Attachment

UTILITY COMMITTEE AGENDA AUGUST 12, 2013 - 6:00 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 Abandonment of Right of Way (Unimproved) - Overlook Place (Staff Recommends Abandonment of the Subject Right-of-Way with Conveyance of Twenty-Five and One-Half Feet (25.5') of Said Right-of-Way to 125 and 126 Overlook Place, Currently Owned by Chu Pao Robinson and Michael P. Bouchard, Respectively, in Conjunction with the Provision of a Public Utility Easement for Each Parcel and Adoption of a Resolution Setting a Public Hearing Before City Council Regarding the Proposed Abandonment for September 9, 2013) 2. TEA/NAES Report (May) (Staff Recommends Acceptance of the Report) 3. Updates A. Green Energy Funding and Programming (Committee Action Not Required) B. National Pollution Discharge Elimination System (NPDES) Municipal Separate Storm Sewer Systems (MS4) Permit (Committee Action Not Required) C. Calpine Energy Center (Committee Action Not Required) D. Garrison Oak Technical Park Project (Committee Action Not Required) 4. Adjournment by 7:00 p.m. /tm S:\AGENDAS-MINUTES-PACKETS\Committee-Agendas\2013\08-12-2013 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: 7/26/2013 PREPARED BY: Sharon J. Duca, P.E., Public Works Director / City Engineer SUBJECT: Abandonment of Right-of-Way – Overlook Place 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 referenced portion of right-of-way shall be abandoned upon approval by City Council. RECOMMENDED ACTION: The following actions are recommended should the Committee be in favor: (1) Abandonment of the subject right-of-way with conveyance of twenty-five and one-half feet (25.5’) of said right-of-way to 125 and 126 Overlook Place, currently owned by Chu Pao Robinson and Michael P. Bouchard, 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 September 9, 2013. BACKGROUND AND ANALYSIS The City Clerk’s Office received a letter from Mr. Michael P. Bouchard, dated November 13, 2012, requesting that the unimproved portion of the Overlook Place right-of-way within the Overlook on Silver Lake subdivision be abandoned. This area extends approximately thirty feet (30’) from the eastern edge of public improvements within the right-of-way. Mr. Bouchard requested that this area be disposed in its entirety to his parcel, 126 Overlook Place. He stated that it is poorly maintained and that it would be a benefit to the community if this area was disposed to the property owners for proper maintenance. A letter was subsequently sent to the additional adjacent property owner to determine interest in participating in the abandonment and having a portion of the right-of-way conveyed to them. Both adjacent property owners have expressed interest in participating. The names of interested property owners and the addresses of their affected properties are as follows: Chu Pao Robinson 125 Overlook Place Michael P. Bouchard 126 Overlook Place Public Works staff has confirmed that this area is unimproved; however, public utility easements will be required for the existing water and wastewater infrastructure located therein. As per the plan, the right-of- way for Overlook Place is fifty-one feet (51’) wide. Half of the right-of-way, or twenty-five and one-half feet (25.5’), would be conveyed to the requesting parties. The Department of Public Works has no objection to the abandonment of the subject area of right-of-way. The Department recommends conveyance of twenty-five and one-half feet (25.5’) of said right-of-way to 125 and 126 Overlook Place in conjunction with the provision of a public utility easement for each parcel.

Overlook Place Proposed Right-of-Way Abandonment Ò ! § §Ò ! Rd r e po Le N nt . ! 0 po 0 5.0 8.0 -1 Du ! . -7 2 1 §Ò 65 9-0 . ! 3 1 ! 64 9-0 .0 × 0 8 §Ò Hw 80 . .0 06 ! 06 - 79 05 - y - 9 01 05 ED §Ò ED 63 09- ! 8. 80 .0 06 0 - 05 06 6 8. 35 00 ED 1. 09 0 !§Ò -0 - 8 × 1- 1.0 1 01 4 1 -7 63 09- 05 64 9-0 . - 68 82 0 ED . .00 .0 68 -0 0 -0 70 e 5 - nu 05 06 6 6.0 4 × 0 0 1 Ve 64 9-0 ED 8. 27 ED 0 09 2 1 -1 8.0 9.0 63 9-0 §Ò -0 06 6 01-6 Dr 1- .0 ! - 3 68 05 6 9- §Ò -0 05 ED 8.0 ! - 05 6 ED - - 0 05 ED 05 ED ED 0 6.0 5 1 -1 5- 12 9-0 ED0 5- 8.0 5- ED0 . §Ò 06 ED0 ED0 5- ! × 117 1-49.00 ! 115 1-50.00 113 1-51.00 09-0 §Ò 111 1-52.00 × 068. ! 09-0 09-0 09-0 068. . ! 068. 068. §Ò 614 ! . ! Pl 5- erlook ED0 Ov ! §Ò 5- ED0 126 1-48.00 . ! 5- ED05-068.09-01-17.00 ED0 124 1-47.00 09-0 5- 5- ED0 068. §Ò 5- ED0 122 1-46.00 ! ED0 09-0 068. ED05-068.09- 120 1-45.00 118 1-44.00 09-0 ED05-068.09- 116 1-43.00 09-0 068. 09-0 09-0 068. 068. 068. 114 112 01-42.00 01-41.00 .00 1-84 .09-0 D 05 -068 E 0 62.5 125 250 Feet ¯ Legend Date Printed: June 31, 2013 File: m:\gis_data\projects/tech_mxds §Ò ! Overhead Electric Pole × Hydrants . Manholes ! \st_abandonment_map Underground Electric Lines Sewer Line Department: Public Services GIS Overhead Electric Lines Dover Parcels City of Dover, Delaware Water Main Overlook Place Hydrant Line

