2008 All Source Participants Workshop June 19, 2008

2008 Participants WorkshopAll Source RFO

June 19, 2008

2008 All Source Participants Workshop June 19, 2008

General Information

• Offers and bid deposits are due Monday, July 21 by 1 p.m. Pacific Time

• All Offers must contain each of the following:

Completed Cover Sheet: Appendix A Signed Offer Agreement: Appendix B (word version and signed executed version) Letter of Credit: Appendix C and C1 (completed W-9 form) Executed 2004 FERC Waiver: Appendix E Executed Power Purchase Agreement (Appendix F) or Purchase and Sale Agreement

(Appendix G) redline and clean versions Offer Data Form: Appendix H1 or H2 Generation Facility Information: Appendix I1 or I2. If you’re submitting more than one

variation of each offer provide a letter after the unique name identifier. Project Description: Appendix J Credit and Finance form: Appendix K and completed Tables A and B Completed Transmission Data form: Appendix L A copy of the completed Gas Interconnection Application and the Agreement to Perform Tariff

Related Work: Appendix M2 Completed Generation Operating Characteristics: Appendix N3 and an “as is” or markup of

Appendix N4.

2008 All Source Participants Workshop June 19, 2008

General Information

• All Offers require five (5) bound copies and (1) one unbound copy.

• We prefer to have two (2) USB removable flash drives or three (3) compact discs. We will not be accepting any offers via FAX or email.

• Version– Standard Microsoft Word or Excel 2003. If you have Microsoft products

greater than v. 2003 make sure you “Save As” v. 2003 to avoid any potential incompatibility issues.

• If more than one offer you must submit each file with a unique name to ensure Offer differentiation

2008 All Source Participants Workshop June 19, 2008

Appendix I1: Market Valuation Sheet - Header

1

2

2008 All Source Participants Workshop June 19, 2008

Appendix I1: Market Valuation Sheet - HeaderLong-term Request for Offers Market Valuation Data SheetHeader

1Seller:

Plant Address:

Technology Type:

Fuel Type:Fuel Delivery Point*:

Power Delivery Location*:

Seller Information1111 Sample Street, SampleCity, CA 99999

Natural GasOBSF

* Participants should provide textual descriptions. PG&E will replace with a “mapping code”.

Number of Units:

Combined Cycle (many-on-1)Combined Cycle (1-on-1)

Number of Units:

Combustion Turbine (multiple CTs)Combustion Turbine (1 CT)Reciprocating Engine (multiple units)

Number of Units:

Reciprocating Engine (1 unit)OtherCombined Cycle (many-on-1)

Number of Units: 2

Must Take: X

Type of Constraints:

Annual:

Q1:

Q2:

Q3:

Q4:

Daily:

Energy

Energy

Energy

Energy

Energy

Energy

Seller Information1111 Sample Street, SampleCity, CA, 99999

Natural GasOBSF

* Participants should provide textual descriptions. PG&E will replace with a "mapping code".

Number of Units 2 The number of units (CTs) if the plant consists of multiple units

(deliver power and consume fuel) regardless of prevailing economics.

Annual NOX (lbs)

Q1 Energy (GWh)

Q2 Energy (GWh)

Q3 Energy (GWh)

Q4 Energy (GWh)

Daily Energy (GWh)

Check the box if the index pricing applies to the Capacity Payments ($/kw-yr)

Indexed Portion 60% % of Capacity Payments subject to indexingIndexing End Date 10/1/2009 Construction Financing Date (The end date before which the Capacity Payments are subject to index)

Check the box if the index pricing applies to the Energy Payments ($/MWh)Check the box if the index pricing applies to the Fixed O&M ($/kw-yr)Check the box if the index pricing applies to the Fired Hour Charge ($/fired hour)Check the box if the index pricing applies to the Variable O&M ($/MWh)

Combined Cycle (many-on-1)Seller Information1111 Sample Street, SampleCity, CA, 99999

Natural GasOBSF

* Participants should provide textual descriptions. PG&E will replace with a "mapping code".

Number of Units 2 The number of units (CTs) if the plant consists of multiple units

(deliver power and consume fuel) regardless of prevailing economics.

