 0.0% 85.0% Start on bid docs 10/1/12 $ 7,950,300 $ 7,950,300 $ 746,987 $ 6,796,715 0.0% $ 6,011,500 $ 6,976,348 $ 746,987 10.7% N/A Debt issuance cost-Garrison Farm 344,000 344,000 - 344,000 0.0% 344,000 344,000 - 0.0% Grand Totals $ 16,453,400 $ 16,652,600 $ 3,765,745 $ 12,480,257 22.6% $ 9,379,800 $ 11,983,500 $ 1,037,320 8.7% Legend (1) Transferred remaining project balance from FY12 to the FY13 I & I Project $916,800 M = Multi-year project - a project with a specific schedule to occur over multiple years. Adjusted Project Budget for FY13 will be $1,916,800 for I & I; Locations to be determined; R = Recurring project - a project that begins and ends each fiscal year and is re-budgeted to start over each fiscal year. SL = State Loan Project - construction phase is financed I = Impact Fee (partially) financed project

City of Dover 5 of 5 Electric Improvement & Extension Fund - Major CIP Projects December, 2012 TOTAL PROJECT - PAST, CURRENT & FUTURE BUDGETS CURRENT FISCAL YEAR Original Latest Project Project % Current Revised Fiscal % Project Project Project To Date Budget Budget Fiscal Year Fiscal Year YTD Budget Code Type Description Budget Budget Expenses Balance Spent Budget Budget Expenses Spent Status Comments FY2012 EE1205 M Frazier Substation Upgrade $ 765,200 $ 765,200 $ 391,175 $ 374,025 51.1% $ 610,200 $ 611,800 $ 237,816 38.9% In process Materials ordered EG1202 M Unit 3 Boiler Systems 390,000 250,000 104,758 145,242 41.9% 129,000 167,300 22,106 13.2% In process Will complete Spring outage EG1212 M Unit 3 Turbine Inspection/Repair 1,494,000 1,494,000 403,190 1,090,810 27.0% 115,000 115,000 6,367 5.5% In process Will complete Spring outage EG1214 M Industrial WW Discharge System 272,000 272,000 36,845 235,155 13.5% - 242,000 6,500 2.7% In process EU1202 M Persimmon Tree Lane Feeder Rplcmt 113,500 113,500 116,191 (2,691) 102.4% - 8,500 12,642 148.7% In process EG1204 Unit 3DCS Comp & Software - - 3,075 (3,075) 0.0% - - 3,075 0.0% Complete Total $ 3,034,700 $ 2,894,700 $ 1,052,159 $ 1,842,541 36.3% $ 854,200 $ 1,144,600 $ 288,506 25.2% FY2013 N/A R Vehicles & Equipment $ 146,000 $ 146,000 $ 22,118 $ 123,882 15.1% $ 146,000 $ 146,000 $ 22,118 15.1% All vehicles received N/A R FY13 New Dvlpmnts - UG Transformers 50,000 68,800 2,394 66,406 3.5% 50,000 68,800 2,394 3.5% Over Budget; Revenue offset EE1313 R FY13 New Dvlpmnts - UG Conductors 350,000 (26,300) 6,266 (32,566) -23.8% 350,000 (26,300) 6,266 -23.8% EE1313 R FY13 New Dvlpmnts - 1 Phase Meters 50,000 25,340 353 24,987 1.4% 50,000 25,340 353 1.4% EE1301 Willow Tree Park - 9,800 13,077 (3,277) 133.4% - 9,800 13,077 133.4% EE1302 Bayard Plaza - 39,400 31,514 7,886 80.0% - 39,400 31,514 80.0% EE1303 Frazier Sub Upgrade - - 3,500 (3,500) 0.0% - - 3,500 0.0% EE1310 YMCA - 22,000 20,916 1,084 95.1% - 22,000 20,916 95.1% EE1311 Super 8 Motel - 6,200 5,802 398 93.6% - 6,200 5,802 93.6% EE1315 State Street Plaza - 8,700 1,408 7,292 16.2% - 8,700 1,408 16.2% EE1317 The Grand Apartments - 79,560 77,378 2,182 97.3% - 79,560 77,378 97.3% EE1318 M & L Ventures Warehouses - 28,800 29,984 (1,184) 104.1% - 28,800 29,984 104.1% EE1319 Proctor & Gamble - 30,000 19,225 10,775 64.1% - 30,000 19,225 64.1% EE1320 Generals Green Lights - 7,200 - 7,200 0.0% - 7,200 - 0.0% EE1322 Grottos Pizza - 45,400 3,124 42,276 6.9% - 45,400 3,124 6.9% EE1323 Dover High Lighting - 264,200 224,679 39,521 85.0% - 264,200 224,679 85.0% EE1324 Bayhealth Fiber Wood - 50,000 40,657 9,343 81.3% - 50,000 40,657 81.3% EE1325 Redner's Grocery Store - 16,600 - 16,600 0.0% - 16,600 - 0.0% EE1327 George & Lynch Asphalt - 25,000 - 25,000 0.0% - 25,000 - 0.0% EE1328 Fiber Blue Hen Project - 49,300 - 49,300 0.0% - 49,300 - 0.0% EE1304 R FY13 Lighting Project & Rehab 100,000 100,000 - 100,000 0.0% 100,000 100,000 - 0.0% Route 13 LED Lighting EE1309 R Distribution Capacitors 125,000 125,000 103,493 21,507 82.8% 125,000 125,000 103,493 82.8% EE1307 Division Sub Fence 70,000 55,000 39,345 15,655 71.5% 70,000 55,000 39,345 71.5% EE1308 M Horsepond Substation Upgrade 761,800 761,800 - 761,800 0.0% 170,000 170,000 - 0.0% EE1305 M FY13 69kv Switch Rplmnt Program 135,000 135,000 - 135,000 0.0% 55,000 70,000 - 0.0% EE1306 R Trans Line Maint Program 75,000 75,000 - 75,000 0.0% 75,000 75,000 - 0.0% EE1312 M General Scott Switchgear 1,155,000 1,150,000 - 1,150,000 0.0% 50,000 50,000 - 0.0% N/A R FY13 Distribution Upgrades 400,000 12,000 - 12,000 0.0% 400,000 12,000 - 0.0% EE1314 Capitol Park Upgrade - 308,000 761 307,239 0.2% - 308,000 761 0.2% EE1321 Pleasanton Acres - 80,000 - 80,000 0.0% - 80,000 32,876 41.1% N/A R FY13 Distribution Feeder Replacements 277,500 213,500 - 213,500 0.0% 277,500 213,500 - 0.0% EE1316 Wyoming Avenue Feeder Replacement - 64,000 - 64,000 0.0% - 64,000 31,662 49.5% EG1301 Units 1 Repair - Gasket leak - 65,000 88,086 (23,086) 135.5% - 65,000 88,086 135.5% New Project; Not budgeted EG1304 R Units 1 & 2 Component Repairs 52,000 52,000 14,564 37,436 28.0% 52,000 52,000 14,564 28.0% EG1305 R Units 1 & 2 Cooling Tower Life Ext. 37,300 37,300 - 37,300 0.0% 37,300 37,300 - 0.0% EG1306 Turbine Level Window Modifications 85,000 85,000 - 85,000 0.0% 85,000 85,000 - 0.0% EG1307 Unit 3 Air Heater Expansion Joint 80,000 80,000 43,629 36,371 54.5% 80,000 80,000 43,629 54.5% EG1309 Unit 3 Stack Repairs 27,000 27,000 - 27,000 0.0% 27,000 27,000 - 0.0% EG1310 Units 1 & 2 Stack Repairs 75,000 75,000 - 75,000 0.0% 75,000 75,000 - 0.0% EG1311 Van Sant Capacity Increase 550,000 550,000 - 550,000 0.0% 550,000 550,000 - 0.0% EG1312 Unit 3 Generator Repairs 236,000 236,000 794 235,206 0.3% 236,000 236,000 794 0.3% EG1313 R Unit 3 Aux Sys Components 55,000 55,000 20,072 34,928 36.5% 55,000 55,000 20,072 36.5% $ 4,892,600 $ 5,237,600 $ 793,068 $ 4,389,532 15.1% $ 3,115,800 $ 3,480,800 $ 877,678 25.2% Grand Totals $ 7,927,300 $ 8,132,300 $ 1,845,227 $ 6,232,073 41.6% $ 3,970,000 $ 4,625,400 $ 1,166,184 25.2% Legend M = Multi-year project - a project with a specific schedule to occur over multiple years. B = Bonded Project R = Recurring project - a project that begins and ends each fiscal year and is re-budgeted to start over each fiscal year. S = State fully or partially reimbursed project