The Energy Authority, Inc. Monthly Management Committee Update – May 2013 June 27, 2013 Prepared by: Robert Trinnear Client Services Manager 904.360.1309 rtrinnear@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 $668,296 under budget due to lower than budgeted cost of energy purchases. Dover’s budgeted cost for all power supply (capacity AND energy) was $93.66/MWh. The actual cost of all power supply (capacity AND energy) was $88.73/MWh. The cost of energy alone was $61.99/MWh, versus a budgeted energy cost of $70.51. Dover’s hedge purchases totaled 46,000 MWh, which was 75% of the projected load and 80% of the actual load. Dover’s power purchases from hedge transactions totaled $2,914,748. Purchases from PJM (energy and fees) totaled $950,863 with DA Energy purchases totaling $657,111 and Balancing Spot Market Energy totaling a credit of $228,205. Dover’s total load was 57,499 MWh versus a forecasted load of 61,609 MWh. Dover’s planned energy purchase from the SunPark solar installation was 2017 MWh. Dover’s actual energy purchase from the SunPark installation was 2226 MWh. 1

Supply Source Summary: Supply Variance: Budget Actual Variance Gross Load 61,609 57,499 4,110 Wholesale Load 59,592 55,273 4,319 Hedged Volume (MWh) 46,000 46,000 - Unhedged Volume (MWh) 13,592 9,273 4,319 Dover SunPark Volume (MWh) 2,017 2,226 (209) Renewable Energy Credits Volume 303 317 (14) Hedged Cost ($/MWh) $ 68 $ 63 $ 5 Unhedged Energy Cost ($/MWh) $ 75 $ 48 $ 27 Solar Energy Cost ($/MWh) $ 83 $ 86 $ (3) Energy Costs ($/MWh) $70.51 $61.99 $8.52 All-in Costs - Energy, Capacity and RECs ($/MWh) $93.66 $88.73 $4.93 2

B. Generation Summary: Dover generated 339.04 MWh in the month. Net generation revenue was $921,176 vs. a budget of $713,280. This delta was mainly due to lower than budgeted O&M costs. 3

Generation Breakdown: City of Dover's Wholesale Generation Net Generation Mwh 339.04 All In Generation Margin PJM Bill Energy $ 13,738.30 PJM Capacity $ 1,205,977.50 Black Start, Reactive Credit, DASR & EFORp $ 36,373.16 Gas Purchases $ (20,661.00) Oil Purchases $ - Transport / Cash Out $ (3,730.74) Gross Margin $ 1,231,697.22 Production Margin Generation Production Revenues (PJM) $ 13,738.30 Gas Purchases $ (20,661.00) Oil Purchases $ - Transport / Cash Out $ (3,730.74) Gross Production Margin $ (10,653.44) $ 3,632.85 $ (31.42) 4

C. Emissions Summary: Emissions Allowance Summary through May 31, 2013 CAIR EMISSION ALLOWANCE SUMMARY SO2 NOx Allowances1 Date Action Allowance Seasonal Annual s 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 10/4/2012 2013 Allocation 1,988 49 76 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) 12/31/12 2012 Emissions2 (1) (37) (37) Nov 2012 NOx Seas. Sales (DEMEC) (2) 2/13/2013 NOx Annual. Sales (DEMEC) (3) 5/31/2013 2013 Emissions 0 1 1 REMAINING ALLOWANCES 11,053 1113 189 On August 21, 2012, a three-judge panel of the U.S. District Court of Appeals (DCA) in Washington vacated EPA’s Cross State Air Pollution Rule (CSAPR) which would have become effective on January 1, 2012. The DCA instructed EPA to continue administering the Clean Air Interstate Rule (CAIR). EPA has appealed this ruling to the 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. 3 Seasonal NOx values are subject to verification by NAES. 5

U.S. Supreme Court, and the Court has agreed to review the DCA opinion. A ruling is not expected before June, 2014. Market liquidity for CAIR allowances continues to be low, with few transactions occurring. The following table shows estimated values for Dover’s banked allowances, based on broker bids & offers: Mark-to-Market for CAIR Allowances (6/24/2013) Commodity $/Ton Tons Extended Value (Bid/Offer Avg.) SO2 Allowances (2009) $ 1.35 3,050 $ 4,118 SO2 Allowances (2010-13) $2.20 8,003 17,613 NOx Allowances - Seasonal $18.00 1113 1,998 NOx Allowances - Annual $40.00 195 7,800 TOTAL $31,529 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 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 104,505 tons as of the end of Calendar year 2012, as shown in the table below. During January & February 2013, Dover’s generating units have not operated; therefore CO2 emissions have been zero. In March, 19 tons of emissions were recorded during a VanSant black-start test and in April, 105 ton were recorded during unit testing during the spring 2013 semi-annual maintenance outage. 6