Annual NOX (lbs)

Q1 Energy (GWh)

Q2 Energy (GWh)

Q3 Energy (GWh)

Q4 Energy (GWh)

Daily Energy (GWh)

Check the box if the index pricing applies to the Capacity Payments ($/kw-yr)

Indexed Portion 60% % of Capacity Payments subject to indexingIndexing End Date 10/1/2009 Construction Financing Date (The end date before which the Capacity Payments are subject to index)

Check the box if the index pricing applies to the Energy Payments ($/MWh)Check the box if the index pricing applies to the Fixed O&M ($/kw-yr)Check the box if the index pricing applies to the Fired Hour Charge ($/fired hour)Check the box if the index pricing applies to the Variable O&M ($/MWh)

Combined Cycle (many-on-1)Seller Information1111 Sample Street, SampleCity, CA, 99999

Natural GasOBSF

* Participants should provide textual descriptions. PG&E will replace with a "mapping code".

Number of Units 2 The number of units (CTs) if the plant consists of multiple units

(deliver power and consume fuel) regardless of prevailing economics.

Annual NOX (lbs)

Q1 Energy (GWh)

Q2 Energy (GWh)

Q3 Energy (GWh)

Q4 Energy (GWh)

Daily Energy (GWh)

Check the box if the index pricing applies to the Capacity Payments ($/kw-yr)

Indexed Portion 60% % of Capacity Payments subject to indexingIndexing End Date 10/1/2009 Construction Financing Date (The end date before which the Capacity Payments are subject to index)

Check the box if the index pricing applies to the Energy Payments ($/MWh)Check the box if the index pricing applies to the Fixed O&M ($/kw-yr)Check the box if the index pricing applies to the Fired Hour Charge ($/fired hour)Check the box if the index pricing applies to the Variable O&M ($/MWh)

Combined Cycle (many-on-1)Seller Information1111 Sample Street, SampleCity, CA, 99999

Natural GasOBSF

* Participants should provide textual descriptions. PG&E will replace with a "mapping code".

Number of Units 2 The number of units (CTs) if the plant consists of multiple units

(deliver power and consume fuel) regardless of prevailing economics.

Annual NOX (lbs)

Q1 Energy (GWh)

Q2 Energy (GWh)

Q3 Energy (GWh)

Q4 Energy (GWh)

Daily Energy (GWh)

Check the box if the index pricing applies to the Capacity Payments ($/kw-yr)

Indexed Portion 60% % of Capacity Payments subject to indexingIndexing End Date 10/1/2009 Construction Financing Date (The end date before which the Capacity Payments are subject to index)

Check the box if the index pricing applies to the Energy Payments ($/MWh)Check the box if the index pricing applies to the Fixed O&M ($/kw-yr)Check the box if the index pricing applies to the Fired Hour Charge ($/fired hour)Check the box if the index pricing applies to the Variable O&M ($/MWh)

Combined Cycle (many-on-1)Seller Information1111 Sample Street, SampleCity, CA, 99999

Natural GasOBSF

* Participants should provide textual descriptions. PG&E will replace with a "mapping code".

Number of Units 2 The number of units (CTs) if the plant consists of multiple units

(deliver power and consume fuel) regardless of prevailing economics.

Annual NOX (lbs)

Q1 Energy (GWh)

Q2 Energy (GWh)

Q3 Energy (GWh)

Q4 Energy (GWh)

Daily Energy (GWh)

Check the box if the index pricing applies to the Capacity Payments ($/kw-yr)

Indexed Portion 60% % of Capacity Payments subject to indexingIndexing End Date 10/1/2009 Construction Financing Date (The end date before which the Capacity Payments are subject to index)

Check the box if the index pricing applies to the Energy Payments ($/MWh)Check the box if the index pricing applies to the Fixed O&M ($/kw-yr)Check the box if the index pricing applies to the Fired Hour Charge ($/fired hour)Check the box if the index pricing applies to the Variable O&M ($/MWh)

Combined Cycle (many-on-1)Seller Information1111 Sample Street, SampleCity, CA, 99999

Natural GasOBSF

* Participants should provide textual descriptions. PG&E will replace with a "mapping code".

Number of Units 2 The number of units (CTs) if the plant consists of multiple units

(deliver power and consume fuel) regardless of prevailing economics.