The Energy Authority, Inc. Monthly Management Committee Update – November 2012 December 20, 2012 Prepared by: Jamie Mahne Vice President, Client Services 904.360.1374 jmahne@teainc.org

TABLE OF CONTENTS I. Executive Summary 1 II. Budget Report 12 III. Operations Management 15 IV. Appendix 29 i

I. Executive Summary A. Power Supply Summary: Overall Power Supply costs were $106,355 under budget due to lower than budgeted cost of hedged energy purchases. Dover’s budgeted cost for all power supply (capacity AND energy) was $94.72/MWh. The actual cost of all power supply (capacity AND energy) was $87.28/MWh. The cost of energy alone was $58.04/MWh, versus a budgeted energy cost of $68.70. Dover’s hedge purchases totaled 44,695MWh, which was 83% of the projected load and 79% of the actual load. Dover’s power purchases from hedge transactions totaled $2,769,375. Purchases from PJM (energy and fees) totaled $1,112,344, with DA Energy purchases totaling $625,407 and Balancing Spot Market Energy totaling a credit of $172,451. Dover’s total load was 56,881 MWh versus a forecasted load of 53,333 MWh. Dover’s planned energy purchase from the SunPark solar installation was 793 MWh. Dover’s actual energy purchase from the SunPark installation was 889 MWh. 1

Supply Source Summary: Supply Variance: Budget Actual Variance Gross Load 53,533 56,881 (3,348) Wholesale Load 52,740 55,992 (3,252) Hedged Volume (MWh) 44,695 44,695 - Unhedged Volume (MWh) 8,045 11,297 (3,252) Dover SunPark Volume (MWh) 793 889 (96) Renewable Energy Credits Volume 119 153 (34) Hedged Cost ($/MWh) $ 65 $ 62 0 Unhedged Energy Cost ($/MWh) $ 90 $ 40 $ 50 Solar Energy Cost ($/MWh) $ 83 $ 86 $ (3) Energy Costs ($/MWh) $68.70 $58.04 $10.66 All-in Costs - Energy, Capacity and RECs ($/MWh) $94.72 $87.28 $7.44 2

B. Generation Summary: Dover generated only 24 MWh (for test power) in the month. Net generation revenue was $696,065 vs. a budget of $667,592. This delta was mainly due to lower than budgeted O&M costs. 3

Generation Breakdown: City of Dover's Wholesale Generation Net Generation Mwh 24.85 All In Generation Margin PJM Bill Energy $ 1,315.23 PJM Capacity $ 1,167,075.00 Black Start, Reactive Credit, DASR & EFORp $ 36,373.16 Gas Purchases $ - Oil Purchases $ - Transport / Cash Out $ (1,854.42) Gross Margin $ 1,202,908.97 Production Margin Generation Production Revenues (PJM) $ 1,315.23 Gas Purchases $ - Oil Purchases $ - Transport / Cash Out $ (1,854.42) Gross Production Margin $ (539.19) $/Mwh All In Generation Margin $ 48,406.80 $/Mwh Generation Production Margin $ (21.70) 4

Fuel Purchases: All of Dover’s fuel purchases were obtained in the imbalance market (below). Transportation and Imbalance: Eastern Shore Transport and Imbalance Charges Imbalance/dth Imbalance/dth Cost/dth Total Cost 1168 $3.91 ($4,566.88) ($4,566.88) Transport Volume/dth $/dth Total Cost Firm/IT 1,168 $0.056300 ($65.76) 1,168 $0.427800 ($499.67) 0 $0.000000 $0.00 ($565.43) Credit September 2012 $3,277.89 Net ($1,854.42) 5

C. Emissions Summary: Emissions Allowance Summary through November 30, 2012 CAIR EMISSION ALLOWANCE SUMMARY SO2 NOx Allowances1 Date Action Allowances Seasonal Annual 1/1/09 2008 Carryover 3,240 0 0 1/1/09 2009 Allocation 2,723 53 80 2/1/10 2010 Allocation 2,039 50 78 1/1/11 2011 Allocation 1,988 49 78 4/1/11 2011 Reallocation 2 4 1/11/12 2012 Allocation 1,988 51 80 9/29/09 SO2 Sales (1,500) 11/12/09 NOx Ann. Sales (45) 11/13/09 SO2 Sales (1,410) 11/20/09 NOx Seas. Sales (25) 12/31/09 2009 Emissions2 (1) (6) (13) 12/31/10 2010 Emissions 0 (54) (54) 10/31/10 EPA Linearity Testing Req. (68) (68) 2011 2010 Deficit NOx Purchases 53 22 Aug 2011 Revised 2010 ECMPS data 30 30 Nov 2011 NOx Seas. Sales (DEMEC) (1) 12/31/11 2011 Emissions2 (1) (32) (36) 11/30/12 2012 Emissions2 (1) (37) (37) Nov 2012 NOx Seas. Sales (DEMEC) (2) TOTAL ALLOWANCES 9,065 63 118 On August 21, 2012, the U.S. District Court of Appeals (DCA) in Washington vacated EPA’s “Transport Rule” (aka Cross State Air Pollution Rule or CSAPR) which would have become effect on January 1, 2012. Additionally, DCA said EPA must continue administering the Clean Air Interstate Rule (CAIR), CSAPR’s predecessor, pending the issuance of a valid replacement rule. EPA submitted a petition for an en banc rehearing to the DCA on October 5, 2012 and is awaiting a ruling on the petition. Market liquidity for CAIR allowances continues to be low, with few transactions occurring. The following table shows estimated values as of November 30, 2012, based on broker bids & offers: 1 Per CAIR, starting in 2009, NOx emissions are governed by a seasonal and annual program. 2 Under CAIR, pre-CAIR SO2 allowances are retired at a rate of 2 allowances for each ton emitted. It is assumed that pre-CAIR allowances will be retired before CAIR allowances. 6

Mark-to-Market for CAIR Allowances (12/18/2012) Commodity $/Ton Tons Extended Value SO2 Allowances $ 0.60 9,065 $ 5,439 NOx Allowances - Seasonal $15.00 63 945 NOx Allowances - Annual $41.00 118 4,838 TOTAL $11,222 Regional Greenhouse Gas Initiative The State of Delaware is a participant in the Regional Greenhouse Gas Initiative (RGGI). The City of Dover must comply with RGGI by surrendering carbon dioxide (CO2) allowances pursuant to the State of Delaware’s laws (Title 7, Chapter 60, Sub-Title II-A). Delaware has elected a combined emissions allowance allocation/auction mechanism for RGGI, in which 40% of CO2 allowances were allocated to sources for 2009, declining by 8% per year so that by 2014, all CO2 allowances are auctioned. Dover has had more than a sufficient number of RGGI allowances allocated to it to cover its requirements through the first compliance period (calendar years 2009-2011). Any unused allowances are carried over (“banked”) for subsequent years. The cumulative balance of unused RGGI allowances held by Dover were 92,712 tons as of the end of Calendar year 2011, as shown in the table below. During the months of June - November, 2012, Dover’s generating units produced 15,265 tons of CO2 emissions, thus reducing the amount available in the allowance bank. 7

