PJM Generator Interconnection #P11 Kewanee 138 kv. Facilities Study Report

Transcription

1 PJM Generator Interconnection #P11 Kewanee 138 kv Facilities Study Report Revised April 14, 2011 Docs #594165v3 Page 1

2 A. FACILITIES STUDY INTRODUCTION 1. PROJECT DESCRIPTION The developer, Bishop Hill, LLC (Interconnection Customer) has proposed the construction and interconnection of the TSS 943 Bishop Hill wind farm generation consisting of 200MW of wind generation with 20% (40MW) capacity. This proposed wind farm located near the town of Bishop Hill in Henry County, Illinois, will interconnect with ComEd 138kV TSS 74 Kewanee substation and consist of an approximately twenty eight (28) mile 138kV generator lead and 134 (one hundred thirty four), 1.5MW GE SLE wind turbine generators. The wind farm will be interconnected to the 138kV South Transfer Bus (S. T-Bus) of TSS 74 Kewanee substation which will be redesignated as Bus #2, utilizing old L.0324 breaker position, as shown in Attachment #1. 2. AMENDMENTS TO THE IMPACT STUDY DATA OR IMPACT STUDY RESULTS 2.1 Replacement of overdutied circuit breaker of 138kV L.7411 at TSS 74 Kewanee substation The impact study indicates the replacement of overdutied circuit breaker of 138kV L.7411 at TSS 74 Kewanee substation as it is rated to interrupting capacity of 13.6kA. It has been verified by ComEd in the field that the existing circuit breaker is rated for interrupting capacity of 5000MVA and is not required to be replaced. 2.2 Change of line number The impact study report describes the replacement of 138kV L.7408 circuit breaker at TSS 74 Kewanee substation assuming completion of project #O29. In this facility study report, the completion of project #O29 is not assumed complete and therefore, L is still identified as L at TSS 74 Kewanee. 2.3 Impact on MISO The results of a cross border study are attached as Attachment 2. In addition to upgrades identified in this report, an upgrade to the Ameren owned portion of the Kewanee bus tie (CB 105 and associated disconnect switches) will be required. The ComEd-owned Kewanee 138kV Main Bus to the Ameren Illinois-owned Kewanee 138kV circuit breaker #105 and series equipment loads to MVA for the Line fault with breaker failure at Nelson. Ameren Illinois reports their ratings for this tie as 275MVA normal and 287 MVA emergency. The proposed upgrade will result in a rating of 478 MVA normal and emergency due to switches. This upgrade will be required upon the Initial Operation of all three of the following PJM Queued Projects: O09, O29, and P11. Subsequently queued projects that also contribute to this overload are P37, Q39, and Q60. Ameren has requested a Facilities Study for this work, and PJM will coordinate with the IC, Ameren, and the Midwest ISO in accordance with paragraph of the Joint Operating Agreement. See Attachment 6 for additional details. Upon completion of the Facilities Study, the IC shall execute, potentially with other parties contributing to these same overloads, an Upgrade Construction Service Agreement or similar document with the Affected System Operator in accord with paragraph of the PJM Open Access Transmission Tariff. The financial responsibility of each project towards each upgrade identified in Attachment 2 assumes all of the identified contributors remain in the queue. If any should withdraw, the allocation to the remainder, as well as the need for the upgrade itself will be reevaluated. 2.4 Stability Study & Low Voltage Ride Through Report Page 2

3 No stability issues have been identified and the proposed installation is in compliance with the low voltage ride through requirements in accordance with FERC Order 661-A. See Siemens PTI Report No. R26-09 for additional information. 2.5 The voltage collapse condition resulting from a fault on 138kV line with a failed breaker at Nelson TSS 155 identified in the Impact Study can be mitigated by the installation of GE WindControl controls. The installation of a series breaker in the Line at Nelson is not required. 3. INTERCONNECTION CUSTOMER SCHEDULE IC has envisioned the construction of 200MW wind farm by spring 2012: Description Start of construction Started Start of turbine delivery September 2011 Substation energization November 2011 Commercial Operation June 1, SCOPE OF WORK BY INTERCONNECTION CUSTOMER (IC) Schedule 4.1 The IC will be responsible for performing design, construction, and operation of all facilities on the IC side of the Point of Interconnection as shown in Attachment #1. The IC will meet all the requirements of protective relaying per design E of most recent version of Guidelines for the Interconnection of Generation to the EED System. 4.2 The IC will be responsible for performing design, procurement, and construction of a twenty eight (28) mile long 138kV generator lead L to the point of interconnection at substation dead end structure at TSS 74 Kewanee substation, as shown in Attachment #1. The IC must provide two (2) physically diverse fiber optic routes to TSS 74 Kewanee for protective relay communication purposes. 4.3 The IC will be responsible for performing design, procurement, and construction of the 200MW wind farm, which includes the generator step-up transformers (GSU s), collection system, two (2) main transformers, and three (3) 138kV breakers. 4.4 The IC will be responsible for purchasing real estate or obtaining the necessary right-ofway to install 138kV generator lead L The IC and ComEd have mutually agreed that the IC will be responsible for the design engineering and procurement of long lead time materials for the Transmission Owner facilities/modifications described in Sections A5 and B4 below. 4.6 PJM Requirements: The IC will be required to install equipment necessary to provide Revenue Metering (kwh, kvarh) and real time data (kw, kvar) for interconnection customer s generating resource. See PJM Manuals M-01 & M-14D, and PJM tariff. 5. DESCRIPTION OF FACILITIES INCLUDED IN THE FACILITIES STUDY 5.1 TSS 74 Kewanee Substation ComEd will be responsible for the construction for the following: Installation of new SF6 gas circuit breaker, motor operated disconnect switches, revenue metering unit, CCVTs, wave trap, and dead end structure for 138kV L.94301, as shown in Attachment #1 and #5 (Attachment Facilities--PJM upgrade #N1992) Removal of existing dual disconnect switch located between 138kV Main BUS and South Transfer BUS installed for old L.0324 (Attachment Facilities--PJM upgrade #N1992) Page 3

4 5.1.3 Removal of old L.0324 disconnect switch and circuit breaker foundations and installation of new foundations and structures for new equipment (Attachment Facilities--PJM upgrade #N1992) Installation of two current differential relay protection schemes on 138kV L.94301(Non-direct connect PJM Network Upgrade n1992) Installation of 138kV T-Bus differential protection scheme (Non-direct connect PJM Network Upgrade n2114) Evaluation of the adequacy of existing batteries and battery chargers due to new microprocessor relays and communication equipment. (Non-direct connect PJM Network Upgrade n2114) Replacement of three (3) existing 138kV circuit breakers, L.6101, L.15508, and L.7423, with new 138kV, 2000 Amp, 40kA gas circuit breakers.( Non-direct connect PJM Network Upgrades n0846, n0847, and n0848) Replacement of three (3) existing bus side dual disconnect switches, L.6101, L.15508, and L.7423, with new 138kV, motor operated disconnect switches. Analyze structures for new disconnect switch load capacity. (Non-direct connect PJM Network Upgrades n0846, n0847, and n0848) Replacement of three (3) existing line side disconnect switches, L.6101, L.15508, and L.7423, with new 138kV, motor operated disconnect switches. Analyze structures for new disconnect switch load capacity. (Non-direct connect PJM Network Upgrade n0846, n0847, and n0848) Remove ability of five (5) existing line side disconnect switches, of L.6101, L.15508, L.7423, L7413, and L.7411 to close from normally open position. (Detail engineering to determine if only blade or entire switch is to be removed). (Non-direct connect PJM Network Upgrade n2114) Remove ability of (3) existing bus side dual disconnect switches, of L.7421, L7413, and L.7411 to close from normally open position. (Detail engineering to determine if only blade or entire switch is to be removed) (Non-direct connect PJM Network Upgrade n2114) Modifiy breaker failure relay circuits on 138kV L7411, L7413, and L7421 breakers. (Non-direct connect PJM Network Upgrade n1993) Upgrade existing communication equipment on L (Non-direct connect PJM Network Upgrade n2114) Upgrade existing 250VDC negative-tripping circuits to 250VDC positivetripping circuits on 138kV L.6101, L.15508, and L ( Non-direct connect PJM Network Upgrades n0846, n0847, and n0848) Upgrade existing 350 MCM copper to 1113 KCmil ACSR between 138kV Main Bus and demarcation point with AmerenIP.(Non-direct connect PJM Network Upgrade n0849) Installation of equipment necessary to provide bi-directional revenue metering (kwh, kvarh) and real time data (kw, kvar, circuit breaker status and 138kV voltage) for IC s generating resource. See ComEd applicable standards available on the PJM website (TO Standards). (Non-direct connect PJM Network Upgrade n1992). 6. TOTAL COSTS OF TRANSMISSION OWNER FACILITIES INCLUDED IN FACILITY STUDY The estimated cost for material and labor for the facilities of #P11 project needed for ComEd portion for network upgrade is $3,848,983 Page 4