Annual NOX (lbs)

Q1 Energy (GWh)

Q2 Energy (GWh)

Q3 Energy (GWh)

Q4 Energy (GWh)

Daily Energy (GWh)

Check the box if the index pricing applies to the Capacity Payments ($/kw-yr)

Indexed Portion 60% % of Capacity Payments subject to indexingIndexing End Date 10/1/2009 Construction Financing Date (The end date before which the Capacity Payments are subject to index)

Check the box if the index pricing applies to the Energy Payments ($/MWh)Check the box if the index pricing applies to the Fixed O&M ($/kw-yr)Check the box if the index pricing applies to the Fired Hour Charge ($/fired hour)Check the box if the index pricing applies to the Variable O&M ($/MWh)

Combined Cycle (many-on-1)

Energy (GWh)

Energy (GWh)

Energy (GWh)

Energy (GWh)

Energy (GWh)

Energy (GWh)

Energy

NOX NOX (lbs)SO2 SO2 (lbs)CO CO (lbs)CO2 CO2 (million lbs)PM10 PM10 (lbs)Fired Hrs Fired HoursNOX NOX (lbs)

Seller Information1111 Sample Street, SampleCity, CA, 99999

Natural GasOBSF

* Participants should provide textual descriptions. PG&E will replace with a "mapping code".

Number of Units 2 The number of units (CTs) if the plant consists of multiple units

(deliver power and consume fuel) regardless of prevailing economics.

Annual NOX (lbs)

Q1 Energy (GWh)

Q2 Energy (GWh)

Q3 Energy (GWh)

Q4 Energy (GWh)

Daily Energy (GWh)

Check the box if the index pricing applies to the Capacity Payments ($/kw-yr)

Indexed Portion 60% % of Capacity Payments subject to indexingIndexing End Date 10/1/2009 Construction Financing Date (The end date before which the Capacity Payments are subject to index)

Check the box if the index pricing applies to the Energy Payments ($/MWh)Check the box if the index pricing applies to the Fixed O&M ($/kw-yr)Check the box if the index pricing applies to the Fired Hour Charge ($/fired hour)Check the box if the index pricing applies to the Variable O&M ($/MWh)

Combined Cycle (many-on-1)

Check the box if the contract is must-take, which means (deliver power and consume fuel)Regarding of prevailing economics.

2008 All Source Participants Workshop June 19, 2008

Appendix I1: Market Valuation Sheet - HeaderLong-term Request for Offers Market Valuation Data SheetHeader

2 Index Pricing: X Check the box if Index Pricing applies to the Capacity

Index Portion: 60 % of Capacity Payments Subject to indexing

Index End Date: 10/1/’09Construction Financing Date (the end date before which the Capacity Payments are subject to index)

X Check the box if the index pricing applies to the Energy Payments ($/MWh)

Check the box if the index pricing applies to the Fixed O&M ($/kw-yr) X

Check the box if the index pricing applies to the Fired Hour Charge ($/fired-hour)

Check the box if the index pricing applies to the Variable O&M ($/MWh)

X

X

2008 All Source Participants Workshop June 19, 2008

Appendix I1: Market Valuation Sheet – Heat RateLong-term Request for Offers Market Valuation Data SheetHeat Rate Seller:

Plant Address:Technology Type:

Fuel Type:Fuel Delivery Point*:

Power Delivery Location*:

Seller Information1111 Sample Street, SampleCity, CA 99999

Natural GasOBSF

CC

Contract Capacity Under Expected Operating Conditions(including Duct Firing and Power Augmentation Capacity if applicable)

(Positive during the term of the contract. Enter blanks outside the term of the contract). Calendar

yearJan.

(MWs)Feb.

(MWs)Mar.

(MWs)Apr.

(MWs)May

(MWs)Jun.

(MWs)Jul.

(MWs)Aug.

(MWs)Sep.

(MWs)Oct.

(MWs)Nov.

(MWs)Dec.