CO2 Allowance Summary (11/30/2012) 1 2 3 4 5 6 7 8 CO2 Allowances Available Annual CO2 CO2 (Per Facility, Allocated Cumulative CO2 Tons CO2 Allowance Allowances Prior to Sale) CO2 Vintage Sold YTD Allowances Emitted Allowance Balance McKee Balance VanSant Run 2009 0 60,128 2,056 62,184 (5,796) 56,388 56,388 2010 0 48,102 1,645 49,747 (32,971) 16,776 73,164 2011 0 36,077 1,234 37,311 (17,763) 19,548 92,712 2012 0 27,058 925 27,983 ( 15,265) 11,793 104,505 3 2013 0 15,032 514 15,546 - 15,546 120,051 The table shows that the “Allocated CO2 Allowances” (column 5) are declining; after 2013, Dover will no longer receive allocations of RGGI allowances. Actual CO2 emissions (column 6) have varied from 5,796 tons in 2009 to 32,971 tons in 2010. The Cumulative Balance (column 8) – aka “Banked Allowances”) can be utilized for generation in future years. Once the banked allowances have been fully utilized, Dover will be required to purchase allowances through the periodic RGGI auctions or through over-the-counter markets. Assuming that Dover does not sell any banked allowances, it will be able to maintain a positive balance through 2016 – 2025, depending on actual annual energy production in 2012 and beyond. The most recent RGGI auction occurred on December 5, 2012 and the auction cleared at $1.93/ton. Based on this auction, the value of Dover’s existing RGGI allowance bank (104,505 tons) is approximately $201,695 (excluding allocations for 2013 which have not yet been allocated). RGGI is currently conducting a program review pursuant to the original RGGI memorandum of understanding between participating states. As a result of these activities, coupled with declining allocations, TEA believes that there is a reasonable expectation that RGGI market prices could increase over the next few years. Dover could elect to sell all or a portion of its banked allowances now and re-acquire allowances at a later date; however TEA is currently of the opinion that Dover will be better off retaining its banked allowances for use during future compliance years. 3 2013 allocations have not been added to Dover’s RGGI COATS account. These are listed for the purpose of showing the last expected allocation of RGGI allowances. 8

Renewable Energy Certificates Dover owns two photovoltaic systems totaling 15 kW, consisting of (a 5 kW unit at the Utilities Administration Building and two 5 kW units at the McKee Run generating station. The output has been recorded on PJM’s Generation Attribute Tracking System (GATS), resulting in a balance of 43 Solar Renewable Energy Certificates (SRECS). Additionally, Dover receives solar energy produced by the 10 MW Dover Sun Park which is owned by White Oak Solar Energy, LLC. In addition to the all of the physical energy produced by the Sun Park, Dover receives 15% of Sun Park’s SRECS. Through the end of October, 2012, Dover has accumulated a total of 3,719 SRECS from this contract. These SRECS have also been recorded in Dover’s GATS account. Given the current SREC market structure, combined with the impact of the Sun Park and other facilities coming on-line in 2011, Dover’s ability to remarket excess SRECs presents unique challenges. Market price for Delaware SRECs from the September 2012 auction was $40/MWh, resulting in a market value of $151,480 for Dover’s 3,762 SRECs. It should be noted, however, that the nearest viable market for Dover’s SRECs is Pennsylvania which has market price mid-point of $16, less than half of the price from the most recent Delaware auction price. TEA is recommending that Dover retain these allowances for compliance with its Renewable Portfolio Standard which we understand DEMEC is working on. Once Dover has an approved RPS in place, it may be required to retire a portion of its current SREC balance for compliance in the 2012/13 future compliance year. Any remaining SRECs could be used for the 2013/14 compliance year. 9

D. Operations Management Summary: During the month of November, there were no reportable or lost time accidents or injuries. The facility has now gone 778 days without an OSHA recordable accident and 778 consecutive days without a lost time reportable accident. There were zero Environmental Notices of Violations issued. There were no Near Miss incidents. All Units were in Planned outages during the month. Unit 1 was put on line for test on November 13th and Unit 2 was put on line November 8th to perform an over speed trip test. Monthly Budget Variance - The actual expenses attributable to O&M of the two sites for the month of November were $506,844. The actual expenses are $28,219 or 5.27% under the approved budget of $535,063. The principal reasons for the favorable variance were due to having a vacant position and lower expenses in Environmental expenses, Other equipment maintenance, and Combustion turbine maintenance due to timing of expenses. This was offset by higher expenses in Boiler systems maintenance due to the repair of boiler safety valves on Units 1 and 2. 10

E. Risk Management Summary: Forward power prices in PJM have fallen slightly since last month due to lower forward gas prices and resulting in a lower blended cost. The current projected cost of service is below: Power Year Hedge Ratio Blended Cost ($/MWh) 2012-13 80% $61.56 2013-14 46% $52.00 2014-15 27% $48.32 2015-16 14% $47.63 11

II. Budget Report Variance Report: Budget Actual Variance Nov-12 Nov-12 Gross Load Forecast 53,533 56,881 (3,348) Power Supply Hedged Energy $2,885,282 $2,769,375 $115,907 PJM- Energy $721,542 $452,956 $268,586 PJM - Transmission and Fees $313,000 $659,388 ($346,388) Dover SUN Park Energy $71,112 $79,150 ($8,038) Management Fees $83,000 $83,000 $0 Capacity UCAP Obligated Purchased $996,729 $920,462 $76,267 Subtotal - Power Supply $5,070,665 $4,964,331 $106,335 Power Generation O&M & Fixed Fuel Plant O&M $535,063 $506,844 $28,219 Subtotal Generation O&M $535,063 $506,844 $28,219 Power Generation Production Margin Economic and reliability dispatch $0 ($1,315) $1,315 Fixed Fuel and Transport Charges $0 $1,854 ($1,854) Subtotal Generation Production Margin $0 $539 ($539) Power Generation Non-Production Revenue Generation Capacity Credit ($1,167,075) ($1,167,075) $0 Emissions Allowance Sales $0 $0 $0 Black Start & Reactive Power Revenue ($35,580) ($36,373) $793 Subtotal - Non-Production Revenue ($1,202,655) ($1,203,448) $793 SubTotal - All Generation ($667,592) ($696,065) $28,473 Total - Utilities Cost $4,403,073 $4,268,266 $134,808 Unit Costs Total - Power Supply $94.72 $87.28 $7.44 Total - Power Generation ($12.47) ($12.24) ($0.23) Final Cost of Service to City of Dover Ratepayers $82.25 $75.04 $7.21 12

Variance Analysis: Power Supply  Dover consumed 3,348 MWh more than what was forecasted for the month.  PJM energy costs were lower than expected, but PJM’s fees were higher than forecast. Hedged costs were under forecast.  The result of lower overall costs for more power was a net power supply cost of $87.28/MWh, $7.44/MWh lower than budget.  For the month, the city realized a favorable variance of $106,335 for power supply vs. the monthly budget.  Dover Sun Park generated 95 MWh more than what was forecasted. Generation  Power generation had a favorable budget variance of $28,473.  Plant O&M expenses had a favorable budget variance of $28,219 for the month. 13

YTD Variance Report: Budget Actual Variance YTD YTD Gross Load Forecast 325,656 337,076 (11,420) Power Supply Hedged Energy $17,603,949 $17,000,477 $603,472 PJM- Energy $5,951,200 $2,627,018 $3,324,182 PJM - Transmission and Fees $1,565,000 $3,302,016 ($1,737,016) Dover SUN Park Energy $646,240 $674,031 ($27,791) Management Fees $415,000 $415,000 $0 Capacity UCAP Obligated Purchased $5,083,320 $4,690,301 $393,019 Subtotal - Power Supply $31,264,709 $28,708,842 $2,555,867 Power Generation O&M & Fixed Fuel Plant O&M $2,433,676 $2,370,912 $62,764 Subtotal Generation O&M $2,433,676 $2,370,912 $62,764 Power Generation Production Margin Economic and reliability dispatch ($1,124,312) ($1,865,604) $741,292 Fixed Fuel and Transport Charges $586,004 $944,037 ($358,033) Subtotal Generation Production Margin ($538,308) ($921,567) $383,259 Power Generation Non-Production Revenue Generation Capacity Credit ($5,952,084) ($5,952,082) ($2) Emissions Allowance Sales $0 $0 $0 Black Start & Reactive Power Revenue ($177,900) ($237,766) $59,866 Subtotal - Non-Production Revenue ($6,129,984) ($6,189,848) $59,864 SubTotal - All Generation ($4,234,616) ($4,740,502) $505,886 Total - Utilities Cost $27,030,093 $23,968,340 $3,061,753 Unit Costs Total - Power Supply $96.02 $86.53 $9.49 Total - Power Generation ($13.30) ($14.41) $1.11 Final Cost of Service to City of Dover Ratepayers $82.72 $72.12 $10.60 14

III. Operations Management NAES Corporation Dover, Delaware November 2012 Monthly Report Operations Supervisor Lawrence Sheranko, I/C Technician Rich Newman, Maintenance Supervisor Phil Marvel, I/C,E Technician Chuck Luton and Auxiliary Operator, Bob Clawson, receiving NAES Quality Award for exemplary performance in difficult situation which averted a force outage on Unit 3. 15