5 NETWORK # SITE LOCATION TOTAL PROJECT COST N1992 Install New 138kV L Circuit Breaker & Associated Equipment at TSS $2,147, Kewanee Substation n kV L.6101 Circuit Breaker Replacement at TSS 74 Kewanee Substation $467,114 n kV L Circuit Breaker Replacement at TSS 74 Kewanee Substation $445,003 n kV L.7423 Circuit Breaker Replacement at TSS 74 Kewanee Substation $471,073 N kV L.7411, L.7413 and L.7421 Relay Upgrade at TSS 74 Kewanee $36,340 Substation N0849 Upgrade station conductor between 138kV Main Bus and demarcation point $31,144 with AmerenIP at TSS 74 Kewanee Substation N2114 Reconfigure 138kV Main/Transfer Bus and install differential relays $250,460 Total Cost of ComEd Work $3,848, SUMMARY OF MILESTONE SCHEDULES FOR COMPLETION OF WORK INCLUDED IN FACILITY STUDY Description Schedule Start Finish Prepare Project Diagram & Specifications Project Design November 2010 May 2011 Material Procurement January 2011 February 2012 Substation Construction Work at TSS 74 July 2011 April 2012 Acceptance Testing L94301 TSS74 October 2011 November 2011 Commissioning/In Service Full Capacity April 2012 May 2012 B. TRANSMISSION OWNER (ComEd) FACILITIES STUDY RESULTS 1. TRANSMISSION LINES - NEW 1.1 The Interconnection Customer is responsible for performing design, procurement, and construction of an approximately twenty-eight (28) mile 138kV generator lead L to the point of interconnection at substation dead end structure of TSS 74 Kewanee substation as shown in attachment #1. 2. TRANSMISSION LINES UPGRADES 2.1 Not applicable. 3. NEW SUBSTATION / SWITCHYARD FACILITIES 3.1 Not applicable. 4. UPGRADES TO EXISTING SUBSTATION / SWITCHYARD FACILITIES Purpose and Necessity: ComEd will be responsible for procurement of other than long lead time equipment, and construction activities to tap new 138kV L to the point of interconnection at substation dead end structure, replacement of existing circuit breakers and upgrade existing protection relays, SCADA and communication equipment to protect 138kV L.6101, L.15508, and L.7423 at TSS 74 Kewanee substation as indicated in one line diagram per attachment #1. Page 5

6 Long lead time equipment that the IC is responsible for providing includes: 138kV SF6 breakers, motor operated disconnect switches, motor operators, metering current transformers & metering set, support steel structures, CCVT's, wavetraps, tuners, terminal A-frames, surge arresters, insulators, line relay panels, breaker relay panels, communication panel and equipment, scada panels and equipment, and relay devices. 4.1 TSS 74 Kewanee Substation Install new dead end structure and foundations for 138kV L per ComEd EM Install new 138kV, 3000Amp, 40kA SF6 gas circuit breaker on new foundations with associated conduit and grounding for 138kV L Install new 138kV motor operated disconnect switch on both the sides of 138kV SF6 gas circuit breaker and connect bus side disconnect switch directly to 138kV South Transfer Bus (S. T-Bus). Install new foundations with associated conduit and grounding on both sides of 138kV L SF6 gas circuit breaker. There are two options for installation of disconnect switches Remove existing dual disconnect switch located between 138kV Main Bus and South Transfer Bus installed for old L Install revenue metering equipment with associated foundations, conduit, and grounding on 138kV L Install new metering panel in control room Install three (3) single phase CCVTs for 3 phase line side voltage sensing and associated structures, foundations, conduit, and grounding on 138kV L Remove all electromechanical relays and complete wiring from existing relay panel #2 of old L Install new relays for 138kV L line protective relaying (microprocessor) consisting of two schemes of direct fiber current differential relay protection using SEL-311L current differential relay as primary and Areva P544 relay as back up Install 138kV L Breaker failure relay SEL-251C to trip adjacent normally connected bus breakers. Revise existing 138kV circuit breaker failure schemes for the new bus configuration. This includes a revision to SPOG 4-7 TSS kV switching. Install SEL-279H2 relay (auto-reclose mode to be RD2 with SCADA close supervision), and SEL-279H2 relay (SCADA close) for new L circuit breaker. This requires cutting front door of the panel having existing relays and install new sheet metal with cutouts for new microprocessor relays Install two (2) physically diverse fiber optic cables to new 138kV L dead end structure Install MFAC relay for 138KkV T-Bus differential protection scheme in relay panel #1 of bus-tie CB Install a donut type CT rated C Amp with 1200:5 maximum ratio 2.0 RF on line side of 138kV CB110 (Main Bus -Transfer Bus Tie) Install a current collector cabinet centrally located from all T-Bus breakers for installation of the high-impedance bus differential relay Upgrade existing SCADA system by adding new Hoffman panel having Sage 3030 data concentrator, Cisco 2811 router, RuggedCom RS416 Ethernet switch, SEL GPS receiver, and SEL Replace existing three (3) 138kV circuit breakers for 138kV L.6101, L.15508, and L.7423 with new 138kV, 2000Amp, 40kA SF6 gas circuit breaker. Page 6

7 Replace existing three (3) bus side dual disconnect switches, L.6101, L.15508, and L.7423, with new 138kV, motor operated disconnect switches. Analyze structures for new disconnect switch load capacity Replace existing three (3) line side disconnect switches, L.6101, L.15508, and L.7423, with new 138kV, motor operated disconnect switches. Analyze structures for new disconnect switch load capacity Remove ability of five (5) existing line side disconnect switches, of L.6101, L.15508, L.7423, L7413, and L.7411 to close from normally open position. (Detail engineering to determine if only blade or entire switch is to be removed) Remove ability of three (3) existing bus side dual disconnect switches, of L.7421, L7413, and L.7411 to close from normally open position. (Detail engineering to determine if only blade or entire switch is to be removed) Replace existing total 330 feet length (approximate 110 feet single length * three buses) of 138kV Main Bus 350 MCM copper conductor connected between Main Bus potential transformer and demarcation point with AmerenIP with new 1113 Kcmil ACSR conductor and associated fittings / connectors Modify existing SBC23B breaker failure relay and install LOR on 138kV L For 138kV L.15508, remove all existing electromechanical line relays, breaker failure relay and reclosing relay from relay panel #6. This requires cutting front door of the panel and installing new sheet metal with cutouts for new microprocessor relays. Install SEL-321 relay, Areva P443 relay, SEL-251C relay, and two (2) SEL- 279H2 relays. Replace existing DCB & Transmitter communication equipment with CS28A & CT51C. Install Bitronics metering. Convert existing 250VDC battery negative-tripping circuits to positive-tripping circuits where possible Install three (3) single phase CCVTs for 3 phase line side voltage sensing and with associated foundations, conduit, and grounding on 138kV L For 138kV L.7423, modify existing SBC23B breaker failure relay and install new LOR. Replace existing 50FD KC-4 (range 2-8A) relay with KC-4 (range 1-4A) relay. Remove existing breaker failure relay enable-disable switch. Install Bitronics metering Remove existing breaker failure relay enable-disable switch on 138kV L.7411, L.7413, and L Evaluate the adequacy of existing batteries and battery chargers for new addition of load due to new microprocessor relays and SCADA communication equipment. 5. METERING & COMMUNICATIONS 5.1 For PJM: The IC will be responsible for performing design, procurement, and construction to install equipment necessary to provide Revenue Metering (kwh, kvarh) and real time data (kw, kvar) for interconnection customer s generating resource. See PJM Manuals M-01 & M-14D, and PJM tariff. 5.2 For ComEd: ComEd will be responsible for performing design, procurement, and construction to install equipment necessary to provide bi-directional revenue metering (kwh, kvarh) and real time data (kw, kvar, circuit breaker status and 138kV voltage) for IC s generating resource. Page 7

8 6. ENVIRONMENTAL, REAL ESTATE AND PERMITTING ISSUES 6.1 IC will be responsible to obtain environmental approvals required for the construction of 138kV TSS 943 Bishop Hill Wind Farm Collector substation. 6.2 The IC will purchase the real estate to accommodate the construction of 138kV TSS 943 Bishop Hill Wind Farm Collector substation. 6.3 The IC will be responsible to purchase real estate or obtain the necessary right-of-way easement to install an approximately twenty eight (28) mile 138kV generator lead up to TSS 74 Kewanee substation. 7. SUMMARY OF RESULTS OF STUDY 7.1 Cost Estimate: The estimated cost for material and labor for the facilities of #P11 project needed for ComEd portion for network upgrade is $3,848,983 NETWORK # SITE LOCATION TOTAL PROJECT COST N1992 Install New 138kV L Circuit Breaker & Associated Equipment at TSS $2,147, Kewanee Substation n kV L.6101 Circuit Breaker Replacement at TSS 74 Kewanee Substation $467,114 n kV L Circuit Breaker Replacement at TSS 74 Kewanee Substation $445,003 n kV L.7423 Circuit Breaker Replacement at TSS 74 Kewanee Substation $471,073 N kV L.7411, L.7413 and L.7421 Relay Upgrade at TSS 74 Kewanee $36,340 Substation N0849 Upgrade station conductor between 138kV Main Bus and demarcation point $31,144 with AmerenIP at TSS 74 Kewanee Substation N2114 Reconfigure 138kV Main/Transfer Bus and install differential relays $250,460 Total Cost of ComEd Work $3,848, Milestone Schedule Description Schedule Start Finish Prepare Project Diagram & Specifications Project Design November 2010 May 2011 Material Procurement January 2011 March 2012 Substation Construction Work at TSS 74 July 2011 April 2012 Acceptance / In Service Testing L94301 TSS74 November 2011 November 2011 Commissioning/In Service Full Capacity April 2012 May Assumptions in Developing Costs and Schedules: ComEd Schedule dates Estimates based on ISA/CSA contract being executed by all parties ComEd Cost Estimates assume that work will be performed during normal weekdays and with no overtime Outages for 138kV Bus tap construction have not been identified, but generally are available in spring (March to May) and fall (September to November). These outages are controlled by ComEd K digital communication circuit is required for SCADA. Page 8