(MWs)

1 20092 20103 20114 2012 510 509 507 505 500 485 470 486 490 495 500 5105 2013 495 494 492 490 485 470 456 471 475 480 485 4956 2014 485 484 482 480 475 461 447 462 466 471 475 4857 2015 480 479 477 475 471 456 442 457 461 466 471 4808 2016 480 479 477 475 471 456 442 457 461 466 471 4809 2017 470 469 468 466 461 447 433 448 452 457 461 470

10 2018 461 460 458 456 452 438 425 439 443 447 452 46111 2019 452 451 449 447 443 430 416 430 434 438 443 45212 2020 447 446 445 443 438 425 412 426 430 434 438 44713 2021 438 437 436 434 430 417 404 418 421 425 430 438

2008 All Source Participants Workshop June 19, 2008

Appendix I1: Market Valuation Sheet – Heat RateLong-term Request for Offers Market Valuation Data SheetHeat Rate Seller:

Plant Address:Technology Type:

Fuel Type:Fuel Delivery Point*:

Power Delivery Location*:

Seller Information1111 Sample Street, SampleCity, CA 99999

Natural GasOBSF

CC

Net Contract Heat Rate at ISO Conditions (all units on)MMBtus/MWh (HHV) @

Calendar year

Heat RateMWs

Heat RateMWs

Heat RateMWs

Heat RateMWs

Heat RateMWs

Heat RateMWs

Heat RateMWs

1 20092 20103 20114 2012 7.50 500.0 7.00 480.00 7.50 422.50 7.70 365.00 8.00 307.50 8.50 250.00 5 2013 7.54 485.0 7.04 465.00 7.54 409.38 7.74 353.75 8.04 298.13 8.54 242.50 6 2014 7.58 475.3 7.07 455.30 7.58 400.89 7.78 346.48 8.08 292.06 8.59 237.65 7 2015 7.61 470.5 7.11 450.55 7.61 396.73 7.82 342.91 8.12 289.09 8.63 235.27 8 2016 7.65 470.5 7.14 450.55 7.65 396.73 7.86 342.91 8.16 289.09 8.67 235.27 9 2017 7.69 461.1 7.18 441.14 7.69 388.49 7.89 335.85 8.20 283.21 8.71 230.57

10 2018 7.73 451.9 7.21 431.91 7.73 380.42 7.93 328.94 8.24 277.45 8.76 225.96 11 2019 7.77 442.9 7.25 422.88 7.77 372.52 7.97 322.16 8.28 271.80 8.80 221.44 12 2020 7.81 438.4 7.28 418.45 7.81 368.64 8.01 318.83 8.33 269.03 8.85 219.22 13 2021 7.84 429.7 7.32 409.68 7.84 360.97 8.05 312.26 8.37 263.55 8.89 214.84

Med-LowMinimumOutput

Max Output with Duct Firing

Max Output Med-High MedMax Output with DF

and PA

2008 All Source Participants Workshop June 19, 2008

Appendix I1: Market Valuation Sheet – Heat RateLong-term Request for Offers Market Valuation Data SheetHeat Rate Seller:

Plant Address:Technology Type:

Fuel Type:Fuel Delivery Point*:

Power Delivery Location*:

Seller Information1111 Sample Street, SampleCity, CA 99999

Natural GasOBSF

CC

Net Contract Heat Rate at Peak July Conditions (all units on)MMBtus/MWh (HHV) @

Calendar year

Heat Rate

MWsHeat Rate

MWsHeat Rate

MWsHeat Rate

MWsHeat Rate

MWsHeat Rate

MWsHeat Rate

MWs

1 20092 20103 20114 2012 7.73 465.3 7.21 445.3 7.73 371.50 7.93 262.50 8.24 153.75 8.76 45.05 2013 7.76 451.3 7.25 431.3 7.76 371.50 7.97 262.50 8.28 153.75 8.80 45.06 2014 7.80 442.3 7.28 422.3 7.80 371.50 8.01 262.50 8.32 153.75 8.84 45.07 2015 7.84 437.9 7.32 417.9 7.84 371.50 8.05 262.50 8.36 153.75 8.89 45.08 2016 7.88 437.9 7.36 417.9 7.88 371.50 8.09 262.50 8.41 153.75 8.93 45.09 2017 7.92 429.1 7.39 409.1 7.92 371.50 8.13 262.50 8.45 153.75 8.98 45.0