CO2 Allowance Summary (5/31/2013) 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 2013 0 15,032 514 15,546 (412) 15,134 119,639 The table shows that the “Allocated CO2 Allowances” (column 5) are declining. After 2013, Dover will no longer receive allocations of RGGI allowances. The Cumulative Balance (column 8) – aka “Banked Allowances”) can be utilized for generation in future years (including 2013). 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. On February 7, 2013, RGGI proposed changes to its Model Rule. The proposed changes have been included in previous monthly reports. With the release of the Updated Model Rule, the RGGI states now plan to revise their CO2 Budget Trading Programs through their individual state-specific statutory and regulatory processes. Each RGGI state seeks to complete their state specific processes such that the proposed changes to the program would take effect on January 1, 2014. 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. The most recent RGGI auction occurred on June 7, 2013 and the auction cleared at $3.21/ton. RGGI futures settlement prices posted on Intercontinental Exchange (ICE) on June 24, 2013 ranged from $3.45 to $3.53/ton, averaging $3.49/ton. Based on the average ICE futures prices, the value of Dover’s existing RGGI allowance bank (119,639 tons) is approximately $417,540. 7

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. Dover also 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 April 2013, Dover has accumulated a total of 4,775 SRECS from these renewable energy resources. The nearest viable market for Dover’s SRECs is Pennsylvania. Pennsylvania’s March 2013 SREC auction cleared at $11/MWh. Using this price, Dover’s SRECs would have a market value of $52,525. TEA continues to recommend to Dover to retain these allowances for compliance with its Renewable Portfolio Standard which 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. 8

D. Operations Management Summary: During the month of May, there were no reportable or lost time accidents or injuries. The facility has now gone 960 days without an OSHA recordable accident and 960 consecutive days without a lost time reportable accident. There were zero Environmental Notices of Violations issued. There was one opacity deviation recorded at VanSant during a water wash of the turbine compressor. The unit was not combusting fuel at the time and the opacity reading was due to water vapor from the wash. There were no Near Miss incidents. In the month of May, no units were dispatched by PJM. All Units were in a planned outage starting March 4. Unit 3 was put on for test as a follow-up to repairs done during the outage. An over speed trip test was successfully performed on Unit 11. Work continued on the installation of the industrial waste water discharge system with the mechanical and electrical work essentially complete. Monthly Budget Variance - The actual expenses attributable to O&M of the two sites for the month of May were $310,521. The actual expenses are $217,757 or 41.22% under the approved budget of $528,278. The principal reason for the favorable variance was due to timing of expenses for labor (2 payrolls billed versus 3 payrolls budgeted), and electrical usage (invoices not booked in May). E. Risk Management Summary: Forward power prices in PJM are similar to last month. The blended cost has decreased for all years as natural gas prices have fallen during the month. The current projected cost of service is below: Blended Cost Power Year Hedge Ratio ($/MWh) 2012-13 81% $61.49 2013-14 62% $51.61 2014-15 38% $47.08 2015-16 14% $45.81 9

II. Budget Report Variance Report: Budget Actual Variance May-13 May-13 Gross Load 61,609 57,499 4,110 Power Supply Hedged Energy $3,143,362 $2,914,748 $228,614 PJM- Energy $1,019,955 $446,577 $573,378 PJM - Transmission and Fees $313,000 $504,286 ($191,286) Dover SUN Park Energy $180,874 $203,217 ($22,343) Management Fees $83,000 $83,000 $0 Capacity UCAP Obligated Purchased $1,029,954 $950,021 $79,933 Subtotal - Power Supply $5,770,145 $5,101,850 $668,296 Power Generation O&M & Fixed Fuel Plant O&M $528,278 $310,521 $217,757 Subtotal Generation O&M $528,278 $310,521 $217,757 Power Generation Production Margin Economic and reliability dispatch $0 ($13,738) $13,738 Fixed Fuel and Transport Charges $0 $24,392 ($24,392) Subtotal Generation Production Margin $0 $10,653 ($10,653) Power Generation Non-Production Revenue Generation Capacity Credit ($1,205,978) ($1,205,978) ($1) Emissions Allowance Sales $0 $0 $0 Black Start & Reactive Power Revenue ($35,580) ($36,373) $793 Subtotal - Non-Production Revenue ($1,241,558) ($1,242,351) $793 SubTotal - All Generation ($713,280) ($921,176) $207,896 Total - Utilities Cost $5,056,865 $4,180,673 $876,192 Unit Costs Total - Power Supply $93.66 $88.73 $4.93 Total - Power Generation ($11.58) ($16.02) $4.44 Final Cost of Service to City of Dover Ratepayers $82.08 $72.71 $9.37 10

Variance Analysis: Power Supply  Dover consumed 4,110 MWh less 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 below forecast.  The result of lower overall costs for more power was a net power supply cost of $88.73/MWh, $4.93/MWh lower than budget.  For the month, the city realized a favorable variance of $668,296 for power supply vs. the monthly budget.  Dover Sun Park generated 209 MWh more than forecast. Generation  Power generation had a favorable budget variance of $207,896.  Plant O&M expenses had a favorable budget variance of $217,757 for the month. 11