9 8. INFORMATION REQUIRED FOR INTERCONNECTION SERVICE AGREEMENT (ISA) Cost Estimate: The following is the ComEd cost breakdown by switchyard for their portion of the # P11 project: Network Upgrade# n0846 n0847 n0848 n0849 PJM Code / Description L6101 Circuit breaker replacement at TSS 74 Kewanee L7408(existing L15508) Circuit breaker replacement at TSS 74 Kewanee L7423 Circuit breaker replacement at TSS 74 Kewanee Upgrade station conductor between Main bus and demarcation point with Ameren IP at TSS 74 Direct Material Material Indirect Direct Labor Labor Indirect TOTAL PROJECT COST $55,222 $3,656 $236,775 $171,461 $467,114 $47,133 $3,120 $228,953 $165,797 $445,003 $55,222 $3,656 $239,071 $173,124 $471,073 $1,011 $67 $17,438 $12,628 $31,144 n KV L94301 Circuit breaker & associated equipment at TSS 74 Kewanee $344,716 $22,820 $1,032,573 $747,740 $2,147,849 n1993 L7411, L7413, L7421 Relay upgrade at TSS 74 Kewanee $547 $36 $20,739 $15,018 $36,340 n2114 Reconfigure Bus and differential relays $9,342 $618 $139,489 $101,011 $250,460 TOTAL COST $513,193 $33,973 $1,915,038 $1,386,779 $3,848,983 Note: 1 IL sales taxes not reflected in this cost estimate. 2 Carrying charges are anticipated to be zero. ATTACHMENTS: Attachment #1: Attachment #2: Attachment #3: Attachment #4: Attachment #5: Attachment #6 One Line Diagram PJM P Queue Analysis: Impact on MISO Facilities TSS 74 Kewanee, Plan & Elevation Section #3 & 7 of 138kV Switchyard TSS 74 Kewanee, One Line Diagram 138kV System TSS 74 Kewanee, New 138kV L Tap Point Facilities Study Scope and Cost Estimate for Kewanee for PJM Project P11 Bishop Hill II Wind Farm Page 9

10 Attachment #1 One Line Diagram

11 Attachment #2 PJM P Queue Analysis: Impact on MISO Facilities

12 PJM P Queue Analysis: Impact on MISO Facilities In analyzing the impacts of the PJM P queue Interconnection Requests, previously developed cases for PJM O queue studies were used as basecases. The following changes were made to these cases: 1) All MISO queue generators from MISO DPP4IL case queued before PJM P queue closing date (1/31/2006) and after O queue closing date (7/31/2005) were added to study cases. List of added projects is represented in Table I. Table I - MISO Projects added to basecases ALTW G538 8/8/2005 ALTW G540 9/1/2005 AMIL G545 9/7/2005 WEC G546 9/10/2005 ALTW G548 9/17/2005 R23 9/17/2005 GRE G549 9/21/2005 ALTW G551 9/27/2005 OTP G555 10/24/2005 AMIL G569 11/11/2005 ALTW G573 12/9/2005 ALTW G574 12/9/2005 ALTW G575 12/9/2005 ALTW G577 12/19/2005 AMMO G578 12/20/2005 R25 12/22/2005 XEL (NSP) G586 12/30/2005 XEL (NSP) G587 12/30/2005 WPS G590 1/23/2006 2) Two cases were developed a. PJM Wind at 20% - PJM O and P queue generation was modeled online and the wind generation was dispatched at 20% to all PJM areas. b. PJM Wind at 100% - PJM O and P queue generations was modeled online and was dispatched at 100% irrespective of the fuel type to all PJM areas.

13 Table II PJM Generators evaluated Queue PJM Substation MW MWC MWE St Fuel County TO P10 LaSalle 138kV IL Wind LaSalle ComEd P11 Kewanee 138kV IL Wind Mercer ComEd P14 McGirr - Mendota 138kV IL Wind Lee ComEd P18 Dixon-Mendota 34.5kV IL Wind Lee ComEd P20 Nelson-Electric Junction 345kV IL Wind Bureau ComEd P24 Mendota 34.5kV IL Wind Lee ComEd P25 Mendota 34.5kV IL Wind Lee ComEd P26 Mendota 34.5kV IL Wind Lee ComEd P30 Bellefonte - N. Proctorville OH Biomass South AEP P36 138kV Nelson - Lee Co. EC 345kV IL Wind Point Bureau ComEd P37 Normandy 138kV IL Wind Bureau ComEd P40 Crescent Ridge 138kV IL Wind Bureau ComEd P42 West Kingsport 138kV TN Biomass Sullivan AEP P44 City of Columbus OH Diesel Franklin AEP P46 Lena 138kV IL Wind JoDaviess ComEd P49 Adkins 345kV OH Natural Pickaway Dayton P50 Greenville 69kV OH Gas Natural Darke Dayton P51 Stuart 345kV OH Gas Coal Adams Dayton P61 Gavin #1 765kV OH Coal Adams AEP P62 Gavin #2 765kV OH Coal Adams AEP

14 Contingency Files Used: Midwest ISO CAT B and CAT C Auto single branch contingencies for areas : COMED, AMIL, AMMO, ALTE, NIPS, DEM, MEC, MPW Auto single bus contingencies for areas: AMMO, AMIL, COMED, DEM, NIPS all reported contingencies are listed in Appendix A Analysis Tool: PSS/e MUST 9.1 was used to perform the analysis and the monitored sensitivity function was used to report the distribution factors for the study generators. Areas Monitored:

15 All of Midwest control areas, it has to be noted per the request of NIPSCO, 69 kv NIPSCO facilities were also monitored. The details of the monitored file are provided in Appendix B Analysis Method The cases developed were run against the contingency file sets as listed in the Table III. Summary of Constraints PJM Wind 20% PJM Wind 100 % CAT B contingencies Auto single branches CAT B contingencies Auto single branches Auto single bus CAT C Table IIII Cases and contingencies evaluated Linear contingency analysis was used to identify a primary group of constraints, following the linear screen; AC analysis was carried out to determine the validity and the AC loading on the identified constraints. The Table IV below presents the worst loadings on constraints that have been observed. These facilities have at least one PJM P queue generator that has sensitivity greater than or equal to 5%.

16 Case and Contingency File Monitored Branch Contingency Line Rating MVA Pre P queue Loading (MW) Pre P Queue Load % Post P Queue Overload % AC PJM Wind at 100 CAT B PJM Wind at 100 Single Bus PJM Wind at 100 CAT C PJM Wind at 100 CAT B OGLES; T OGLESBY MN HENNE; T HENNEPIN S POWERTN JCT LILLY PLS PR ZION ; R MAZON; R OGLES; T % 125.7% Bus outage: LASCO; B % % D:7BROKAW -7CLINTON1 +7DUCK CR-7TAZEWEL % % CHERR; R SILVE; R % % Table IV Worst Loading % on Constraints Proposed mitigations and cost allocation For (37085 OGLES; T OGLESBY MN 138 1) The 143 MVA rating is due to terminal equipment at Oglesby including multiple CT s and a wave trap. The approximate cost for this work is $200,000 which will provide a new rating of 256 MVA normal and 281 MVA emergency due to bus conductor. Project Ogles;T-Oglesby ($200K) Contribution, MW Cost, K O O O O O P P P P P P

17 For (36839 HENNE; T HENNEPIN S 138 1) The replacement of this conductor for approximately $300,000 will provide a new rating of 191 MVA due to 800A terminal equipment. Project Contribution, MW Henne-Hennepin (300K) Cost, K P P P P P For ( POWERTN JCT LILLY 138 1) The 132 MVA rating is due to sag-limited 336 ACSR conductor. Re-sagging 2.88 miles of this conductor to 120 degrees C will obtain an emergency rating of 161 MVA which will cost approximately $432,000. Project POWERTN JCT-LILLY ($432K) Contribution, MW Cost, K P P P P P P For ( PLS PR ZION ; R 345 1) -- ATC has plans to uprate the Pleasant Prairie to Zion (#2221) 345-kV line rating through replacement of the wave trap. This mitigation will work for this PJM study as well. The existing rating of this line is 973/1069 MVA for Summer Normal and Emergency operation and 1053/1143 MVA for Winter Normal and Emergency operation. The expected future line ratings which result from the wave trap replacement will be 1201/1479 MVA for Summer Normal and Emergency operation and 1497/1710 MVA for Winter Normal and Emergency operation. PJM generators will not have any cost responsibility towards this upgrade. The MUST reported distribution factors from and the P queue generator impacts are presented in Appendix C.