10 2018 7.96 420.6 7.43 400.6 7.96 371.50 8.17 262.50 8.49 153.75 9.02 45.011 2019 8.00 412.1 7.47 392.1 8.00 371.50 8.21 262.50 8.53 153.75 9.07 45.012 2020 8.04 408.0 7.50 388.0 8.04 371.50 8.25 262.50 8.58 153.75 9.11 45.013 2021 8.08 399.9 7.54 379.9 8.08 371.50 8.30 262.50 8.62 153.75 9.16 45.0

Max Output with DF and PA

Max Output with Duct Firing

Max Output Med-High Med Med-LowMinimumOutput

2008 All Source Participants Workshop June 19, 2008

Appendix I1: Market Valuation Sheet – Heat RateLong-term Request for Offers Market Valuation Data SheetHeat Rate Seller:

Plant Address:Technology Type:

Fuel Type:Fuel Delivery Point*:

Power Delivery Location*:

Seller Information1111 Sample Street, SampleCity, CA 99999

Natural GasOBSF

CC

Net Contract Heat Rate at ISO Conditions (1 unit on)MMBtus/MWh (HHV) @

Calendar year

Heat RateMWs

Heat RateMWs

Heat RateMWs

Heat RateMWs

Heat RateMWs

Heat RateMWs

Heat RateMWs

1 20092 20103 20114 2012 7.50 250.0 7.00 240.0 7.50 211.3 7.70 182.5 8.00 153.8 8.50 125.05 2013 7.54 242.5 7.04 232.5 7.54 204.7 7.74 176.9 8.04 149.1 8.54 121.36 2014 7.58 237.7 7.07 227.7 7.58 200.4 7.78 173.2 8.08 146.0 8.59 118.87 2015 7.61 235.3 7.11 225.3 7.61 198.4 7.82 171.5 8.12 144.5 8.63 117.68 2016 7.65 235.3 7.14 225.3 7.65 198.4 7.86 171.5 8.16 144.5 8.67 117.69 2017 7.69 230.6 7.18 220.6 7.69 194.2 7.89 167.9 8.20 141.6 8.71 115.3

10 2018 7.73 226.0 7.21 216.0 7.73 190.2 7.93 164.5 8.24 138.7 8.76 113.011 2019 7.77 221.4 7.25 211.4 7.77 186.3 7.97 161.1 8.28 135.9 8.80 110.712 2020 7.81 219.2 7.28 209.2 7.81 184.3 8.01 159.4 8.33 134.5 8.85 109.613 2021 7.84 214.8 7.32 204.8 7.84 180.5 8.05 156.1 8.37 131.8 8.89 107.4

Max Output with DF and PA

Max Output with Duct Firing

Max Output Med-High Med Med-LowMinimumOutput

2008 All Source Participants Workshop June 19, 2008

Appendix I1: Market Valuation Sheet – Heat RateLong-term Request for Offers Market Valuation Data SheetHeat Rate Seller:

Plant Address:Technology Type:

Fuel Type:Fuel Delivery Point*:

Power Delivery Location*:

Seller Information1111 Sample Street, SampleCity, CA 99999

Natural GasOBSF

CC

Net Contract Heat Rate at Peak July Conditions (1 unit on)MMBtus/MWh (HHV) @

Calendar year

Heat RateMWs

Heat RateMWs

Heat RateMWs

Heat RateMWs

Heat RateMWs

Heat RateMWs

Heat RateMWs

1 20092 20103 20114 2012 7.73 232.7 7.21 222.7 7.73 185.8 7.93 131.3 8.24 76.9 8.76 22.55 2013 7.76 225.7 7.25 215.7 7.76 185.8 7.97 131.3 8.28 76.9 8.80 22.56 2014 7.80 221.2 7.28 211.2 7.80 185.8 8.01 131.3 8.32 76.9 8.84 22.57 2015 7.84 218.9 7.32 208.9 7.84 185.8 8.05 131.3 8.36 76.9 8.89 22.58 2016 7.88 218.9 7.36 208.9 7.88 185.8 8.09 131.3 8.41 76.9 8.93 22.59 2017 7.92 214.6 7.39 204.6 7.92 185.8 8.13 131.3 8.45 76.9 8.98 22.5