YTD Variance Report: Budget Actual Variance YTD YTD Gross Load 683,055 683,497 (442) Power Supply Hedged Energy $35,836,569 $34,701,034 $1,135,535 PJM- Energy $12,434,372 $7,124,623 $5,309,749 PJM - Transmission and Fees $3,443,000 $4,773,924 ($1,330,924) Dover SUN Park Energy $1,329,563 $1,438,537 ($108,974) Management Fees $913,000 $913,000 $0 Capacity UCAP Obligated Purchased $11,130,146 $10,268,605 $861,541 Subtotal - Power Supply $65,086,650 $59,219,724 $5,866,926 Power Generation O&M & Fixed Fuel Plant O&M $4,916,254 $4,720,333 $195,921 Subtotal Generation O&M $4,916,254 $4,720,333 $195,921 Power Generation Production Margin Economic and reliability dispatch ($1,124,312) ($1,882,864) $758,552 Fixed Fuel and Transport Charges $586,004 $982,644 ($396,640) Subtotal Generation Production Margin ($538,308) ($900,220) $361,912 Power Generation Non-Production Revenue Generation Capacity Credit ($13,032,341) ($13,032,337) ($4) Emissions Allowance Sales $0 $0 $0 Black Start & Reactive Power Revenue ($391,380) ($456,005) $64,625 Subtotal - Non-Production Revenue ($13,423,721) ($13,488,342) $64,621 SubTotal - All Generation ($9,045,775) ($9,668,229) $622,454 Total - Utilities Cost $56,040,875 $49,551,496 $6,489,379 Unit Costs Total - Power Supply $95.29 $86.64 $8.65 Total - Power Generation ($13.24) ($14.15) $0.90 Final Cost of Service to City of Dover Ratepayers $82.04 $72.50 $9.55 12

III. Operations Management NAES Corporation Dover, Delaware May 2013 Monthly Report Chuck Luton (right), IC&E Technician, accepts the NAES Service Recognition Award presented by Vince Scire, Plant Manager, in recognition of completing 5 years of service working at the City of Dover Generating Facilities. 13

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 14

1.0 Environmental, Health and Safety: During the month of May, there were no restricted work days or lost time accidents. The facility has now gone two years, seven months and seventeen days (960 days) through May 31, 2013 without an OSHA Recordable Accident or a Lost Time Reportable Accident. The plant received no Notice of Violations (NOVs) during the month. The May (April Discharge) DMR was submitted for the McKee Run site with no NPDES exceedences. Shakedown of the Industrial Wastewater Project is in-progress with final system adjustments being made. Project completion is anticipated for June 2013. An Opacity deviation was recorded on Unit 11 during a compressor water wash operation during the month of May (5/30/2013). The unit was not combusting fuel at the time and the opacity reading was due to water vapor from the wash. Per the Title V permit conditions, DNREC was notified via fax and mail in the allotted timeframe. No further action is anticipated on the part of the facility or DNREC. OSHA 16 hour Asbestos Operations & Maintenance training was held at the facility for selected Operations, Maintenance, and Management personnel. Environmental, Health, and Safety Statistics Month Fiscal Year to Date (May) (7/1/12-5/30/13) NOVs 0 0 Opacity Deviations 1 1 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 4,670.50 51,073.5 Date last OSHA Recordable 10/14/10 Date last Lost Time Accident 10/14/10 Days since last OSHA recordable 959 Days since last Lost Time Accident 959 15

Emissions (NOx & SO2) All data thru 5/31/13 NOx Summary – Ozone Season (May-Sep) Tons Year Unit #1 Unit #2 Unit #3 Unit #11 TOTAL 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 2013 0.0 0.0 0.6 0.0 0.6 NOx Summary - Year (Jan-Dec) Tons Year Unit #1 Unit #2 Unit #3 Unit #11 TOTAL 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 2013 0.0 0.0 0.7 0.0 0.7 SO2 Summary - Year (Jan-Dec) Tons Year Unit #1 Unit #2 Unit #3 Unit #11 TOTAL 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 2013 0.0 0.0 0.0 0.0 0.0 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 15,032 514 412 15,134 Note: All CO2 allowance values are provided by the RGGI CO2 Allowance Tracking System. 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* 2013 0 1850 138 0 1988* *Note – Emissions allowances are deducted according to oldest vintage first or unless otherwise directed. 16

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 3*** 27/0 0/2 earlier 2011 0 77/48 5/3 33/31– 3/1 0/0 - 0/0 42/10 2/2 2012 2** 75/46 5/3 36/36 – 1/1 0/0 - 0/0 39/10 4/2 2013 0 77/48 5/3 1/1 – 0/0 0/0 - 0/0 76/47 5/3 *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. ***Note- The facility transferred Annual allowances to a third party 17