18 Appendix A Reported contingencies Contingency 'Bus outage: TAZEWELL 138' Open branch from bus to bus ckt 1 / TAZEWELL CAT SUB Open branch from bus to bus ckt 1 / TAZEWELL EASTERN Open branch from bus to bus ckt 1 / TAZEWELL RAILSPLITTER Open branch from bus to bus ckt 1 / TAZEWELL FLINT Open branch from bus to bus ckt 1 / TAZEWELL TAZEWELL Open branch from bus to bus ckt 2 / TAZEWELL TAZEWELL Open branch from bus to bus ckt 3 / TAZEWELL TAZEWELL Open branch from bus to bus ckt 1 / EDWARDS TAZEWELL Open branch from bus to bus ckt 2 / EDWARDS TAZEWELL end Contingency ' CHERR; R SILVE; R ' Open branch from bus to bus ckt 1 / CHERR; R SILVE; R end Contingency 'Bus outage: LASCO; B 138' Open branch from bus to bus ckt 1 / LASCO; B MAZON; B Open branch from bus to bus ckt 1 / LASCO; B N Open branch from bus to bus ckt 1 / LASCO;1M LASCO; B Open branch from bus to bus ckt 1 / BROOK; B LASCO; B end CONTINGENCY '36969 MAZON; R OGLES; T 138 1' OPEN BRANCH FROM BUS TO BUS CKT 1 END end

19 Appendix B Monitored Facilities MONITOR BRANCHES IN AREA 217 KVRANGE //NIPS MONITOR TIES FROM AREA 217 KVRANGE MONITOR BRANCHES IN AREA 356 KVRANGE //AMRN MONITOR TIES FROM AREA 356 KVRANGE MONITOR BRANCHES IN AREA 357 KVRANGE //IP MONITOR TIES FROM AREA 357 KVRANGE MONITOR BRANCHES IN AREA 207 KVRANGE MONITOR TIES FROM AREA 207 KVRANGE MONITOR BRANCHES IN AREA 210 KVRANGE MONITOR TIES FROM AREA 210 KVRANGE MONITOR BRANCHES IN AREA 615 KVRANGE MONITOR TIES FROM AREA 615 KVRANGE MONITOR BRANCHES IN AREA 613 KVRANGE MONITOR TIES FROM AREA 613 KVRANGE MONITOR BRANCHES IN AREA 360 KVRANGE //CWLP MONITOR TIES FROM AREA 360 KVRANGE MONITOR BRANCHES IN AREA 361 KVRANGE MONITOR TIES FROM AREA 361 KVRANGE MONITOR BRANCHES IN AREA 600 KVRANGE MONITOR TIES FROM AREA 600 KVRANGE MONITOR BRANCHES IN AREA 627 KVRANGE //ALTW MONITOR TIES FROM AREA 627 KVRANGE MONITOR BRANCHES IN AREA 218 KVRANGE //METC MONITOR TIES FROM AREA 218 KVRANGE MONITOR BRANCHES IN AREA 219 KVRANGE //ITC MONITOR TIES FROM AREA 219 KVRANGE MONITOR BRANCHES IN AREA 216 KVRANGE //IPL

20 MONITOR TIES FROM AREA 216 KVRANGE MONITOR BRANCHES IN AREA 202 KVRANGE //FE MONITOR TIES FROM AREA 202 KVRANGE MONITOR BRANCHES IN AREA 208 KVRANGE //CIN MONITOR TIES FROM AREA 208 KVRANGE MONITOR BRANCHES IN AREA 694 KVRANGE //ALTE MONITOR TIES FROM AREA 694 KVRANGE MONITOR BRANCHES IN AREA 620 KVRANGE //OTP MONITOR TIES FROM AREA 620 KVRANGE MONITOR BRANCHES IN AREA 295 KVRANGE MONITOR TIES FROM AREA 295 KVRANGE MONITOR BRANCHES IN AREA 333 KVRANGE MONITOR TIES FROM AREA 333 KVRANGE MONITOR BRANCHES IN AREA 608 KVRANGE MONITOR TIES FROM AREA 608 KVRANGE MONITOR BRANCHES IN AREA 696 KVRANGE MONITOR TIES FROM AREA 696 KVRANGE MONITOR BRANCHES IN AREA 697 KVRANGE MONITOR TIES FROM AREA 697 KVRANGE MONITOR BRANCHES IN AREA 698 KVRANGE MONITOR TIES FROM AREA 698 KVRANGE MONITOR BRANCHES IN AREA 635 KVRANGE MONITOR TIES FROM AREA 635 KVRANGE MONITOR BRANCHES IN AREA 633 KVRANGE MONITOR TIES FROM AREA 633 KVRANGE END

21 Appendix C DFs for listed flowgates FG# ** From bus ** ** To bus ** CKT Contingency OGLES; T OGLESBY MN MAZON; R OGLES; T HENNE; T HENNEPIN S Bus outage: LASCO; B POWERTN JCT LILLY D:7BROKAW -7CLINTON1 +7DUCK CR-7TAZEWEL PLS PR ZION ; R CHERR; R SILVE; R 345 Table V Flowgates reported

22 FG1 FG2 FG3 FG4 P-010C P-010E P-011C P-011E P-014C P-014E P-018C P-018E P-020C P-020E P-024C P-024E P-025C P-025E P-026C P-026E P P-036C P-036E P-037C P-037E P-040C P-040E P P P-046C P-046E P P P P P Table VI DFs for P queue projects on reported flowgates Note: Projects marked green don t have DF 5% or more on any reported flowgates.

23 FG# ** From bus ** ** To bus ** CKT OGLES; T OGLESBY MN HENNE; T HENNEPIN S POWERTN JCT LILLY PLS PR ZION ; R Contingency Bus outage: KEWAN; Bus outage: LASCO; B 138 D:7BROKAW - 7CLINTON1 +7DUCK CR-7TAZEWEL CHERR; R SILVE; R ContMW Rating BaseFlow Pre P queue loading, % % 18.66% 80.90% % ContLd% % Pre P queue loading, MW P queue contribution, MW P-010C % 32.47% 81.08% % P-010E % 87.69% 81.80% % P-011C % 89.89% 84.17% % P-011E % 98.70% 93.65% % P-014C % 98.78% 93.78% % P-014E % 99.09% 94.34% % P-018C % 99.09% 94.34% % P-018E % 99.11% 94.36% % P-020C % 99.10% 94.49% % P-020E % 99.08% 95.02% % P-024C % 99.10% 95.06% % P-024E % 99.18% 95.20% % P-025C % 99.20% 95.23% % P-025E % 99.28% 95.37% % P-026C % 99.30% 95.40% % P-026E % 99.38% 95.54% % P % 99.35% 95.52% % P-036C % 99.60% 95.97% % P-036E % % 97.79% % P-037C % % 98.74% % P-037E % % % % P-040C % % % % P-040E % % % % P % % % % P % % % % P-046C % % % % P-046E % % % % P % % % % P % % % % P % % % % P % % % % P % % % % Table VII Break down by P queue projects.

24 Attachment #3 TSS 94 Kewanee Plan & Elevation Section #3 &7 138kV Switchyard

25 Attachment #4 TSS 94 Kewanee One Line Diagram 138kV System

26 CB 110 Foundation for Main Bus South Transfer Bus Tie New 138kV L to 138kV South Transfer Bus (S. T-Bus) utilizing old breaker location of formerly L kV CB Attachment #5 TSS 74 Kewanee New 138kV L Tap point 138kV North Transfer Bus 138kV South Transfer Bus 138kV Main Bus 138kV CB 7423

27 Attachment #6 Facilities Study Scope and Cost Estimate For Kewanee For PJM Project P11 Bishop Hill II Wind Farm PROJECT DESCRIPTION PJM Interconnection Project No. P11 is a 200 MW wind farm interconnecting to the 138 kv bus at Commonwealth Edison Company s Kewanee Substation. AFFECTED SYSTEM UPGRADES The following Ameren facilities have been identified by PJM System Impact Studies, and confirmed by Ameren s Transmission Planning department, as overloaded by P11 and in need of upgrade before PJM can grant Interconnection Service to P11. At East Kewanee Substation: Circuit Breaker #B105 Disconnect Switch #106 Disconnect Switch #108 An undetermined amount of bus conductor on the Transfer Bus (the amount to be determined as part of the Facilities Study) PROJECT TASKS Ameren will complete the following tasks during the course of the Facilities Study: Transmission planning to review and confirm the proposed Affected Systen Upgrades required to mitigate the impacts on the affected facilities identified in the System Impact Study. Substation design engineering to develop preliminary design, cost estimates, and schedule for the upgrades to any affected substation facilities. Short circuit and coordination study to determine the system protection requirements for the any modifications to existing protection systems. Transmission line engineering to develop preliminary design, cost estimates, and schedule for any required transmission line upgrade work. Drafting of the preliminary substation and transmission line drawings as may be required for a Facilities Construction Agreement. Prepare and compile a Facilities Study Report.