Table of Contents 1.0 Environmental, Health and Safety 2.0 Financial 3.0 Operations 4.0 Maintenance 5.0 CIP 6.0 General Plant Information 7.0 Summary of NAES Performance 16

1.0 Environmental, Health and Safety: During the month of November, there were no restricted work days or lost time accidents. The facility has now gone two years and eighteen days (778 days total) through November 30, 2012 without an OSHA Recordable Accident or a Lost Time reportable accident. The October DMR was submitted for the McKee Run site with no NPDES exceedences. The plant received no Notice of Violations (NOVs) during the month. Work continues on the IWDP (wastewater) permit with Kent County. Bid requests have been issued for project installation work. The facility sold/transferred two (2) Ozone Season NOx allowances. Environmental, Health, and Safety Statistics Month Fiscal Year to Date (November) (7/1/12-11/30/12) NOVs 0 0 Opacity Deviations 0 0 Environmental Deviations 0 7 OSHA Recordable 0 0 OSHA LTA's 0 0 First Aid cases 0 0 Restricted Workday Accident 0 0 Near Miss 0 2 Man Hours Worked 3,953.00 21,105.75 Date last OSHA Recordable 10/14/10 Date last Lost Time Accident 10/14/10 Days since last OSHA recordable 778 Days since last Lost Time Accident 778 Emissions (NOx & SO2) All data thru 10/31/12 NOx Summary – Ozone Season (May-Sep) Tons Year Unit #1 Unit #2 Unit #3 Unit #11 TOTAL 2009 0.9 0.7 4.2 0.6 6.4 2010 0.7 2.2 88.7 3.3 94.7 2011 1.8 1.5 31.4 1.4 36.1 2012 1.2 1.0 35.8 1.0 33.1 NOx Summary - Year (Jan-Dec) Tons Year Unit #1 Unit #2 Unit #3 Unit #11 TOTAL 2009 0.9 0.7 10.1 0.6 12.3 2010 0.7 2.2 88.7 3.3 94.7 2011 1.8 1.5 32.6 2.9 38.8 2012 1.2 1.1 35.8 1.0 36.9 17

SO2 Summary - Year (Jan-Dec) Tons Year Unit #1 Unit #2 Unit #3 Unit #11 TOTAL 2009 0.05 0.05 0.1 0.2 0.4 2010 0.0 0.0 0.3 0.0 0.3 2011 0.0 0.0 0.1 0.5 0.6 2012 0.0 0.0 0.0 0.1 0.1 SO2 Allowances Summary SO2 Allowances Available Total SO2 SO2 (Per Unit, Prior to Sale & Tons Emitted SO2 SO2 Allowance Allowances Reconciliation) – Allowances Vintage Sold - YTD U3 and U11 Balance Unit #3 Unit #11 YTD 2010 and earlier 0 4815 276 0 5089 2011 0 1850 138 1 1988* 2012 0 1850 138 1 1988* *Note – Emissions allowances are deducted according to oldest vintage first or unless otherwise directed. CO2 Allowances Summary* CO2 CO2 CO2 Allowances Available Total CO2 CO2 Allowance Allowances (Per Facility, Prior to Tons Emitted Allowance Vintage Sold YTD Sale) Balance McKee Run VanSant 2009 0 60,128 2,056 5,796 56,388 2010 0 48,102 1,645 32,971 16,776 2011 0 36,077 1,234 17,763 19,548 2012 0 27,058 925 15,265 11,793 2013 0 15,032 514 0 15,546 Note: All CO2 allowance values are provided by the RGGI CO2 Allowance Tracking System. CAIR NOx Allowances Summary* NOx Allowances CAIR CAIR NOx Available Total NOx NOx Allowance Balance CAIR NOx NOx Allowances (Per Facility, Prior to Tons Emitted Allowances Allowance Sold YTD Sale) (Yr/ Season) Purchased Vintage McKee McKee VanSant YTD VanSant Run McKee Run - Run (Yr/Season) (Yr/Season) (Yr/Season) VanSant (Yr/Season) 2010 and 1 29/30 0/2 earlier 2011 0 77/48 5/3 33/31– 3/1 0/0 - 0/0 44/17 2/2 2012 2** 75/48 5/3 36/36 – 1/1 0/0 - 0/0 39/10 4/2 *Note – Emissions allowances are deducted according to oldest vintage first or unless otherwise directed. **Note – The facility transferred Ozone Season allowances to a third party. 18

2.0 Financial Financial – Current Month Month – November Actual Budget Variance Personnel 365,874 378,211 12,337 Materials & Supplies 7,221 7,282 61 Administrative Expenses 133,749 149,570 15,821 Total $506,844 $535,063 $28,219 Financial – Fiscal Year to Date Number of Months – 4 Actual Budget Variance Personnel 1,287,504 1,345,157 57,653 Materials & Supplies 118,353 129,410 11,057 Administrative Expenses 965,054 959,109 (5,945) Total 2,370,911 2,433,676 $62,765 2.1 Variance analysis: The City of Dover Finance Department has closed the books for the month of November. The expenses for November are $506,844 against a budgeted amount of $535,063 for a favorable variance of $28,219 or ≈ 5.27%. The variance was due to the following: PERSONNEL EXPENSES – A favorable monthly variance of $12,337 was to due to having a vacant position and lower than budgeted labor burdens. MATERIALS AND SUPPLIES EXPENSES- A favorable monthly variance of $61 with no major variances in any of the accounts. ADMINISTRATIVE EXPENSES – A favorable monthly variance of $15,821 was due to lower expenses in Environmental Expenses, Other Equipment – Maintenance, and Combustion Turbine Maintenance. A portion of this was due to timing of invoice receipts for CEMS maintenance contracts and not performing the main gas piping inspection at the VanSant station as budgeted, although it will be completed later in the fiscal year. Contractual Services and Boiler Systems Maintenance accounts expenses were higher than budgeted due to HEP and FAC work (Contractual Services)was completed sooner than budgeted and due to needed repairs to Units 1and 2 boiler safety valves (Boiler Systems Maintenance) found during the annual inspection/testing. The budget is currently forecasted to finish this fiscal year at $5,863,983 expensed versus a budget of $5,914,900 thereby realizing a 99.14% expenditure rate. 19

3.0 Operations Unit Operations / Outages / Trips On October 1, 2012 at 0700 hours, all four of the City of Dover units went into a planned fall outage. Unit 1 was started and placed online on November 13 in order to check out repairs that had been made to turbine gland seals that also included a realignment of the turbine and generator. Month - November 2012 McKee McKee McKee MRS VanSant Total Unit 1 Unit 2 Unit 3 Facility Unit 11 All Units Capacity MW 17 17 102 136 39 175 On Line Hours Hrs 3.5 0.0 0.0 0.0 0.0 3.5 Starts # 1 0 0 1 0 1 Gross Generation MWh 25.473 0.0 0.0 25.473 0.0 25.473 Net Generation MWh 24.85 0.0 0.0 24.85 0.0 24.85 Total Auxiliaries MWh 29.06 28.43 118.34 175.83 2.687 178.51 Auxiliaries purchased MWh 28.432 28.43 118.34 175.204 2.687 177.79 Fuel Gas Used MMBTU 410.685 0.0 0.0 410.685 0.0 410.685 Fuel Oil Used MMBTU 0.0 0.0 0.0 0.0 0.0 0.0 Fuel Oil Used Gallons 0.0 0.0 0.0 0.0 0.0 0.0 Total Fuel MMBTU 410.685 0.0 0 410.685 0.0 410.685 Net Heat Rate BTU/KWh 16,527 0.0 0 16,527 0 16,527 Unit Trips # 0 0 0 0 0 0 Capacity Factor % 0.2 0.0 0.0 .03 0.0 .02 Availability Factor % 0.49 0.0 0.0 0.16 0.0 0.12 Commercial % 0 0 0 0 0 0 Unavailability (CU) Planned Outage Hours Hours 737.000 737.000 737.000 2,211.000 737.000 2,948.000 Maintenance Outage Hours 0.0 0.0 0.0 0.0 0.0 0.0 Hours Forced Outage Hours Hours 0.0 0.0 0.0 0.0 0.0 0.0 Reserve Shutdown Hours 0.0 0.0 0.0 0.0 0.0 0.0 Hours HW Boiler Gas Usage MMBTU 0 0 Pilot Gas Usage MMBTU 0 0 0 0 # Note: Does not include HWB or Pilot Gas. Fuel usage numbers are taken from fuel flow instruments. 20