10 2018 7.96 210.3 7.43 200.3 7.96 185.8 8.17 131.3 8.49 76.9 9.02 22.511 2019 8.00 206.1 7.47 196.1 8.00 185.8 8.21 131.3 8.53 76.9 9.07 22.512 2020 8.04 204.0 7.50 194.0 8.04 185.8 8.25 131.3 8.58 76.9 9.11 22.513 2021 8.08 199.9 7.54 189.9 8.08 185.8 8.30 131.3 8.62 76.9 9.16 22.5

Max Output with Duct Firing

Med-LowMinimumOutput

Max Output Med-High MedMax Output with DF

and PA

2008 All Source Participants Workshop June 19, 2008

Appendix I1: Market Valuation Sheet – CharacteristicsLong-term Request for Offers Market Valuation Data SheetCharacteristics Seller:

Plant Address:Technology Type:

Fuel Type:Fuel Delivery Point*:

Power Delivery Location*:

Seller Information1111 Sample Street, SampleCity, CA 99999

Natural GasOBSF

CC

Calendar year

Equivalent Forced

Outage Rate in Summer

(%)

Equivalent Forced Outage Rate in Winter

(%)

Maximum Ramp Rate (MWs/Min)

Minimum UpTime after start (Hours)

Minimum DownTime

after shutdown (Hours)

Cold Start Fuel

(MMBtus)

Warm Start Fuel

(MMBtus)

Hot Start Fuel

(MMBtus)Cold Start Cost ($s)

Warm Start Cost ($s)

Hot Start Cost ($s)

Cold Start Time

(minutes)

Warm Start Time

(minutes)

Hot Start Time

(minutes)

Cold Start Shut Down

Time (> # Hours)

Hot Start Shut Down

Time (< # Hours)

1 20092 20103 20114 2012 2.0% 4.0% 20 1 1 3,500 2,200 1,200 1,500 750 500 240 180 90 48 85 2013 2.0% 4.0% 20 1 1 3,500 2,200 1,200 1,500 750 500 240 180 90 48 86 2014 2.0% 4.0% 20 1 1 3,500 2,200 1,200 1,500 750 500 240 180 90 48 87 2015 2.0% 4.5% 20 1 1 3,500 2,200 1,200 1,500 750 500 240 180 90 48 88 2016 2.0% 4.5% 20 1 1 3,500 2,200 1,200 1,500 750 500 240 180 90 48 89 2017 2.0% 4.5% 20 1 1 3,500 2,200 1,200 1,500 750 500 240 180 90 48 8

10 2018 2.0% 5.0% 20 1 1 3,500 2,200 1,200 1,500 750 500 240 180 90 48 811 2019 2.0% 5.0% 20 1 1 3,500 2,200 1,200 1,500 750 500 240 180 90 48 812 2020 2.0% 6.0% 20 1 1 3,500 2,200 1,200 1,500 750 500 240 180 90 48 813 2021 2.0% 6.0% 20 1 1 3,500 2,200 1,200 1,500 750 500 240 180 90 48 8

Operating Characteristics of the Contract or Plant Operating Characteristics of the Contract or Plant

2008 All Source Participants Workshop June 19, 2008

Appendix I1: Market Valuation Sheet – CharacteristicsLong-term Request for Offers Market Valuation Data SheetCharacteristics Seller:

Plant Address:Technology Type:

Fuel Type:Fuel Delivery Point*:

Power Delivery Location*:

Seller Information1111 Sample Street, SampleCity, CA 99999

Natural GasOBSF

CC

Maintenance Hours Required per MonthCalendar

year Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

1 20092 20103 20114 2012 2805 2013 2806 2014 2807 2015 2808 2016 280 8009 2017 280

10 2018 28011 2019 28012 2020 28013 2021 280

Additional Annual Hours

2008 All Source Participants Workshop June 19, 2008

Calendar year

when PG&E takes GHG risk

when the Seller takes GHG risk For Duct Firing

1 20092 20103 20114 2012 100.00 101.00 5.00 100.00 2.00 3.00 5 2013 103.00 104.03 5.00 100.00 2.06 3.09 6 2014 106.09 107.15 5.00 100.00 2.12 3.18 7 2015 109.27 110.37 5.00 100.00 2.19 3.28 8 2016 112.55 113.68 5.00 100.00 2.25 3.38 9 2017 115.93 117.09 5.00 100.00 2.32 3.48