28 DELIVERABLE ITEMS Ameren will prepare and deliver study report will describe the work to be performed for each Affected System Upgrade, specified above in this Agreement, that is required to mitigate the constraints identified in the System Impact Study. Additional Affected System Upgrades may be identified in the course of the performing the study. Any such additional Affected System Upgrades will also be included in the report with an explanation as to why the additional upgrades are needed. The report will include some or all of the following exhibits, which will become the basis for a Facilities Construction Agreement for the engineering, design, procurement, and construction of the Affected System Upgrades: (i) Exhibit 1: A single-line diagram of the relevant portions of the transmission system showing the Affected System Upgrades. (ii) Exhibit 2: A categorized list or tabulation showing the estimated cost of the Affected System Upgrades. (iii) Exhibit 3: A categorized detailed cost breakdown of each Affected System Upgrade shown in Exhibit 2 by major component (e.g. transformer, line terminal, circuit breaker, etc.) and by subcomponent (e.g. lightning arrester, disconnect switch, protection equipment, communication equipment, monitoring and alarm equipment, metering facilities, grounding, special controls, or equipment needed to meet stability or short circuit criteria, etc.) Similarly, each transmission line will be subcategorized by the major and minor components. (iv) Exhibit 4: A table of milestones giving the estimated schedule for the funding, engineering, design, procurement, and construction of the Affected System Upgrades. SCHEDULE Day Milestone 0 Facility Study clock starts 30 Project and interconnection facility requirements finalized 60 Preliminary design estimating and scheduling activities completed 75 Rough draft of Facility Report completed 90 Final draft of Facility Study report completed

29 COST ESTIMATE The current 2011 average billing labor rates currently in effect are as shown in the table following. These rates are updated periodically, invoices will be based on the rates in effect at the time the charges are incurred. Invoices will be submitted monthly. Out of pocket expenses directly related to the Facilities Study will be itemized. Billing Man Classification Cost Rate Hours Study Coordinator $ $4,760 Substation Design Engineering $ $7,140 System Protection Engineering $ $2,380 Civil Engineering $ $3,570 Transmission Planning Engineering $ $3,450 Drafting $91 30 $2,730 Total Labor 205 $ 24,030 Estimated travel expenses* Other direct expenses Total estimated cost $ 230 $ $ 24,260 * Travel related to this project would be charged at $0.51 per mile in accordance with the 2011 IRS mileage rate.

30 PJM Generator Interconnection #P11 Kewanee 138 kv Facilities Study Report April 2011 Page 1

31 A. FACILITIES STUDY INTRODUCTION 1. PROJECT DESCRIPTION The developer, Bishop Hill, LLC (Interconnection Customer) has proposed the construction and interconnection of the TSS 943 Bishop Hill wind farm generation consisting of 200MW of wind generation with 20% (40MW) capacity. This proposed wind farm located near the town of Bishop Hill in Henry County, Illinois, will interconnect with ComEd 138kV TSS 74 Kewanee substation and consist of an approximately twenty eight (28) mile 138kV generator lead and 134 (one hundred thirty four), 1.5MW GE SLE wind turbine generators. The wind farm will be interconnected to the 138kV South Transfer Bus (S. T-Bus) of TSS 74 Kewanee substation which will be redesignated as Bus #2, utilizing old L.0324 breaker position, as shown in Attachment #1. 2. AMENDMENTS TO THE IMPACT STUDY DATA OR IMPACT STUDY RESULTS 2.1 Replacement of overdutied circuit breaker of 138kV L.7411 at TSS 74 Kewanee substation The impact study indicates the replacement of overdutied circuit breaker of 138kV L.7411 at TSS 74 Kewanee substation as it is rated to interrupting capacity of 13.6kA. It has been verified by ComEd in the field that the existing circuit breaker is rated for interrupting capacity of 5000MVA and is not required to be replaced. 2.2 Change of line number The impact study report describes the replacement of 138kV L.7408 circuit breaker at TSS 74 Kewanee substation assuming completion of project #O29. In this facility study report, the completion of project #O29 is not assumed complete and therefore, L is still identified as L at TSS 74 Kewanee. 2.3 Impact on MISO The results of a cross border study are attached as Attachment 2. In addition to upgrades identified in this report, an upgrade to the Ameren owned portion of the Kewanee bus tie (CB 105 and associated disconnect switches) will be required. The ComEd-owned Kewanee 138kV Main Bus to the Ameren Illinois-owned Kewanee 138kV circuit breaker #105 and series equipment loads to MVA for the Line fault with breaker failure at Nelson. Ameren Illinois reports their ratings for this tie as 275MVA normal and 287 MVA emergency. The proposed upgrade will result in a rating of 478 MVA normal and emergency due to switches. This upgrade will be required upon the Initial Operation of all three of the following PJM Queued Projects: O09, O29, and P11. Subsequently queued projects that also contribute to this overload are P37, Q39, and Q60. Ameren has requested a Facilities Study for this work, and PJM will coordinate with the IC, Ameren, and the Midwest ISO in accordance with paragraph of the Joint Operating Agreement. See Attachment 6 for additional details. Upon completion of the Facilities Study, the IC shall execute, potentially with other parties contributing to these same overloads, an Upgrade Construction Service Agreement or similar document with the Affected System Operator in accord with paragraph of the PJM Open Access Transmission Tariff. The financial responsibility of each project towards each upgrade identified in Attachment 2 assumes all of the identified contributors remain in the queue. If any should withdraw, the allocation to the remainder, as well as the need for the upgrade itself will be reevaluated. 2.4 Stability Study & Low Voltage Ride Through Report Page 2

32 No stability issues have been identified and the proposed installation is in compliance with the low voltage ride through requirements in accordance with FERC Order 661-A. See Siemens PTI Report No. R26-09 for additional information. 2.5 The voltage collapse condition resulting from a fault on 138kV line with a failed breaker at Nelson TSS 155 identified in the Impact Study can be mitigated by the installation of GE WindControl controls. The installation of a series breaker in the Line at Nelson is not required. 3. INTERCONNECTION CUSTOMER SCHEDULE IC has envisioned the construction of 200MW wind farm by spring 2012: Description Start of construction Started Start of turbine delivery September 2011 Substation energization November 2011 Commercial Operation June 1, SCOPE OF WORK BY INTERCONNECTION CUSTOMER (IC) Schedule 4.1 The IC will be responsible for performing design, construction, and operation of all facilities on the IC side of the Point of Interconnection as shown in Attachment #1. The IC will meet all the requirements of protective relaying per design E of most recent version of Guidelines for the Interconnection of Generation to the EED System. 4.2 The IC will be responsible for performing design, procurement, and construction of a twenty eight (28) mile long 138kV generator lead L to the point of interconnection at substation dead end structure at TSS 74 Kewanee substation, as shown in Attachment #1. The IC must provide two (2) physically diverse fiber optic routes to TSS 74 Kewanee for protective relay communication purposes. 4.3 The IC will be responsible for performing design, procurement, and construction of the 200MW wind farm, which includes the generator step-up transformers (GSU s), collection system, two (2) main transformers, and three (3) 138kV breakers. 4.4 The IC will be responsible for purchasing real estate or obtaining the necessary right-ofway to install 138kV generator lead L The IC and ComEd have mutually agreed that the IC will be responsible for the design engineering and procurement of long lead time materials for the Transmission Owner facilities/modifications described in Sections A5 and B4 below. 4.6 PJM Requirements: The IC will be required to install equipment necessary to provide Revenue Metering (kwh, kvarh) and real time data (kw, kvar) for interconnection customer s generating resource. See PJM Manuals M-01 & M-14D, and PJM tariff. 5. DESCRIPTION OF FACILITIES INCLUDED IN THE FACILITIES STUDY 5.1 TSS 74 Kewanee Substation ComEd will be responsible for the construction for the following: Installation of new SF6 gas circuit breaker, motor operated disconnect switches, revenue metering unit, CCVTs, wave trap, and dead end structure for 138kV L.94301, as shown in Attachment #1 and #5 (Attachment Facilities--PJM upgrade #N1992) Removal of existing dual disconnect switch located between 138kV Main BUS and South Transfer BUS installed for old L.0324 (Attachment Facilities--PJM upgrade #N1992) Page 3

33 5.1.3 Removal of old L.0324 disconnect switch and circuit breaker foundations and installation of new foundations and structures for new equipment (Attachment Facilities--PJM upgrade #N1992) Installation of two current differential relay protection schemes on 138kV L.94301(Non-direct connect PJM Network Upgrade n1992) Installation of 138kV T-Bus differential protection scheme (Non-direct connect PJM Network Upgrade n2114) Evaluation of the adequacy of existing batteries and battery chargers due to new microprocessor relays and communication equipment. (Non-direct connect PJM Network Upgrade n2114) Replacement of three (3) existing 138kV circuit breakers, L.6101, L.15508, and L.7423, with new 138kV, 2000 Amp, 40kA gas circuit breakers.( Non-direct connect PJM Network Upgrades n0846, n0847, and n0848) Replacement of three (3) existing bus side dual disconnect switches, L.6101, L.15508, and L.7423, with new 138kV, motor operated disconnect switches. Analyze structures for new disconnect switch load capacity. (Non-direct connect PJM Network Upgrades n0846, n0847, and n0848) Replacement of three (3) existing line side disconnect switches, L.6101, L.15508, and L.7423, with new 138kV, motor operated disconnect switches. Analyze structures for new disconnect switch load capacity. (Non-direct connect PJM Network Upgrade n0846, n0847, and n0848) Remove ability of five (5) existing line side disconnect switches, of L.6101, L.15508, L.7423, L7413, and L.7411 to close from normally open position. (Detail engineering to determine if only blade or entire switch is to be removed). (Non-direct connect PJM Network Upgrade n2114) Remove ability of (3) existing bus side dual disconnect switches, of L.7421, L7413, and L.7411 to close from normally open position. (Detail engineering to determine if only blade or entire switch is to be removed) (Non-direct connect PJM Network Upgrade n2114) Modifiy breaker failure relay circuits on 138kV L7411, L7413, and L7421 breakers. (Non-direct connect PJM Network Upgrade n1993) Upgrade existing communication equipment on L (Non-direct connect PJM Network Upgrade n2114) Upgrade existing 250VDC negative-tripping circuits to 250VDC positivetripping circuits on 138kV L.6101, L.15508, and L ( Non-direct connect PJM Network Upgrades n0846, n0847, and n0848) Upgrade existing 350 MCM copper to 1113 KCmil ACSR between 138kV Main Bus and demarcation point with AmerenIP.(Non-direct connect PJM Network Upgrade n0849) Installation of equipment necessary to provide bi-directional revenue metering (kwh, kvarh) and real time data (kw, kvar, circuit breaker status and 138kV voltage) for IC s generating resource. See ComEd applicable standards available on the PJM website (TO Standards). (Non-direct connect PJM Network Upgrade n1992). 6. TOTAL COSTS OF TRANSMISSION OWNER FACILITIES INCLUDED IN FACILITY STUDY The estimated cost for material and labor for the facilities of #P11 project needed for ComEd portion for network upgrade is $3,848,983 Page 4