2.0 Financial Financial – Current Month Month – MAY Actual Budget Variance Personnel 236,700 362,664 125,964 Materials & Supplies 6,401 11,890 5,489 Administrative Expenses 67,420 153,724 86,304 Total $310,521 $528,278 217,757 Financial – Fiscal Year to Date Number of Months – 11 Actual Budget Variance Personnel 2,849,937 2,935,561 85,624 Materials & Supplies 177,895 200,860 22,965 Administrative Expenses 1,692,499 1,779,833 87,344 Total $4,719,358 $4,916,254 196,896 2.1 Variance analysis: The City of Dover Finance Department has closed the books for the month of May 2013. The expenses for May are $310,521 against a budgeted amount of $528,278 for a favorable variance of $217,757 or ≈ 41.22%. The variance was due to the following: PERSONNEL EXPENSES – A favorable monthly variance of $125,964 was due to having two (2) payroll periods billed versus the three (3) that had been originally budgeted for May. Included in these costs are straight time labor, overtime labor, and labor burdens. MATERIALS AND SUPPLIES EXPENSES- A favorable monthly variance of $5,489 was due primarily to lower water/sewer costs and the deferral of the mobile crane inspection that was budgeted for this month. ADMINISTRATIVE EXPENSES – A favorable monthly variance of $86,304 was due primarily to no monthly electric usage invoices being booked (timing) in month of May. In addition, there were insulation repairs and air compressor maintenance kits that weren’t needed this fiscal year. The budget is currently forecasted to finish this fiscal year at $5,813,929 expensed versus an approved budget of $5,914,900 thereby realizing a 98.29% expenditure rate. 18

3.0 Operations Unit Operations / Outages / Trips For the entire month of May, all units were in the spring outage. On May 2, plant staff tested Unit 3 boiler and turbine as a follow up to repairs/inspections performed on the equipment earlier in the outage. The unit was on line for approximately thirty minutes before it was taken off line to address turbine oil system leaks and to correct poor connections on the fuses in the PT compartment. On May 7, Unit 3 was again brought on line to continue testing of the turbine and the boiler. During the startup process, the unit experienced a high turbine oil temperature of 140 degrees at which point, the unit was tripped offline. It was discovered that the impeller on one of the Unit 3 Cooling Water Pump’s impellers had failed. The unit was brought back on line and completed testing that day. On May 30, a water wash of the compressor section of Unit 11 was performed after which a successful over speed trip test of the unit was completed. Month May 2013 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 0.0 0.0 7.883 7.883 0.0 7.883 Starts # 0 0 3 3 0 3 Gross Generation MWh 0.0 0.0 378.152 378.152 0.0 378.152 Net Generation MWh 0.0 0.0 342.894 342.894 0.0 342.894 Total Auxiliaries MWh 21.529 21.529 226.911 269.968 2.845 272.813 Auxiliaries purchased MWh 21.529 21.529 191.653 234.710 2.845 237.555 Fuel Gas Used MMBTU 0.0 0.0 4,767.553 4,767.553 109.678 4,877.232 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 0.0 0.0 4,767.553 4,767.553 109.678 4,877.232 Net Heat Rate BTU/KWh 0 0 13.904 13.904 0 13.904 Unit Trips # 0 0 1 1 0 1 Capacity Factor % 0.0 0.0 0.45 0.45 0.0 0.45 Availability Factor % 0.00 0.00 0.00 0.00 0.00 0.00 Commercial % 0 0 0 0 0 0 Unavailability (CU) Planned Outage Hours Hours 744.000 744.000 744.000 2,232.000 720.000 2,976.000 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 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. 19

2012-2013 Fiscal Year-to-Date - May 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 71.970 298.013 466.265 22.699 488.964 Starts # 3 2 30 35 5 40 Gross Generation MWh 668.79 582.202 19,258.400 20,509.392 714.904 21,224.296 Net Generation MWh 628.855 541.673 17,728.618 18,899.146 714.287 19,613.433 Total Auxiliaries MWh 340.587 341.180 3,410.813 4,092.579 37.876 4,130.455 Auxiliaries purchased MWh 300.652 300.652 1,881.031 2,482.334 37.345 2,519.679 Fuel Gas Used MMBTU 9,483 8,108 205,542.399 223,133.399 8,642.270 231,776 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, 205,542.399 223,133.399 8,642.270 231,776 Net Heat Rate BTU/KWh 15,021 14,970 12.041 14.010 12,604 13,704 Unit Trips # 0 0 2 2 0 2 Capacity Factor % 0.44 0.40 2.17 1.73 0.23 1.40 Availability Factor % 54.50 54.50 54.65 54.55 54.50 54.54 Commercial % 0 0 0 0 0 0 Unavailability (CU) Planned Outage Hours Hours 3,641 3,641 3,641 10,923 3,641 14,564 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 4,306.218 4,327.030 4,113.570 12,746.818 4,376.934 17,123.752 Hours HW Boiler Gas Usage MMBTU 2,560.313 2,560.313 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) 450,319 452,963 0 2,644 454,725 0 (1,762) VanSant 144,827 145,796 0 969 152,150 0 (6,354) (#2 Fuel Oil) Note: As measured by tank level instruments. Tank levels may change due to oil temperature. VanSant Lifetime through 5/31//13 Actual Starts Factored Starts Fired Hours VanSant 1308 2,238.75 4,219.80 Since HGP - Dec 2004 232 571.05 836.22 20