10 2018 119.41 120.60 5.00 100.00 2.39 3.58 11 2019 122.99 124.22 5.00 100.00 2.46 3.69 12 2020 126.68 127.94 5.00 100.00 2.53 3.80 13 2021 130.48 131.78 5.00 100.00 2.61 3.91

Capacity Payments ($/kw-yr)

Appendix I1: Market Valuation Sheet – CompensationLong-term Request for Offers Market Valuation Data SheetCompensation Seller:

Plant Address:Technology Type:

Fuel Type:Fuel Delivery Point*:

Power Delivery Location*:

Seller Information1111 Sample Street, SampleCity, CA 99999

Natural GasOBSF

CC

5.00 10.00 2.00 5.00 10.00 2.06 5.00 10.00 2.12 5.00 10.00 2.19 5.00 10.00 2.25 5.00 10.00 2.32 5.00 10.00 2.39 5.00 10.00 2.46 5.00 10.00 2.53 5.00 10.00 2.61

Fixed O&M ($/kw-Year)

Fired Hour Charge Per Hour with One

Unit On ($/Unit fired hour)

Energy Payments ($/MWh)

For Base Load (Max Output) For Duct Firing

For Power Augmentation

1 20092 20103 20114 2012 100.00 101.00 5.00 100.00 2.00 3.00 5 2013 103.00 104.03 5.00 100.00 2.06 3.09 6 2014 106.09 107.15 5.00 100.00 2.12 3.18 7 2015 109.27 110.37 5.00 100.00 2.19 3.28 8 2016 112.55 113.68 5.00 100.00 2.25 3.38 9 2017 115.93 117.09 5.00 100.00 2.32 3.48

10 2018 119.41 120.60 5.00 100.00 2.39 3.58 11 2019 122.99 124.22 5.00 100.00 2.46 3.69 12 2020 126.68 127.94 5.00 100.00 2.53 3.80 13 2021 130.48 131.78 5.00 100.00 2.61 3.91

Variable O&M ($/MWh)

Fired Hour Charge Per Hour with One

Unit On ($/Unit fired hour)

2008 All Source Participants Workshop June 19, 2008

Appendix I1: Market Valuation Sheet – EmissionsLong-term Request for Offers Market Valuation Data SheetEmissions Seller:

Plant Address:Technology Type:

Fuel Type:Fuel Delivery Point*:

Power Delivery Location*:

Seller Information1111 Sample Street, SampleCity, CA 99999

Natural GasOBSF

CC

Calendar year NOX SO2 CO CO2 PM10 NOX SO2 CO CO2 PM10 NOX SO2 CO CO2 PM10 NOX SO2 CO CO2 PM10 NOX SO2 CO CO2 PM10

1 20092 20103 20114 2012 60 6 60 120,000 6 50 5 50 100,000 5 10 1 10 10,000 1 10 1 10 10,000 1 5 2013 60 6 60 120,000 6 50 5 50 100,000 5 10 1 10 10,000 1 10 1 10 10,000 1 6 2014 60 6 60 120,000 6 50 5 50 100,000 5 10 1 10 10,000 1 10 1 10 10,000 1 7 2015 60 6 60 120,000 6 50 5 50 100,000 5 10 1 10 10,000 1 10 1 10 10,000 1 8 2016 60 6 60 120,000 6 50 5 50 100,000 5 10 1 10 10,000 1 10 1 10 10,000 1 9 2017 60 6 60 120,000 6 50 5 50 100,000 5 10 1 10 10,000 1 10 1 10 10,000 1

10 2018 60 6 60 120,000 6 50 5 50 100,000 5 10 1 10 10,000 1 10 1 10 10,000 1 11 2019 60 6 60 120,000 6 50 5 50 100,000 5 10 1 10 10,000 1 10 1 10 10,000 1 12 2020 60 6 60 120,000 6 50 5 50 100,000 5 10 1 10 10,000 1 10 1 10 10,000 1 13 2021 60 6 60 120,000 6 50 5 50 100,000 5 10 1 10 10,000 1 10 1 10 10,000 1