34 NETWORK # SITE LOCATION TOTAL PROJECT COST N1992 Install New 138kV L Circuit Breaker & Associated Equipment at TSS $2,147, Kewanee Substation n kV L.6101 Circuit Breaker Replacement at TSS 74 Kewanee Substation $467,114 n kV L Circuit Breaker Replacement at TSS 74 Kewanee Substation $445,003 n kV L.7423 Circuit Breaker Replacement at TSS 74 Kewanee Substation $471,073 N kV L.7411, L.7413 and L.7421 Relay Upgrade at TSS 74 Kewanee $36,340 Substation N0849 Upgrade station conductor between 138kV Main Bus and demarcation point $31,144 with AmerenIP at TSS 74 Kewanee Substation N2114 Reconfigure 138kV Main/Transfer Bus and install differential relays $250,460 Total Cost of ComEd Work $3,848, SUMMARY OF MILESTONE SCHEDULES FOR COMPLETION OF WORK INCLUDED IN FACILITY STUDY Description Schedule Start Finish Prepare Project Diagram & Specifications Project Design November 2010 May 2011 Material Procurement January 2011 February 2012 Substation Construction Work at TSS 74 July 2011 April 2012 Substation Construction Work at TSS 155 January 2012 March 2012 Acceptance Testing L94301 TSS74 October 2011 November 2011 Commissioning/In Service Full Capacity April 2012 May 2012 B. TRANSMISSION OWNER (ComEd) FACILITIES STUDY RESULTS 1. TRANSMISSION LINES - NEW 1.1 The Interconnection Customer is responsible for performing design, procurement, and construction of an approximately twenty-eight (28) mile 138kV generator lead L to the point of interconnection at substation dead end structure of TSS 74 Kewanee substation as shown in attachment #1. 2. TRANSMISSION LINES UPGRADES 2.1 Not applicable. 3. NEW SUBSTATION / SWITCHYARD FACILITIES 3.1 Not applicable. 4. UPGRADES TO EXISTING SUBSTATION / SWITCHYARD FACILITIES Purpose and Necessity: ComEd will be responsible for procurement of other than long lead time equipment, and construction activities to tap new 138kV L to the point of interconnection at substation dead end structure, replacement of existing circuit breakers and upgrade existing protection relays, SCADA and communication equipment to protect 138kV L.6101, L.15508, and L.7423 at TSS 74 Kewanee substation as indicated in one line diagram per attachment #1. Page 5

35 ComEd will be responsible for procurement of other than long lead time equipment, and construction activities to add new 138kV SF6 gas circuit breaker in series with existing 138kV circuit breaker and upgrade existing protection relays, SCADA and communication equipment to protect 138kV L at TSS 155 Nelson Substation as indicated in one line diagram per attachment #1. Long lead time equipment that the IC is responsible for providing includes: 138kV SF6 breakers, motor operated disconnect switches, motor operators, metering current transformers & metering set, support steel structures, CCVT's, wavetraps, tuners, terminal A-frames, surge arresters, insulators, line relay panels, breaker relay panels, communication panel and equipment, scada panels and equipment, and relay devices. 4.1 TSS 74 Kewanee Substation Install new dead end structure and foundations for 138kV L per ComEd EM Install new 138kV, 3000Amp, 40kA SF6 gas circuit breaker on new foundations with associated conduit and grounding for 138kV L Install new 138kV motor operated disconnect switch on both the sides of 138kV SF6 gas circuit breaker and connect bus side disconnect switch directly to 138kV South Transfer Bus (S. T-Bus). Install new foundations with associated conduit and grounding on both sides of 138kV L SF6 gas circuit breaker. There are two options for installation of disconnect switches Remove existing dual disconnect switch located between 138kV Main Bus and South Transfer Bus installed for old L Install revenue metering equipment with associated foundations, conduit, and grounding on 138kV L Install new metering panel in control room Install three (3) single phase CCVTs for 3 phase line side voltage sensing and associated structures, foundations, conduit, and grounding on 138kV L Remove all electromechanical relays and complete wiring from existing relay panel #2 of old L Install new relays for 138kV L line protective relaying (microprocessor) consisting of two schemes of direct fiber current differential relay protection using SEL-311L current differential relay as primary and Areva P544 relay as back up Install 138kV L Breaker failure relay SEL-251C to trip adjacent normally connected bus breakers. Revise existing 138kV circuit breaker failure schemes for the new bus configuration. This includes a revision to SPOG 4-7 TSS kV switching. Install SEL-279H2 relay (auto-reclose mode to be RD2 with SCADA close supervision), and SEL-279H2 relay (SCADA close) for new L circuit breaker. This requires cutting front door of the panel having existing relays and install new sheet metal with cutouts for new microprocessor relays Install two (2) physically diverse fiber optic cables to new 138kV L dead end structure Install MFAC relay for 138KkV T-Bus differential protection scheme in relay panel #1 of bus-tie CB Install a donut type CT rated C Amp with 1200:5 maximum ratio 2.0 RF on line side of 138kV CB110 (Main Bus -Transfer Bus Tie) Install a current collector cabinet centrally located from all T-Bus breakers for installation of the high-impedance bus differential relay. Page 6

36 Upgrade existing SCADA system by adding new Hoffman panel having Sage 3030 data concentrator, Cisco 2811 router, RuggedCom RS416 Ethernet switch, SEL GPS receiver, and SEL Replace existing three (3) 138kV circuit breakers for 138kV L.6101, L.15508, and L.7423 with new 138kV, 2000Amp, 40kA SF6 gas circuit breaker Replace existing three (3) bus side dual disconnect switches, L.6101, L.15508, and L.7423, with new 138kV, motor operated disconnect switches. Analyze structures for new disconnect switch load capacity Replace existing three (3) line side disconnect switches, L.6101, L.15508, and L.7423, with new 138kV, motor operated disconnect switches. Analyze structures for new disconnect switch load capacity Remove ability of five (5) existing line side disconnect switches, of L.6101, L.15508, L.7423, L7413, and L.7411 to close from normally open position. (Detail engineering to determine if only blade or entire switch is to be removed) Remove ability of three (3) existing bus side dual disconnect switches, of L.7421, L7413, and L.7411 to close from normally open position. (Detail engineering to determine if only blade or entire switch is to be removed) Replace existing total 330 feet length (approximate 110 feet single length * three buses) of 138kV Main Bus 350 MCM copper conductor connected between Main Bus potential transformer and demarcation point with AmerenIP with new 1113 Kcmil ACSR conductor and associated fittings / connectors Modify existing SBC23B breaker failure relay and install LOR on 138kV L For 138kV L.15508, remove all existing electromechanical line relays, breaker failure relay and reclosing relay from relay panel #6. This requires cutting front door of the panel and installing new sheet metal with cutouts for new microprocessor relays. Install SEL-321 relay, Areva P443 relay, SEL-251C relay, and two (2) SEL- 279H2 relays. Replace existing DCB & Transmitter communication equipment with CS28A & CT51C. Install Bitronics metering. Convert existing 250VDC battery negative-tripping circuits to positive-tripping circuits where possible Install three (3) single phase CCVTs for 3 phase line side voltage sensing and with associated foundations, conduit, and grounding on 138kV L For 138kV L.7423, modify existing SBC23B breaker failure relay and install new LOR. Replace existing 50FD KC-4 (range 2-8A) relay with KC-4 (range 1-4A) relay. Remove existing breaker failure relay enable-disable switch. Install Bitronics metering Remove existing breaker failure relay enable-disable switch on 138kV L.7411, L.7413, and L Evaluate the adequacy of existing batteries and battery chargers for new addition of load due to new microprocessor relays and SCADA communication equipment. 5. METERING & COMMUNICATIONS 5.1 For PJM: The IC will be responsible for performing design, procurement, and construction to install equipment necessary to provide Revenue Metering (kwh, kvarh) and real time data (kw, kvar) for interconnection customer s generating resource. See PJM Manuals M-01 & M-14D, and PJM tariff. 5.2 For ComEd: Page 7