Team Report: The Operations staff continues to support maintenance activities during the planned outage by serving as Confined Space Attendants for confined space areas as well as other support tasks. The Operations staff has also supported the outage by performing various LOTO tasks needed to test or place equipment in or out or service. 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 the Operations and Maintenance areas to help in maintaining the plant. The Operations staff has been continuing their work on painting the fuel lines as most all of the insulation has been removed. Capacity Testing – FY 2012-2013 Summer 2012 (June 1- Aug 31) Winter 2012-2013 (Dec 1- Feb 28) Unit Rated Net Reported Net Unit Rated Net Reported Net Capability (MW) Capability (MW) Capability (MW) Capability (MW) 1 17 17.0 1 17 17* 2 17 17.3 2 17 17* 3 102 102.7 3 102 102* VanSant 39 39.0 11 39 39* Total 175 176.0 Total 175 175* Note: * Denotes Unit is qualified for the PJM Winter Demonstration Period Exemption Program and data has been submitted into the PJM eGADS 21

4.0 Maintenance During the month of May, the Plant Maintenance staff continued addressing the backlog of work orders and completing outage activities. There were fifteen work orders issued with ninety-two 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 May - 2013 Outstanding From Outstanding Previous Issued This Completed at the end of Priority # Month Month This Month the month 1 14 3 7 10 2 54 8 30 32 3 40 4 7 37 4 6 0 0 6 5 16 0 3 13 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 71 0 45 26 Totals 201 15 92 124 Note: PMs are included in the priority totals Notable activities during the month include:  The NAES Maintenance and Operations staff completed a gas purge on the gas skid at VanSant. This was completed to facilitate the changing a defective natural gas condensate dump valve. The gas condensate valve was installed and tested for proper operation.  The NAES Mechanics, IC&E Technicians and selected operations staff attended asbestos training. The staff was trained on the proper procedures in using a glove bag to remove gaskets from flanges or packing from valve that contain asbestos.  The NAES IC&E and Operations staff assisted in the testing of the Industrial Waste Water system. There were a few wiring and instrumentation issues during start up that needed to be addressed. These items were repaired and/or changed. There are still a few minor issues with the program logic pertaining to the overall system operation that will be taken care of in the near future. 22

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. Completion at 90%. Minor work is in process of being completed with an Unit #3 Boiler EG1202 expected completion date in the June time period. Systems Schedule: Tube repairs are complete and the ductwork has been repaired. Unit was operated and no more problems encountered. Progress: Work scheduled for the Spring 2013 outage. Completion at 90%. Minor work is in process of being completed with an Unit 3 Auxiliary EG1203 expected completion date in the June time period. System Components Schedule: Scheduled work is on track for completion by end of Spring 2013 outage. Progress: Plant staff working with OEM to determine long lead material requirements. Schedule: Long lead items will be procured Unit 3 Turbine EG1212 in the spring of 2013. Some turbine parts (turbine 9th stage blades) Repairs have been ordered and received. List of consumables is being finalized and quotes requested thereafter. Progress: Work on hold for present time. Units 1 & 2 EG1304 Schedule: Work on hold for present time. Components Repairs Turbine Level Progress: Feedback from insurance company revealed that this EG1306 Window recommendation will be withdrawn. modification Schedule: Work complete. Progress: Material has been purchased, delivered ,and has been Unit 3 Air Heater installed EG1112 Expansion Joint Schedule: Work was completed in November. Project will be closed. 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 quarter FY13 with bids and revised installation costs identified. Actual repair work will be scheduled for fiscal 2015. EG1310 Units 1&2 Stack Progress: The FY2013 work scope package being developed. 23

Repairs Schedule: Work to be completed during the spring outage or deferred until 2015. Inspection was completed in November and report is forthcoming so scoping documents may be developed. Progress: Valuation of the benefits of various technologies has been completed and TEA is recommending implementation of the Wet Compression Technology at an approximate cost of $1.5M. Plant VanSant Capacity EG1311 staff to develop cost schedule and COD Management to bring Increase forward to COD Council for decision on the project. Schedule: COD Management Team to work on approval of project going forward. Progress: Contract work was awarded and vendor has completed Unit 3 Generator work. Unit has been tested for proper operation. Air leak test and oil EG1312 Repairs flush completed prior to start-up. Schedule: Operational check of the unit completed. Progress: Mechanical and electrical installation work has been started. Mechanical work is 95% complete and electrical work is MR Industrial Waste EG1214 75%. water System Schedule: Installation work slated for completion in May with testing of system to commence immediately thereafter. Unit 1 Gland Steam Progress: NA EG1301 Schedule: Work is complete. Seal Repair 24

6.0 General Plant Information  TEA has evaluated the findings of the McHale and Associates Report (Capacity upgrade opportunities for VanSant) and has imported the data into their financial model. From this, TEA developed a presentation that was presented at the March COD/TEA/NAES Management Meeting in which they recommended implementation of the Wet Compression Technology with an estimated cost of $1.5 million dollars. A number of action items were also identified that need to be followed up by NAES and by TEA including updating the project CIP costing and having a discussion with the DNREC regarding the effect the power increase could have on emissions. Included in the action item list was a breakdown of project costs and time frame when those costs would be expected to be expensed.  Plant staff is working to complete as many of the remaining outages tasks as possible prior to the end of the outage. Some of the work will be able to be completed when the units come out of the outage. Only a few minor tasks, if any, will need to be deferred until a later date. Training:  Chuck Luton was recognized for completing five years of service with NAES at the Dover Facility.  Topics discussed during the monthly safety committee meeting were reviewed by the entire staff. The monthly safety topic was on “Heat Stress”. Topics discussed during the monthly safety committee meeting were reviewed by the entire staff.  Plant employees continue using the 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 as well. 25