2012-2013 Fiscal Year-to-Date - November McKee McKee McKee MRS VanSant Total Unit 1 Unit 2 Unit 3 Facility Unit 11 All Units Capacity MW 17 17 102 136 39 175 On Line Hours Hrs 96.282 71.970 285.597 453.849 22.066 475.915 Starts # 3 2 26 31 4 35 Gross Generation MWh 668.79 582.202 18,797.488 20,048.48 714.818 20,763.298 Net Generation MWh 628.855 541.673 17,317.513 18,488.041 714.287 19,202.328 Total Auxiliaries MWh 175.257 175.850 2456.057 2,807.165 9.368 2,816.523 Auxiliaries purchased MWh 135.322 135.322 976.082 1,247.723 8.837 1,255.563 Fuel Gas Used MMBTU 9,483 8,108, 199,166.724 216,348 8,429, 225,188 Fuel Oil Used MMBTU 0.0 0.0 0.0 0.0 112.567 112.567 Fuel Oil Used Gallons 0.0 0.0 0.0 0.0 5,806 5,806 Total Fuel MMBTU 9,483 8,108, 199,166.724 216,348 8,54 225,301 Net Heat Rate BTU/KWh 15,021 14,970 11.826 13,939 12,604 13,271 Unit Trips # 0 0 1 1 0 1 Capacity Factor % 0.40 0.36 2.35 1.86 0.28 1.67 Availability Factor % 74.85 74.85 74.85 74.85 75.94 75.12 Commercial % 0 0 0 0 0 0 Unavailability (CU) Planned Outage Hours Hours 1,457 1,457 1,457 4,371 1,457 5,828 Maintenance Outage Hours 0.0 0.0 0.0 0.0 0.0 0.0 Hours Forced Outage Hours Hours 0.0 0.0 0.0 0.0 0.0 0.0 Reserve Shutdown Hours 2,122.218 2,143.030 1,929.570 6,194.818 2,192.934 8,387.752 Hours HW Boiler Gas Usage MMBTU 0 0 Pilot Gas Usage MMBTU 1,340 1,049 2,389 2,389 Fuel Oil Inventory Monthly Monthly Fuel Monthly FY 12-13 Fuel FY 12-13 Inventory Inventory Purchases Inventory Inventory Purchases Inventory (Start) (End) (Month) (Change) (Start) (YTD) (Change) McKee Run (#2 Fuel Oil) 452,963 451,200 0 (1,763) 454,725 0 (3,525) VanSant 144,616 143,942 0 (674) 152,150 0 (8,208) (#2 Fuel Oil) Note: As measured by tank level instruments. Tank levels may change due to oil temperature. 21

VanSant Lifetime through 10/31//12 Actual Starts Factored Starts Fired Hours VanSant 1303 2230.45 4215.86 Since HGP - Dec 2004 229 566.05 832.28 Capacity Testing – FY 2012-2013 Summer 2012 (June 1- Aug 31) Winter 2012-2013 (Dec 1- Mar 1) Unit Rated Net Reported Net Unit Rated Net Reported Net Capability (MW) Capability (MW) Capability (MW) Capability (MW) 1 17 17.0 1 17 * 2 17 17.3 2 17 * 3 102 102.7 3 102 * VanSant 39 39.0 11 39 * Total 175 176.0 Total 175 175 Note: * Denotes Unit is qualified for the PJM Winter Demonstration Period Exemption Program Team Report: Operations personnel continue to support maintenance by working on Preventative Maintenance (PM) work orders and other work orders that they have the necessary skills to successfully complete the task. The Operations Department continues to utilize the Day Shift Workers in both Operations and Maintenance areas to help in maintaining the plant. Plant employees continue General Physics safety training and environmental courses to enhance their overall knowledge of permit and safety requirements. As the GPI courses are being completed the employee reviews the standard operating procedure (SMP) for the same topic they are training on to review NAES policy and score a minimum 80% on a quiz before they can complete the SMP. 22

4.0 Maintenance During the month of November, the Plant Maintenance staff continued addressing the backlog of work orders and completing outage activities. There were fifty-one work orders issued with fifty-nine work orders being completed during the month. There was no safety work orders entered into the plant’s Computerized Maintenance Management System (MP2) during the month. The table below summarizes the monthly work order activities. Work Order Report November - 2012 Outstanding From Outstanding Previous Issued This Completed at the end of Priority # Month Month This Month the month 1 14 1 5 10 2 43 12 18 37 3 49 7 5 51 4 7 1 2 6 5 15 1 0 16 SW1 0 0 0 0 SW2 0 0 0 0 SW3 0 0 0 0 SW4 0 0 0 0 SW5 0 0 0 0 PM 54 29 29 54 Totals 182 51 59 174 Note: PMs are included in the priority totals Notable activities during the month include:  All four units were in a planned maintenance outage during the month. Unit 1 was place online for testing.  NAES Mechanical and IC&E staff continued working on outage related work that returns critical unit equipment to a safe and reliable condition also maintaining unit availability in the most cost effective manner. All work performed in accordance with safe work practices and without impact to the environment.  STI CEMS was on site to complete the third party calibration and maintenance of the Teledyne 560 LightHawk opacity monitors on all four units. This is an annual audit. No issues were found with any of the monitors.  APEX Piping System was on site to install a new expansion joint on the hot gas outlet of the Unit 3 Boiler. APEX also replaced the condenser steam drain piping tree on Unit 3 due to thinning of the piping. APEX was also contracted to repair two RH tube leaks discovered during a vacuum test of the RH piping system. 23

New clips and lugs were also installed while work was being performed in the RH section. Additional work in the reheat section of the boiler will be needed in the spring outage.  Maintenance staff installed a new spring check valve on the condensate line that goes from the outdoor storage tank to the indoor storage tank. This valve was installed to prevent the water migration from the indoor storage tank to the outdoor storage tank. 24

5.0 Capital Improvement Projects (CIP) Project Description Update Number Units 1 & 2 Cooling Progress: The FY2013 work scope package being developed EG1102 Tower Repairs Schedule: Work scheduled to be completed in the 4th quarter Progress: Work scheduled for the Spring 2013 outage. Bid Unit #3 Boiler document being developed. Completion at 5%. EG1202 Systems Schedule: Bids to be obtained in 2nd quarter of 2012 and work to be completed in the spring 2013 outage. Progress: The FY2013 Spring Outage work scope package is being developed. Unit 3 Auxiliary EG1203 Schedule: Some work is being performed on the Unit 3 Condenser System Components Drains and other work is scheduled to be complete in the spring outage. Progress: Long lead material requirements being developed for bid. Unit 3 Turbine EG1212 Schedule: Long lead items will be procured in the spring of 2013. Repairs Progress: The FY2013 work scope package being developed Units 1 & 2 EG1304 Schedule: Work to be completed during the spring outage Components Repairs Turbine Level Progress: The FY2013 work scope package being developed EG1306 Window Schedule: Work to be completed during the 2ndquarter of 2013. modification Progress: Material has been purchased, delivered and has been Unit 3 Air Heater EG1112 installed Expansion Joint Schedule: Work was completed in November. Progress: Scope of work has changed since this project was proposed as the stack inspection performed in spring of 2012 determined stack lining in worse condition than expected. Activities in 2013 will be to develop repair scope and obtain bids for the work. EG1309 Unit 3 Stack Repairs This should be completed in the 3rd FY quarter. Schedule: The scoping of work should be completed in the 3rd FY quarter with bids and revised installation costs identified. Actual repair work will be scheduled for fiscal 2014. Progress: The FY2013 work scope package being developed. Units 1&2 Stack Schedule: Work to be completed during the spring outage or EG1310 Repairs deferred until 2014. Inspection was completed in November and report is forthcoming. Progress: Valuation of the benefits of various technologies is VanSant Capacity underway. Final decision on moving forward with the project has EG1311 Increase still not been made. Schedule: Installation was scheduled for the 4th quarter but is 25

dependent on favorable decision to move forward. At present time, this cannot expect to be completed until late 2013, at the earliest. Progress: Parts identification has been completed and parts are on Unit 3 Generator order. Installation bid package being developed. Expect to issue bids EG1312 Repairs in the 2nd FY quarter. Schedule: Installation work to be completed in the 4th quarter. Progress: Mechanical and electrical design is complete. Quotes for MR Industrial Waste Mechanical materials sent out to qualified bidders. Pre-bid set up for EG1214 water System December for both mechanical and electrical contractors. Schedule: Installation work planned for the 3rd quarter of FY. Progress: Work was to be completed in November with a system Unit 1 Gland Steam EG1301 check of the unit occurring afterwards. Seal Repair Schedule: Work is now complete. 26