37 ComEd will be responsible for performing design, procurement, and construction to install equipment necessary to provide bi-directional revenue metering (kwh, kvarh) and real time data (kw, kvar, circuit breaker status and 138kV voltage) for IC s generating resource. 6. ENVIRONMENTAL, REAL ESTATE AND PERMITTING ISSUES 6.1 IC will be responsible to obtain environmental approvals required for the construction of 138kV TSS 943 Bishop Hill Wind Farm Collector substation. 6.2 The IC will purchase the real estate to accommodate the construction of 138kV TSS 943 Bishop Hill Wind Farm Collector substation. 6.3 The IC will be responsible to purchase real estate or obtain the necessary right-of-way easement to install an approximately twenty eight (28) mile 138kV generator lead up to TSS 74 Kewanee substation. 7. SUMMARY OF RESULTS OF STUDY 7.1 Cost Estimate: The estimated cost for material and labor for the facilities of #P11 project needed for ComEd portion for network upgrade is $3,848,983 NETWORK # SITE LOCATION TOTAL PROJECT COST N1992 Install New 138kV L Circuit Breaker & Associated Equipment at TSS $2,147, Kewanee Substation n kV L.6101 Circuit Breaker Replacement at TSS 74 Kewanee Substation $467,114 n kV L Circuit Breaker Replacement at TSS 74 Kewanee Substation $445,003 n kV L.7423 Circuit Breaker Replacement at TSS 74 Kewanee Substation $471,073 N kV L.7411, L.7413 and L.7421 Relay Upgrade at TSS 74 Kewanee $36,340 Substation N0849 Upgrade station conductor between 138kV Main Bus and demarcation point $31,144 with AmerenIP at TSS 74 Kewanee Substation N2114 Reconfigure 138kV Main/Transfer Bus and install differential relays $250,460 Total Cost of ComEd Work $3,848, Milestone Schedule Description Schedule Start Finish Prepare Project Diagram & Specifications Project Design November 2010 May 2011 Material Procurement January 2011 March 2012 Substation Construction Work at TSS 74 July 2011 April 2012 Substation Construction Work at TSS 155 January 2012 March 2012 Acceptance / In Service Testing L94301 TSS74 November 2011 November 2011 Commissioning/In Service Full Capacity April 2012 May Assumptions in Developing Costs and Schedules: ComEd Schedule dates Estimates based on ISA/CSA contract being executed by all parties. Page 8

38 7.3.2 ComEd Cost Estimates assume that work will be performed during normal weekdays and with no overtime Outages for 138kV Bus tap construction have not been identified, but generally are available in spring (March to May) and fall (September to November). These outages are controlled by ComEd K digital communication circuit is required for SCADA. 8. INFORMATION REQUIRED FOR INTERCONNECTION SERVICE AGREEMENT (ISA) Cost Estimate: The following is the ComEd cost breakdown by switchyard for their portion of the # P11 project: Network Upgrade# n0846 n0847 n0848 n0849 PJM Code / Description L6101 Circuit breaker replacement at TSS 74 Kewanee L7408(existing L15508) Circuit breaker replacement at TSS 74 Kewanee L7423 Circuit breaker replacement at TSS 74 Kewanee Upgrade station conductor between Main bus and demarcation point with Ameren IP at TSS 74 Direct Material Material Indirect Direct Labor Labor Indirect TOTAL PROJECT COST $55,222 $3,656 $236,775 $171,461 $467,114 $47,133 $3,120 $228,953 $165,797 $445,003 $55,222 $3,656 $239,071 $173,124 $471,073 $1,011 $67 $17,438 $12,628 $31,144 n KV L94301 Circuit breaker & associated equipment at TSS 74 Kewanee $344,716 $22,820 $1,032,573 $747,740 $2,147,849 n1993 L7411, L7413, L7421 Relay upgrade at TSS 74 Kewanee $547 $36 $20,739 $15,018 $36,340 n2114 Reconfigure Bus and differential relays $9,342 $618 $139,489 $101,011 $250,460 TOTAL COST $513,193 $33,973 $1,915,038 $1,386,779 $3,848,983 Note: 1 IL sales taxes not reflected in this cost estimate. 2 Carrying charges are anticipated to be zero. ATTACHMENTS: Attachment #1: Attachment #2: Attachment #3: Attachment #4: Attachment #5: Attachment #6 One Line Diagram PJM P Queue Analysis: Impact on MISO Facilities TSS 74 Kewanee, Plan & Elevation Section #3 & 7 of 138kV Switchyard TSS 74 Kewanee, One Line Diagram 138kV System TSS 74 Kewanee, New 138kV L Tap Point Facilities Study Scope and Cost Estimate for Kewanee for PJM Project P11 Bishop Hill II Wind Farm Page 9

39 Attachment #1 One Line Diagram

40 Attachment #2 PJM P Queue Analysis: Impact on MISO Facilities

41 PJM P Queue Analysis: Impact on MISO Facilities In analyzing the impacts of the PJM P queue Interconnection Requests, previously developed cases for PJM O queue studies were used as basecases. The following changes were made to these cases: 1) All MISO queue generators from MISO DPP4IL case queued before PJM P queue closing date (1/31/2006) and after O queue closing date (7/31/2005) were added to study cases. List of added projects is represented in Table I. Table I - MISO Projects added to basecases ALTW G538 8/8/2005 ALTW G540 9/1/2005 AMIL G545 9/7/2005 WEC G546 9/10/2005 ALTW G548 9/17/2005 R23 9/17/2005 GRE G549 9/21/2005 ALTW G551 9/27/2005 OTP G555 10/24/2005 AMIL G569 11/11/2005 ALTW G573 12/9/2005 ALTW G574 12/9/2005 ALTW G575 12/9/2005 ALTW G577 12/19/2005 AMMO G578 12/20/2005 R25 12/22/2005 XEL (NSP) G586 12/30/2005 XEL (NSP) G587 12/30/2005 WPS G590 1/23/2006 2) Two cases were developed a. PJM Wind at 20% - PJM O and P queue generation was modeled online and the wind generation was dispatched at 20% to all PJM areas. b. PJM Wind at 100% - PJM O and P queue generations was modeled online and was dispatched at 100% irrespective of the fuel type to all PJM areas.

42 Table II PJM Generators evaluated Queue PJM Substation MW MWC MWE St Fuel County TO P10 LaSalle 138kV IL Wind LaSalle ComEd P11 Kewanee 138kV IL Wind Mercer ComEd P14 McGirr - Mendota 138kV IL Wind Lee ComEd P18 Dixon-Mendota 34.5kV IL Wind Lee ComEd P20 Nelson-Electric Junction 345kV IL Wind Bureau ComEd P24 Mendota 34.5kV IL Wind Lee ComEd P25 Mendota 34.5kV IL Wind Lee ComEd P26 Mendota 34.5kV IL Wind Lee ComEd P30 Bellefonte - N. Proctorville OH Biomass South AEP P36 138kV Nelson - Lee Co. EC 345kV IL Wind Point Bureau ComEd P37 Normandy 138kV IL Wind Bureau ComEd P40 Crescent Ridge 138kV IL Wind Bureau ComEd P42 West Kingsport 138kV TN Biomass Sullivan AEP P44 City of Columbus OH Diesel Franklin AEP P46 Lena 138kV IL Wind JoDaviess ComEd P49 Adkins 345kV OH Natural Pickaway Dayton P50 Greenville 69kV OH Gas Natural Darke Dayton P51 Stuart 345kV OH Gas Coal Adams Dayton P61 Gavin #1 765kV OH Coal Adams AEP P62 Gavin #2 765kV OH Coal Adams AEP

43 Contingency Files Used: Midwest ISO CAT B and CAT C Auto single branch contingencies for areas : COMED, AMIL, AMMO, ALTE, NIPS, DEM, MEC, MPW Auto single bus contingencies for areas: AMMO, AMIL, COMED, DEM, NIPS all reported contingencies are listed in Appendix A Analysis Tool: PSS/e MUST 9.1 was used to perform the analysis and the monitored sensitivity function was used to report the distribution factors for the study generators. Areas Monitored:

44 All of Midwest control areas, it has to be noted per the request of NIPSCO, 69 kv NIPSCO facilities were also monitored. The details of the monitored file are provided in Appendix B Analysis Method The cases developed were run against the contingency file sets as listed in the Table III. Summary of Constraints PJM Wind 20% PJM Wind 100 % CAT B contingencies Auto single branches CAT B contingencies Auto single branches Auto single bus CAT C Table IIII Cases and contingencies evaluated Linear contingency analysis was used to identify a primary group of constraints, following the linear screen; AC analysis was carried out to determine the validity and the AC loading on the identified constraints. The Table IV below presents the worst loadings on constraints that have been observed. These facilities have at least one PJM P queue generator that has sensitivity greater than or equal to 5%.