Emissions per Warm Start (lbs/start)Emissions at Max. Operational

Cap. with DF & Power Augmentation (lbs./hour)

Emissions at Max.Operational Capacity with Duct Firing (lbs./hour)

Emissions at Maximum Operational Capacity (lbs./hour)

Emissions per Hot Start (lbs/start)

2008 All Source Participants Workshop June 19, 2008

Appendix I1: Market Valuation Sheet – ConstraintsLong-term Request for Offers Market Valuation Data SheetConstraints Seller:

Plant Address:Technology Type:

Fuel Type:Fuel Delivery Point*:

Power Delivery Location*:

Seller Information1111 Sample Street, SampleCity, CA 99999

Natural GasOBSF

CC

Annual

Calendar year Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

Annual Limit NOX (lbs)

Q1Limit Energy (GWh)

Q2 Limit Energy (GWh)

Q3 Limit Energy (GWh)

Q4 Limit Energy (GWh)

Cold Start Number

Allowed Per year

Warm Start Number

Allowed Per year

Hot Start Number

Allowed Per year

1 20092 20103 20114 2012 1100 1100 1100 1100 50 100 1505 2013 1100 1100 1100 1100 50 100 1506 2014 1100 1100 1100 1100 50 100 1507 2015 1100 1100 1100 1100 50 100 1508 2016 1100 1100 1100 1100 50 100 1509 2017 1100 1100 1100 1100 50 100 150

10 2018 1100 1100 1100 1100 50 100 15011 2019 1100 1100 1100 1100 50 100 15012 2020 1100 1100 1100 1100 50 100 15013 2021 1100 1100 1100 1100 50 100 150

Daily Constraints on Energy (GWh) (Leave blank if no constraint.) Quarterly Starts per Year

Annual Limit Energy (GWh)

2008 All Source Participants Workshop June 19, 2008

Appendix I1: Market Valuation Sheet – Ancillary ServicesLong-term Request for Offers Market Valuation Data SheetAncillary Services Seller:

Plant Address:Technology Type:

Fuel Type:Fuel Delivery Point*:

Power Delivery Location*:

Seller Information1111 Sample Street, SampleCity, CA 99999

Natural GasOBSF

CC

Calendar year

Spinning Reserve (Max

MWs)

Non-Spinning Reserve

(Max MWs)

Regulating Reserves

(Max MWs)

1 20092 20103 20114 2012 125 50 255 2013 125 50 256 2014 125 50 257 2015 125 50 258 2016 125 50 259 2017 125 50 25

10 2018 125 50 2511 2019 125 50 2512 2020 125 50 2513 2021 125 50 25

Ancillary Services

2008 All Source Participants Workshop June 19, 2008

Appendix F: Power Purchase Agreement Modifications

Reference Revision Description

Appendix II Page 2 - Capacity Table

Appendix XIIPages 1 & 2

Appendix XIIIHeader and Deviation - Amount of Over (Under) deliveryCase 3 & 4

Appendix XIVHeader

Humidity

Price of Gas

Reference to 3.5(c)

Increased deviation amount

Reference to 3.13(d)(ii)

Spelling

Clarification of the components that make up the Price of Gas when Actual Gas is greater than or lower than the Expected Gas.

Previous reference to 3.5(d) corrected to 3.5(c).

Increased deviation amount from 10 to 25 to better reflect the CAISO band of the greater of 5 MW or 3% of Pmax. This example assumes aPmax amount of 500 MW and a 3% tolerance band of 15MW.

 

Corrected reference format. 

2008 All Source Participants Workshop June 19, 2008

Appendix F: Power Purchase Agreement Modifications

Reference Revision Description

Appendix XVExample 4.3(d) Equation

Appendix XVI 4.2(a) Table

4.2(c) (iii) Equation

Appendix XVIIPages 1 & 2

Monthly Fixed Payment

Reference to Appendix II

Reference to 4.2(c) (iii)

Monthly Fixed Payment

Corrected Monthly Fixed Payment (MFP) equation to include Fixed O&M rate (FOMR).

Corrected reference from App. B to App. II.

Modified reference from 4.2(a) (iii) to 4.2(c) (iii) and inserted reference to Note section at the bottom of the page.

Added Fixed O&M Rate to illustration and corrected equation.