6.0 General Plant Information After a thorough recruiting search, Christine Dean was brought onboard as the new Plant Administrative Manager. Christine started work on November 13, 2012 and has started to become familiar with NAES and plant procedures. She is tentatively scheduled to go to Issaquah the week of January 14th for training and orientation. Training: Topics discussed during the monthly safety committee meeting were reviewed by the entire staff. The monthly safety topic was on “Winter Slip Protection” which provided important information on how to avoid injuries that typically might occur during the wintery season. Calendar of Events Date Units 1, 2, 3 and 11 Fall Outage October 1, 2012 – December 3, 2012 Two Year Accident Free October 14, 2012 Winter Capacity Period December 1, 2012 to February 28, 2013 McKee Run and VanSant Title V Annual Certification Due February 1, 2013 Annual VanSant Black Start Test TBD EIA-860 Report February 28, 2013 EIA-923 Report February 28, 2013 NOx Emissions Reconciliation Due March 1, 2013 SO2 Emissions Reconciliation Due March 1, 2013 SARA III Report March 1, 2013 NPDES Permit Renewal Due March 4, 2013 Units 1, 2, and 3 Spring Outage March , 2013 – June 1, 2013 Unit 11 Spring Outage March , 2013 – June 1, 2013 Air Emission Inventory June 30, 2012 NOx Ozone Season Starts May 1, 2013 PJM Summer Capacity Test Period June 1, 2013 – August 31, 2013 Toxic Release Inventory (TRI) Annual Report July 1, 2013 McKee Run and VanSant Title V Semi-Annual Certification Due August 1, 2013 DRBC Study Due September 15, 2013 NOx Ozone Season Ends September 30, 2013 27

7.0 Summary of NAES Performance to Date Plant Performance FY 2012-2013 Measure Month Year to Date YTD FY Maximum Incentive Incentive Commercial 0% 0% $92,128 $92,128 Unavailability (CU) Safety 0 0 $17,273 $17,273 Environmental 0 0 $17,273 $17,273 Capacity Tests Summer Winter Summer Winter Completed Unit 1 No No Yes Yes* $3,455* $3,455 Unit 2 No No Yes Yes* $3,455* $3,455 Unit 3 No No Yes Yes* $20,520* $20,520 Unit 11 No No Yes Yes* $6,840* $6,840 Total YTD 100.00% Total YTD Incentive $161,224 $161,224 Incentive % Note: Units 1 and 2 PJM Summer Capacity Tests have been successfully completed and would be entered into the PJM Winter Capacity Test Exemption Program*. The YTD Incentive calculation reflects this information. 28

IV. Appendix – PJM Invoice Breakdown Gen Load Grand Total Auction Revenue Rights $ (1,081.20) $ (1,081.20) Balancing Operating Reserve $ 23,734.78 $ 23,734.78 Balancing Spot Market Energy $ (1,121.56) $ (172,451.00) $ (173,572.56) Balancing Transmission Congestion $ (138.27) $ 8,824.81 $ 8,686.54 Balancing Transmission Losses $ (55.40) $ 4,613.14 $ 4,557.74 Black Start Service $ (6,905.58) $ 1,869.02 $ (5,036.56) Capacity Resource Deficiency $ (224.95) $ (224.95) Capacity Transfer Rights $ (32,243.40) $ (32,243.40) Day-ahead Operating Reserve $ 14,932.66 $ 14,932.66 Day-ahead Scheduling Reserve $ 72.58 $ 72.58 Day-ahead Spot Market Energy $ 625,407.19 $ 625,407.19 Day-ahead Transmission Congestion $ 114,911.45 $ 114,911.45 Day-ahead Transmission Losses $ 112,028.78 $ 112,028.78 Expansion Cost Recovery $ 413.70 $ 413.70 FERC Annual Recovery $ 3,933.41 $ 3,933.41 Generation Deactivation Refund $ (744.31) $ (744.31) Inadvertent Interchange $ 819.58 $ 819.58 Load Reconciliation for Balancing Operating $ (1.83) $ (1.83) Load Reconciliation for FERC Annual Recovery $ (7.55) $ (7.55) Load Reconciliation for Inadvertent Interchange $ 0.24 $ 0.24 Load Reconciliation for Market Monitoring Unit (MMU) Funding $ (0.47) $ (0.47) Load Reconciliation for North American Electric Reliability Corporation (NERC) $ (1.18) $ (1.18) Load Reconciliation for PJM Scheduling, System Control and Dispatch Service $ (22.64) $ (22.64) Load Reconciliation for PJM Scheduling, System Control and Dispatch Service Refund $ 1.01 $ 1.01 Load Reconciliation for Reactive Services $ (161.26) $ (161.26) Load Reconciliation for Regulation and Frequency Response Service $ (24.34) $ (24.34) Load Reconciliation for Reliability First $ (1.48) $ (1.48) Load Reconciliation for Schedule 9-6 - Advanced Second Control Center $ (2.83) $ (2.83) Load Reconciliation for Spot Market Energy $ (3,899.89) $ (3,899.89) Load Reconciliation for Synchronized Reserve $ (6.15) $ (6.15) Load Reconciliation for Transmission Congestion $ (121.86) $ (121.86) Load Reconciliation for Transmission Losses $ (121.43) $ (121.43) Load Reconciliation for Transmission Owner Scheduling, System Control and Dispatch $ (8.15) $ (8.15) Locational Reliability $ 953,933.56 $ 953,933.56 Market Monitoring Unit (MMU) Funding $ 260.24 $ 260.24 Meter Error Correction $ (1,881.20) $ (1,881.20) Network Integration Transmission Service $ 285,936.60 $ 285,936.60 Non-Firm Point-to-Point Transmission Service $ (645.90) $ (645.90) 29

North American Electric Reliability Corporation $ 616.58 $ 616.58 Organization of PJM States, Inc. (OPSI) Funding $ 39.39 $ 39.39 PJM Scheduling, System Control and Dispatch Service - Advanced Second Control Center $ 1,603.45 $ 1,603.45 PJM Scheduling, System Control and Dispatch Service - Capacity Resource/Obligation Mgmt. $ 918.30 $ 918.30 PJM Scheduling, System Control and Dispatch Service - Control Area Administration $ 9,659.41 $ 9,659.41 PJM Scheduling, System Control and Dispatch Service - Market Support $ 2,184.11 $ 2,184.11 PJM Scheduling, System Control and Dispatch Service - Market Support Offset $ (319.81) $ (319.81) PJM Scheduling, System Control and Dispatch Service - Regulation Market Administration $ 102.07 $ 102.07 PJM Scheduling, System Control and Dispatch Service Refund - Capacity Resource/Obligation $ (165.99) $ (165.99) PJM Scheduling, System Control and Dispatch Service Refund - Control Area Administration $ (1,861.10) $ (1,861.10) PJM Scheduling, System Control and Dispatch Service Refund - Market Support $ (423.42) $ (423.42) PJM Scheduling, System Control and Dispatch Service Refund - Regulation Market $ (22.35) $ (22.35) PJM Settlement, Inc. $ 319.81 $ 319.81 Reactive Services $ 1,099.37 $ 1,099.37 Reactive Supply and Voltage Control from Generation and Other Sources Service $ (29,467.58) $ 32,467.96 $ 3,000.38 Regulation and Frequency Response Service $ 23,337.99 $ 23,337.99 Reliability First Corporation (RFC) $ 770.69 $ 770.69 RPM Auction $ (1,167,075.00) $ (1,167,075.00) Synchronized Reserve $ 19,288.76 $ 19,288.76 Transmission Enhancement $ 18,945.11 $ 18,945.11 Transmission Losses $ (24,606.80) $ (24,606.80) Transmission Owner Scheduling, System Control and Dispatch Service $ 4,241.68 $ 4,241.68 Day-ahead Operating Reserve for Load Response $ 0.03 $ 0.03 Balancing Operating Reserve for Load Response $ 4.58 $ 4.58 Load Reconciliation for Organization of PJM States, Inc. (OPSI) Funding $ (0.08) $ (0.08) Load Reconciliation for Day-ahead Scheduling $ (0.35) $ (0.35) Load Reconciliation for Synchronous Condensing $ (0.07) $ (0.07) Emergency Load Response $ (36.36) $ (36.36) Demand Resource and ILR Compliance Penalty $ (92.70) $ (92.70) PJM Annual Membership Fee $ 5,000.00 $ 5,000.00 Day-Ahead Load Response Charge Allocation $ 87.17 $ 87.17 Real-Time Load Response Charge Allocation $ 519.32 $ 519.32 Incremental Capacity Transfer Rights $ (1,003.50) $ (1,003.50) Michigan - Ontario Interface Phase Angle $ 183.87 $ 183.87 Non-Synchronized Reserve $ 1,914.04 $ 1,914.04 CT Lost Opportunity Cost Allocation $ (5.28) $ (5.28) Grand Total $ (1,204,763.39) $ 2,032,805.61 $ 828,042.22 30