45 Case and Contingency File Monitored Branch Contingency Line Rating MVA Pre P queue Loading (MW) Pre P Queue Load % Post P Queue Overload % AC PJM Wind at 100 CAT B PJM Wind at 100 Single Bus PJM Wind at 100 CAT C PJM Wind at 100 CAT B OGLES; T OGLESBY MN HENNE; T HENNEPIN S POWERTN JCT LILLY PLS PR ZION ; R MAZON; R OGLES; T % 125.7% Bus outage: LASCO; B % % D:7BROKAW -7CLINTON1 +7DUCK CR-7TAZEWEL % % CHERR; R SILVE; R % % Table IV Worst Loading % on Constraints Proposed mitigations and cost allocation For (37085 OGLES; T OGLESBY MN 138 1) The 143 MVA rating is due to terminal equipment at Oglesby including multiple CT s and a wave trap. The approximate cost for this work is $200,000 which will provide a new rating of 256 MVA normal and 281 MVA emergency due to bus conductor. Project Ogles;T-Oglesby ($200K) Contribution, MW Cost, K O O O O O P P P P P P

46 For (36839 HENNE; T HENNEPIN S 138 1) The replacement of this conductor for approximately $300,000 will provide a new rating of 191 MVA due to 800A terminal equipment. Project Contribution, MW Henne-Hennepin (300K) Cost, K P P P P P For ( POWERTN JCT LILLY 138 1) The 132 MVA rating is due to sag-limited 336 ACSR conductor. Re-sagging 2.88 miles of this conductor to 120 degrees C will obtain an emergency rating of 161 MVA which will cost approximately $432,000. Project POWERTN JCT-LILLY ($432K) Contribution, MW Cost, K P P P P P P For ( PLS PR ZION ; R 345 1) -- ATC has plans to uprate the Pleasant Prairie to Zion (#2221) 345-kV line rating through replacement of the wave trap. This mitigation will work for this PJM study as well. The existing rating of this line is 973/1069 MVA for Summer Normal and Emergency operation and 1053/1143 MVA for Winter Normal and Emergency operation. The expected future line ratings which result from the wave trap replacement will be 1201/1479 MVA for Summer Normal and Emergency operation and 1497/1710 MVA for Winter Normal and Emergency operation. PJM generators will not have any cost responsibility towards this upgrade. The MUST reported distribution factors from and the P queue generator impacts are presented in Appendix C.

47 Appendix A Reported contingencies Contingency 'Bus outage: TAZEWELL 138' Open branch from bus to bus ckt 1 / TAZEWELL CAT SUB Open branch from bus to bus ckt 1 / TAZEWELL EASTERN Open branch from bus to bus ckt 1 / TAZEWELL RAILSPLITTER Open branch from bus to bus ckt 1 / TAZEWELL FLINT Open branch from bus to bus ckt 1 / TAZEWELL TAZEWELL Open branch from bus to bus ckt 2 / TAZEWELL TAZEWELL Open branch from bus to bus ckt 3 / TAZEWELL TAZEWELL Open branch from bus to bus ckt 1 / EDWARDS TAZEWELL Open branch from bus to bus ckt 2 / EDWARDS TAZEWELL end Contingency ' CHERR; R SILVE; R ' Open branch from bus to bus ckt 1 / CHERR; R SILVE; R end Contingency 'Bus outage: LASCO; B 138' Open branch from bus to bus ckt 1 / LASCO; B MAZON; B Open branch from bus to bus ckt 1 / LASCO; B N Open branch from bus to bus ckt 1 / LASCO;1M LASCO; B Open branch from bus to bus ckt 1 / BROOK; B LASCO; B end CONTINGENCY '36969 MAZON; R OGLES; T 138 1' OPEN BRANCH FROM BUS TO BUS CKT 1 END end

48 Appendix B Monitored Facilities MONITOR BRANCHES IN AREA 217 KVRANGE //NIPS MONITOR TIES FROM AREA 217 KVRANGE MONITOR BRANCHES IN AREA 356 KVRANGE //AMRN MONITOR TIES FROM AREA 356 KVRANGE MONITOR BRANCHES IN AREA 357 KVRANGE //IP MONITOR TIES FROM AREA 357 KVRANGE MONITOR BRANCHES IN AREA 207 KVRANGE MONITOR TIES FROM AREA 207 KVRANGE MONITOR BRANCHES IN AREA 210 KVRANGE MONITOR TIES FROM AREA 210 KVRANGE MONITOR BRANCHES IN AREA 615 KVRANGE MONITOR TIES FROM AREA 615 KVRANGE MONITOR BRANCHES IN AREA 613 KVRANGE MONITOR TIES FROM AREA 613 KVRANGE MONITOR BRANCHES IN AREA 360 KVRANGE //CWLP MONITOR TIES FROM AREA 360 KVRANGE MONITOR BRANCHES IN AREA 361 KVRANGE MONITOR TIES FROM AREA 361 KVRANGE MONITOR BRANCHES IN AREA 600 KVRANGE MONITOR TIES FROM AREA 600 KVRANGE MONITOR BRANCHES IN AREA 627 KVRANGE //ALTW MONITOR TIES FROM AREA 627 KVRANGE MONITOR BRANCHES IN AREA 218 KVRANGE //METC MONITOR TIES FROM AREA 218 KVRANGE MONITOR BRANCHES IN AREA 219 KVRANGE //ITC MONITOR TIES FROM AREA 219 KVRANGE MONITOR BRANCHES IN AREA 216 KVRANGE //IPL

49 MONITOR TIES FROM AREA 216 KVRANGE MONITOR BRANCHES IN AREA 202 KVRANGE //FE MONITOR TIES FROM AREA 202 KVRANGE MONITOR BRANCHES IN AREA 208 KVRANGE //CIN MONITOR TIES FROM AREA 208 KVRANGE MONITOR BRANCHES IN AREA 694 KVRANGE //ALTE MONITOR TIES FROM AREA 694 KVRANGE MONITOR BRANCHES IN AREA 620 KVRANGE //OTP MONITOR TIES FROM AREA 620 KVRANGE MONITOR BRANCHES IN AREA 295 KVRANGE MONITOR TIES FROM AREA 295 KVRANGE MONITOR BRANCHES IN AREA 333 KVRANGE MONITOR TIES FROM AREA 333 KVRANGE MONITOR BRANCHES IN AREA 608 KVRANGE MONITOR TIES FROM AREA 608 KVRANGE MONITOR BRANCHES IN AREA 696 KVRANGE MONITOR TIES FROM AREA 696 KVRANGE MONITOR BRANCHES IN AREA 697 KVRANGE MONITOR TIES FROM AREA 697 KVRANGE MONITOR BRANCHES IN AREA 698 KVRANGE MONITOR TIES FROM AREA 698 KVRANGE MONITOR BRANCHES IN AREA 635 KVRANGE MONITOR TIES FROM AREA 635 KVRANGE MONITOR BRANCHES IN AREA 633 KVRANGE MONITOR TIES FROM AREA 633 KVRANGE END

50 Appendix C DFs for listed flowgates FG# ** From bus ** ** To bus ** CKT Contingency OGLES; T OGLESBY MN MAZON; R OGLES; T HENNE; T HENNEPIN S Bus outage: LASCO; B POWERTN JCT LILLY D:7BROKAW -7CLINTON1 +7DUCK CR-7TAZEWEL PLS PR ZION ; R CHERR; R SILVE; R 345 Table V Flowgates reported

51 FG1 FG2 FG3 FG4 P-010C P-010E P-011C P-011E P-014C P-014E P-018C P-018E P-020C P-020E P-024C P-024E P-025C P-025E P-026C P-026E P P-036C P-036E P-037C P-037E P-040C P-040E P P P-046C P-046E P P P P P Table VI DFs for P queue projects on reported flowgates Note: Projects marked green don t have DF 5% or more on any reported flowgates.

52 FG# ** From bus ** ** To bus ** CKT OGLES; T OGLESBY MN HENNE; T HENNEPIN S POWERTN JCT LILLY PLS PR ZION ; R Contingency Bus outage: KEWAN; Bus outage: LASCO; B 138 D:7BROKAW - 7CLINTON1 +7DUCK CR-7TAZEWEL CHERR; R SILVE; R ContMW Rating BaseFlow Pre P queue loading, % % 18.66% 80.90% % ContLd% % Pre P queue loading, MW P queue contribution, MW P-010C % 32.47% 81.08% % P-010E % 87.69% 81.80% % P-011C % 89.89% 84.17% % P-011E % 98.70% 93.65% % P-014C % 98.78% 93.78% % P-014E % 99.09% 94.34% % P-018C % 99.09% 94.34% % P-018E % 99.11% 94.36% % P-020C % 99.10% 94.49% % P-020E % 99.08% 95.02% % P-024C % 99.10% 95.06% % P-024E % 99.18% 95.20% % P-025C % 99.20% 95.23% % P-025E % 99.28% 95.37% % P-026C % 99.30% 95.40% % P-026E % 99.38% 95.54% % P % 99.35% 95.52% % P-036C % 99.60% 95.97% % P-036E % % 97.79% % P-037C % % 98.74% % P-037E % % % % P-040C % % % % P-040E % % % % P % % % % P % % % % P-046C % % % % P-046E % % % % P % % % % P % % % % P % % % % P % % % % P % % % % Table VII Break down by P queue projects.

53 Attachment #3 TSS 94 Kewanee Plan & Elevation Section #3 &7 138kV Switchyard

54 Attachment #4 TSS 94 Kewanee One Line Diagram 138kV System

55 CB 110 Foundation for Main Bus South Transfer Bus Tie New 138kV L to 138kV South Transfer Bus (S. T-Bus) utilizing old breaker location of formerly L kV CB Attachment #5 TSS 74 Kewanee New 138kV L Tap point 138kV North Transfer Bus 138kV South Transfer Bus 138kV Main Bus 138kV CB 7423