Calendar of Events Date 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 Units 1, 2, 3 and 11 Fall Outage TBD Three Year Accident Free October 14, 2013 Winter Capacity Period December 1, 2013 to February 28, 2014 EIA-860 Report February 28, 2014 EIA-923 Report February 28, 2014 NOx Emissions Reconciliation Due March 1, 2014 SO2 Emissions Reconciliation Due March 1, 2014 SARA III Report March 1, 2014 NPDES Permit Renewal Due March 4, 2014 Units 1, 2, and 3 Spring Outage March , 2014 – June , 2014 Unit 11 Spring Outage March , 2014 – June , 2014 Annual VanSant Black Start Test March , 2014 Air Emission Inventory March , 2014 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: All units have successfully completed the PJM Summer Capacity Tests and are qualified for entry into the PJM Winter Capacity Test Exemption Program*. The YTD Incentive calculation reflects this information. 26

IV. Appendix – PJM Invoice Breakdown Gen Load Grand Total Auction Revenue Rights $ (1,117.24) $ (1,117.24) Balancing Operating Reserve $ 25,877.62 $ 25,877.62 Balancing Spot Market Energy $ (17,095.97) $ (228,205.33) $ (245,301.30) Balancing Transmission Congestion $ 3,394.95 $ (9,046.60) $ (5,651.65) Balancing Transmission Losses $ (37.28) $ 889.04 $ 851.76 Black Start Service $ (6,905.58) $ 1,905.49 $ (5,000.09) Capacity Resource Deficiency $ (526.27) $ (526.27) Capacity Transfer Rights $ (33,318.18) $ (33,318.18) Day-ahead Operating Reserve $ 9,109.26 $ 9,109.26 Day-ahead Scheduling Reserve $ 987.39 $ 987.39 Day-ahead Spot Market Energy $ 657,110.51 $ 657,110.51 Day-ahead Transmission Congestion $ (58,341.43) $ (58,341.43) Day-ahead Transmission Losses $ 49,183.72 $ 49,183.72 Expansion Cost Recovery $ 427.49 $ 427.49 FERC Annual Recovery $ 3,354.71 $ 3,354.71 Generation Deactivation Refund $ (758.35) $ (758.35) Inadvertent Interchange $ (282.01) $ (282.01) Load Management Test Failure $ (199.95) $ (199.95) Load Reconciliation for Balancing Operating Reserve $ 19.17 $ 19.17 Load Reconciliation for FERC Annual Recovery $ 53.04 $ 53.04 Load Reconciliation for Inadvertent Interchange $ (2.30) $ (2.30) Load Reconciliation for Market Monitoring Unit (MMU) Funding $ 3.39 $ 3.39 Load Reconciliation for North American Electric Reliability Corporation (NERC) $ 8.91 $ 8.91 Load Reconciliation for PJM Scheduling, System Control and Dispatch Service $ 184.07 $ 184.07 Load Reconciliation for Reactive Services $ 1,593.34 $ 1,593.34 Load Reconciliation for Regulation and Frequency Response Service $ 251.22 $ 251.22 Load Reconciliation for Reliability First Corporation (RFC) $ 12.75 $ 12.75 Load Reconciliation for Schedule 9-6 - Advanced Second Control Center $ 22.97 $ 22.97 Load Reconciliation for Spot Market Energy $ 35,928.70 $ 35,928.70 Load Reconciliation for Synchronized Reserve $ 198.23 $ 198.23 Load Reconciliation for Transmission Congestion $ (477.62) $ (477.62) Load Reconciliation for Transmission Losses $ 1,220.95 $ 1,220.95 Load Reconciliation for Transmission Owner Scheduling, System Control and Dispatch Service $ 66.23 $ 66.23 Locational Reliability $ 984,894.18 $ 984,894.18 Market Monitoring Unit (MMU) Funding $ 220.89 $ 220.89 Meter Error Correction $ (5,225.34) $ (5,225.34) Network Integration Transmission Service $ 292,797.79 $ 292,797.79 Non-Firm Point-to-Point Transmission Service $ (379.34) $ (379.34) North American Electric Reliability Corporation (NERC) $ 563.80 $ 563.80 Organization of PJM States, Inc. (OPSI) Funding $ 38.92 $ 38.92 PJM Scheduling, System Control and Dispatch Service - Advanced Second Control Center $ 1,743.65 $ 1,743.65 PJM Scheduling, System Control and Dispatch Service - Capacity Resource/Obligation Mgmt. $ 948.91 $ 948.91 PJM Scheduling, System Control and Dispatch Service - Control Area Administration $ 9,539.81 $ 9,539.81 PJM Scheduling, System Control and Dispatch Service - Market Support $ 2,171.15 $ 2,171.15 PJM Scheduling, System Control and Dispatch Service - Market Support Offset $ (300.62) $ (300.62) PJM Scheduling, System Control and Dispatch Service - Regulation Market Administration $ 88.52 $ 88.52 PJM Scheduling, System Control and Dispatch Service Refund - Capacity Resource/Obligation Mgmt. $ (24.18) $ (24.18) PJM Scheduling, System Control and Dispatch Service Refund - Control Area Administration $ (270.63) $ (270.63) PJM Scheduling, System Control and Dispatch Service Refund - Market Support $ (63.36) $ (63.36) PJM Scheduling, System Control and Dispatch Service Refund - Regulation Market Administration $ (3.12) $ (3.12) PJM Settlement, Inc. $ 300.62 $ 300.62 Reactive Services $ 91,608.55 $ 91,608.55 Reactive Supply and Voltage Control from Generation and Other Sources Service $ (29,467.58) $ 34,906.05 $ 5,438.47 Regulation and Frequency Response Service $ 15,231.75 $ 15,231.75 Reliability First Corporation (RFC) $ 806.27 $ 806.27 RPM Auction $ (1,205,977.50) $ (1,205,977.50) Synchronized Reserve $ 3,441.27 $ 3,441.27 Synchronous Condensing $ 0.71 $ 0.71 Transmission Enhancement $ 23,052.94 $ 23,052.94 Transmission Losses $ (14,961.25) $ (14,961.25) Transmission Owner Scheduling, System Control and Dispatch Service $ 4,189.16 $ 4,189.16 Balancing Operating Reserve for Load Response $ (1.67) $ (1.67) Load Reconciliation for Organization of PJM States, Inc. (OPSI) Funding $ 0.62 $ 0.62 Load Reconciliation for Day-ahead Scheduling Reserve $ 1.02 $ 1.02 Demand Resource and ILR Compliance Penalty $ (95.79) $ (95.79) Day-Ahead Load Response Charge Allocation $ 232.75 $ 232.75 Real-Time Load Response Charge Allocation $ 56.21 $ 56.21 Incremental Capacity Transfer Rights $ (1,028.27) $ (1,028.27) Michigan - Ontario Interface Phase Angle Regulators $ 188.73 $ 188.73 Non-Synchronized Reserve $ 76.94 $ 76.94 CT Lost Opportunity Cost Allocation $ (10.23) $ (10.23) Load Reconciliation for Non-Synchronized Reserve $ 13.94 $ 13.94 Grand Total $ (1,256,088.96) $ 1,900,884.27 $ 644,795.31 27