FUND SUMMARY as of 01/28/2013 Total Collected $847,907.14 DEMEC Admin Fee Paid $37,984.60 State Admin Fee Paid $17,752.88 Grants Paid $664,208.32 Customer Only Grants/Fees Reserved and Amount Owed $33,358.63 Community Project Funds Requested $367,050.00 Energy Depot Paid $41,672.60 Efficiency Programs Paid $34,068.34 Solar Electric Power Association (SEPA) Fee $2,158.81 *Unencumbered Funds Available $12,569.98 Funding Shortfall Current Grant Payment Delay (Months) 0.0 * As of 01/28/2013 GRANTS PAID Grant Amount Review Fee Amount Date Grant Paid Applicant Type Paid Paid Owed 9/21/2007 Laura Drew Kelly Geo - Res $ 3,000.00 $ 225.00 $ - 12/5/2007 Domingo Reye Solar - Res $ 12,762.50 $ 750.00 $ - 4/16/2008 Lakeland Commercial Group Geo - Comm $ 10,800.00 $ 750.00 $ - 6/19/2008 & 08/25/2008 L.D. Shank - Triad Farms Solar - Comm $ 30,000.00 $ 750.00 $ - 10/6/2008 City of Dover Solar - Comm $ 40,820.00 $ 750.00 $ - 10/21/2008 Robert & Cynthia Hartman Geo HP- Res $ 1,800.00 $ 135.00 $ - 10/21/2008 Robert Varipapa Geo HP- Res $ 2,400.00 $ 180.00 $ - 2/27/2009 David Jump Solar - Res $ 15,000.00 $ 750.00 $ - 2/27/2009 Jakob Seren Solar - Res $ 15,000.00 $ 750.00 $ - 2/27/2009 William Sweet Solar - Res $ 15,000.00 $ 750.00 $ - 3/31/2009 LD Shank - Triad Farms Solar WH-Comm $ 3,000.00 $ 225.00 $ - 3/31/2009 Warren & Joan Seaver Geo HP- Res $ 3,000.00 $ 225.00 $ - 4/22/2009 William Sweet Solar HW $ 3,000.00 $ 225.00 $ - 4/28/2009 State of DE/DNREC - DE National Solar - Comm $ 30,000.00 $ 750.00 $ - 4/29/2009 Delaware Primary Care, LLC Solar - Comm $ 30,000.00 $ 750.00 $ - 9/11/2009 NCALL Solar - Comm $ 30,000.00 $ 750.00 $ - 9/11/2009 D. Brian Beckman Geo HP- Res $ 2,000.00 $ 150.00 $ - 9/21/2009 LKSC Dover, LLC Kids Cottage Solar - Comm $ 29,925.00 $ 750.00 $ - 10/5/2009 Mark F. Boller Geo HP- Res $ 3,000.00 $ 225.00 $ - 10/5/2009 John Welgan Solar - Res $ 15,000.00 $ 750.00 $ - 11/4/2009 LKSC Dover, LLC Kids Cottage Geo - Comm $ 12,000.00 $ 750.00 $ - 3/25/2010 Minaxi Patel Solar - Res $ 15,000.000 $ 750.000 $ - 3/23/2010 J. McGiffin Jr. & K. Doyle Geo HP- Res $ 3,000.000 $ 225.000 $ - 5/28/2010 Nancy Warner Geo HP- Res $ 1,200.000 $ 90.000 $ - 6/2/2010 David Teel Geo HP - Res $ 1,800.000 $ 135.000 $ - 6/2/2010 Dewey J. Barich Geo HP- Res $ 2,400.00 $ 180.000 $ - 7/12/2010 Mike & Sharonb Laverty Solar - Res $ 5,105.000 $ 382.880 $ - 8/19/2010 James Grilli Geo HP- Res $ 1,800.00 $ 135.000 $ - 8/19/2010 Michael Noble Solar - Res $ 15,000.000 $ 750.000 $ - 9/17/2010 David Teel Solar - Res $ 7,500.000 $ 562.500 $ - 3/8/2011 Michael & Carol Apgar Solar - Res $ 7,500.000 $ 562.500 $ - 3/17/2011 Elizabeth Murphey School Geo HP - Comm $ 9,200.000 $ 690.000 $ - 5/24/2011 Richard Avant Geo HP - Res $ 2,400.000 $ 180.000 $ - 6/23/2011 Charles Messina Plumbing Solar - Comm $ 10,000.000 $ 750.000 $ - 10/4/2011 Charles Bounds Geo HP - Res $ 1,800.000 $ 135.000 $ - 3/29/2011 Psychiatric Access Central DE Solar - Comm $ 13,187.500 $ 750.000 $ - 7/8/2011 Michael J. Kopp Geo - Res $ 2,300.000 $ 135.000 $ 37.50 10/17/2011 City of Dover ** Geo HP $ 48,267.000 $ - 3/7/2012 Ruth Ann Piper Geo - Res $ 1,200.000 $ 90.00 3/7/2012 Robert Hall Geo - Res $ 3,000.000 $ 225.00 3/7/2012 Elizabeth Murphey School Geo - Comm $ 13,800.000 $ 750.00 3/7/2012 Elizabeth Murphey School Geo - Comm $ 12,000.000 $ 750.00 3/7/2012 Elizabeth Murphey School Geo - Comm $ 5,400.000 $ 405.00 3/7/2012 Elizabeth Murphey School Geo - Comm $ 1,800.000 $ 135.00 3/7/2012 Elizabeth Murphey School Geo - Comm $ 10,200.000 $ 750.00 3/7/2012 Frank Daniels Geo - Res $ 4,400.000 $ 330.00 8/15/2012 Chong S. Tamburo-Lepage Geo - Res $ 2,300.00 $ 172.50 12/19/2012 Christopher W. Los Geo - Res $ 3,000.00 $ 225.00 Total $ 512,067.00 $ 17,752.88 $ 3,870.00 ARRA RELIEF GRANTS PAID Paid by State Customer System Type Amount 6/10/2011 Arturo Sanchez Solar - PV $ 7,500.00 10/19/2011 John Diamond Enterprise LLC Solar - PV - Com $ 30,000.00 10/19/2011 John Diamond Enterprise LLC Geo HP - Com $ 10,000.00 Total $ 47,500.00 PENDING APPLICATIONS Grant Reservation Status Applicant Type Request Review Fee Reservation Approved - Pending Completion ABRA Associates, LLC Solar - PV - Com $10,770.00 $750.00 Reservation Approved - Pending Completion Delaware Tech Solar - PV - Com $6,940.00 $520.50 Reservation Approved - Pending Completion Dennis Ho Solar - Res $6,775.00 $508.13 Reservation Approved - Pending Completion Matthew and Kimberly Chesser Geo - Res $3,000.00 $225.00 Total $27,485.00 $2,003.63 ENERGY DEPOT FEES Paid Fee Period Amount 3/3/2008 Start-up Fees $5,872.50 4/15/2008 Start-up Fees $1,957.50 4/15/2008 Mar, Apr, May 2008 $1,692.13 7/22/2008 June, July, Aug 2008 $1,692.13 10/10/2008 Sept, Oct, Nov 2008 $1,692.13 1/2/2009 Dec 08, Jan, Feb 2009 $1,692.13 4/3/2008 Mar, Apr, May 2009 $1,692.13 7/1/2009 June, July, Aug 2009 $1,692.13 9/11/2009 Sept, Oct, Nov 2009 $1,692.13 1/4/2010 Dec 09, Jan, Feb 2010 $1,692.13 3/29/2010 Mar, April, May 2010 $1,692.13 6/30/2010 June, July, Aug 2010 $1,692.13

10/4/2010 Sept, Oct, Nov 2010 $1,692.13 1/3/2011 Dec 2010, Jan, Feb 2011 $1,692.13 4/5/2011 Mar, Apr, May 2011 $1,692.13 7/8/2011 June, July, Aug 2011 $1,692.13 10/4/2011 Sept, Oct, Nov, 2011 $1,692.13 1/3/2012 Dec 2011; Jan, Feb 2012 $1,692.13 4/5/2012 Mar, Apr, May 2012 $1,692.13 7/2/2012 June, July, Aug 2012 $1,692.13 10/2/2012 Sept, Oct, Nov 2012 $1,692.13 12/12/2012 Dec 09, Jan, Feb 2013 $1,692.13 Total Paid $41,672.60 ENERGY EFFICIENCY CAMPAIGNS/EDUCATION PROGRAMS Paid Program Measure Amount 1,500 CFL Campaign & 10/21/2008 Educational Literature $5,012.29 12/11/2008 Reimbursement for Green $3,459.12 Thermal Imager for Home Audits 3/31/2009 Program $5,581.12 Eco @ Home Energy Conserv. 1/4/2011 Calendars $20,015.81 Total $34,068.34 Dover Library Commuity Grant Project Collections $5,021.15 1/2 of Oct 2009 GEF Payment $4,783.94 1/2 of Nov 2009 GEF Payment $4,813.23 1/2 of Dec 2009 GEF Payment $5,454.02 1/2 of Jan 2010 GEF Payment $5,147.49 1/2 of Feb 2010 GEF Payment $4,897.69 1/2 of March 2010 GEF Payment $3,976.14 1/2 of April 2010 GEF Payment $5,638.90 1/2 of May 2010 GEF Payment $5,645.35 1/2 of June 2010 GEF Payment $6,590.60 1/2 of July 2010 GEF Payment $7,786.09 1/2 of August 2010 GEF Payment $6,415.31 1/2 of Sept 2010 GEF Payment $5,327.96 1/2 of Oct 2010 GEF Payment $4,787.73 1/2 of Nov 2010 GEF Payment $4,939.75 1/2 of Dec 2010 GEF Payment $5,452.55 1/2 of Jan 2011 GEF Payment $5,410.35 1/2 of Feb 2011 GEF Payment $4,646.32 1/2 of March 2011 GEF Payment $4,742.22 1/2 of April 2011 GEF Payment $4,702.48 1/2 of May 2011 GEF Payment $5,664.97 1/2 of June 2011 GEF Payment $6,430.15 1/2 of July 2011 GEF Payment $6,916.50 1/2 of Aug 2011 GEF Payment $6,149.31 1/2 of Sept 2011 GEF Payment $5,243.92 1/2 of Oct 2011 GEF Payment $4,829.91 1/2 of Nov 2011 GEF Payment $4,531.81 1/2 of Dec 2011 GEF Payment $4,990.50 1/2 of Jan 2012 GEF Payment $5,071.81 1/2 of Feb 2012 GEF Payment $4,828.32 1/2 of March 2012 GEF Payment $4,857.07 1/2 of April 2012 GEF Payment $4,230.04 1/2 of May 2012 GEF Payment $5,711.19 1/2 of June 2012 GEF Payment $6,085.89 1/2 of July 2012 GEF Payment $7,347.66 1/2 of Aug 2012 GEF Payment $6,453.66 1/2 of Sept 2012 GEF Payment $4,886.43 1/2 of Oct 2012 GEF Payment $4,132.99 1/2 of Nov 2012 GEF Payment 1/2 of Dec 2012 GEF Payment $204,541.31 Total Collections Total Dover Lib. Draws to Date $48,267.00 10/17/2011 $152,141.32 12/5/2012 $4,132.98 Total Funds Available for Draw

City of Dover Electric Revenue Fund FY 2013 by Month Electric Supply & Generation - Cost per MWh by supply source July August September October November December YTD Power Supply & Generation Power Supply - Hedged Energy $ 4,223,076 $ 3,922,292 $ 3,188,284 $ 2,897,450 $ 2,769,375 $ 2,870,476 $ 19,870,953 Power Supply Management 83,000 83,000 83,000 83,000 83,000 83,000 498,000 Capacity Charges - Load 950,098 950,128 919,482 950,133 920,462 950,423 5,640,726 Dover Sun Park - Energy 188,115 165,987 149,808 90,971 79,150 54,242 728,272 Dover Sun Park - REC's 43,161 39,370 35,300 21,432 18,631 - 157,894 PJM Charges - Energy 802,211 606,534 450,504 314,812 452,956 393,584 3,020,601 PJM Charges - Transmission & Fees 918,146 695,232 561,029 468,221 659,388 553,192 3,855,208 Total Power Supply 7,207,807 6,462,542 5,387,407 4,826,019 4,982,962 4,904,916 33,771,653 Plant Operations 635,784 440,669 401,557 386,058 506,844 354,376 2,725,288 Generation Fuel 612,486 203,309 126,388 - 1,854 2,255 946,292 Capacity Credits (1,205,978) (1,205,978) (1,167,075) (1,205,977) (1,167,075) (1,205,978) (7,158,061) PJM Spot Market Energy - Dispatch (1,314,170) (327,757) (222,362) - (1,315) - (1,865,604) PJM Credits (Black Start/Reactive Pwr) (87,990) (39,939) (37,091) (36,373) (36,373) (72,746) (310,512) Total Generation (1,359,868) (929,696) (898,583) (856,292) (696,065) (922,093) (5,662,597) Total Power Supply & Plant 5,847,939 5,532,846 4,488,824 3,969,727 4,286,897 3,982,824 28,109,056 Budget Load (MWh) 79,471 72,771 60,787 59,094 53,533 58,224 383,880 Actual Gross Load (MWh) - Total Supply 82,270 77,973 63,216 56,736 56,881 58,283 395,359 Actual Gross Load (MWh) - PJM 80,172 76,080 61,534 55,715 55,992 57,674 387,167 MWh Hedged 63,480 59,400 48,720 46,450 44,695 46,048 308,793 MWh Unhedged 4,541 12,445 10,120 9,265 11,273 11,626 59,270 MWh Generated 12,151 4,235 2,694 - 24 - 19,104 MWh Purchased/Generated - Solar 2,098 1,893 1,682 1,021 889 609 8,192 MWh Power Supply $ (non-Solar) $ 87.02 $ 82.24 $ 84.54 $ 84.60 $ 87.25 $ 84.11 $ 84.94 MWh Solar Energy $ 89.66 $ 87.68 $ 89.07 $ 89.10 $ 89.03 $ 89.07 $ 88.90 MWh Generation $ $ (57.75) $ (29.39) $ (35.63) $ - $ 22.46 $ - $ (48.12) Net Plant Revenue $ (non-Generation) $ (658,184) $ (805,248) $ (802,609) $ (856,292) $ (696,604) $ (924,348) $ (4,743,285) All In MWh Supply & Generation $ $ 70.56 $ 70.45 $ 70.45 $ 69.59 $ 75.04 $ 68.34 $ 70.70 Solar REC's MWh 315 315 252 153 133 1,168 MWh Solar REC $ (one month lag) $ 137.02 $ 124.98 $ 140.08 $ 140.08 $ 140.08 $ 135.18 ]

City of Dover Electric Supply & Generation Cost per MWh by Supply Source Fiscal Year 2013 $75.04 $70.56 $70.45 $69.59 $70.45 $87.25 All In MWh Supply & Generation $ $87.02 $84.54 $84.60 $82.24 $89.03 $68.34 MWh Power Supply $ (non‐Solar) $89.66 $89.07 $89.10 $87.68 $84.11 MWh Solar Energy $140.08 $137.02 $124.98 $140.08 $140.08 $89.07 MWh Solar REC $ (one month lag) $‐ $22.46 $‐ $(29.39) $(35.63) $(57.75) MWh Generation $ July August September October November December ]