FUND SUMMARY as of 07/23/2013 Total Collected $ 919,288.77 DEMEC Admin Fee Paid $ 45,122.76 State Admin Fee Paid $ 22,292.26 Total Grant Dollars Paid $ 676,983.32 Customer Only Grants/Fees Reserved and Amount Owed $ 14,035.31 Community Project Funds Requested - Dov. Lib - Requested $ 415,317.00 Community Project Funds Requested - Dov. Lib -Still Owed $ 214,908.68 Energy Depot Fees Paid $ 45,056.86 Efficiency Program Dollars Paid $ 34,068.34 Solar Electric Power Association (SEPA) Fee $ 4,317.61 *Unencumbered Funds Available $ 37,588.51 Funding Shortfall Current Grant Payment Delay (Months) 0.0 * As of 07/23/2013 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 ** Library Geo - Comm $ 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 $ 4,400.00 $ 303.75 $ 26.25 8/15/2012 Chong S. Tamburo-Lepage Geo - Res $ 2,300.00 $ 172.50 $ - 12/5/2012 City of Dover ** Library Geo - Comm $ 152,141.32 $ - $ - 12/19/2012 Christopher W. Los Geo - Res $ 3,000.00 $ 225.00 $ - 1/30/2013 Matthew and Kimberly Chesser Geo - Res $ 3,000.00 $ 225.00 $ - 2/25/2013 Dennis Ho Solar - Res $ 6,775.00 $ 508.13 $ - 6/28/2013 John DeMarie Geo - Res $ 3,000.00 $ - $225.00 Total $ 676,983.32 $ 22,292.26 $ 288.75 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 James and Corinna Fritsch Solar - PV - Res $ 5,287.50 $ 396.56 Reservation Approved - Pending Completion James and Deri Austin Solar - PV - Res $ 7,500.00 $ 562.50 Total $ 12,787.50 $ 959.06 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 11/30/2012 Dec 12, Jan, Feb 2013 $ 1,692.13 2/25/2013 Mar, Apr, May 2013 $ 1,692.13 7/22/2013 June, July, Aug 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 Conserve. 1/4/2011 Calendars $ 20,015.81 Total $ 34,068.34 Dover Library Community Grant Request - $ 415,317.00 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 $ 5,513.86 1/2 of Dec 2012 GEF Payment $ 5,187.25 1/2 of Jan 2013 GEF Payment $ 5,307.83 1/2 of Feb 2013 GEF Payment $ 4,783.25 1/2 of March 2013 GEF Payment $ 4,903.40 1/2 of April 2013 GEF Payment $ 4,673.21 1/2 of May 2013 GEF Payment $ 5,322.04 1/2 of June 2013 GEF Payment $ 240,232.12 Total Collections Total Dover Library Grant Payment Draws to Date $ 48,267.00 10/17/2011 $ 152,141.32 12/5/2012 Total Dover Library Grant Dollars to be Paid $ 214,908.68 Library Funds Available for Draw $ 39,823.80 Total Library Grant Uncollected Funds Still Needed $ 175,084.88