Crisis Communications Procedures

Appendix E: In-Bound Calls Treatment Crisis Communications Procedures

150 CALL TREATMENT FOR EMERGENCY/CRISIS SITUATION

During a major event resulting in a high volume of incoming calls to the general ERCOT numbers, Client Services will implement and staff an emergency call center to handle incoming calls.

Corporate Communications will notify the Security Desk to forward main incoming extensions 3000 and 7000 to 4600 - an emergency phone tree. The Facilities Security Manager or Site Supervisor may initiate as needed if Corporate Communications is unavailable.

Calls that require responses and are not from media or government contacts will be sent to the emergency call center for handling.

Corporate Communications will record grid updates as available as a "Temporary Greeting" for the grid updates line: 2750.

For "Grid Message Mailbox" examples, see EEA examples in Appendix A-2 and a Hurricane example in Appendix B.

Details of this call treatment and access numbers are confidential.

151 ERCOT Emergency Call Treatment

Call flow treatment diagram including passwords and personal contact information has been redacted from public version.

152 Appendix F: Black Start Crisis Communications Procedures

153 BLACK START

In the event of a full system outage requiring use of the ERCOT Black Start Plan3, the Manager of System Operations will contact the Crisis Communications Team. The Communications staff will work with System Operations throughout the outage to determine the appropriate information to release to the media and public. Channels used for communication will depend on the extent of the outage and what systems are affected. Procedures defined in ERCOT's Business Continuity Plan likely would be implemented in case of a cascading blackout situation.

ERCOT will not publicly release the names of specific plants utilized in the Black Start Plan. The detailed Black Start Plan is a confidential document.

3 A high-level description of the Black Start Plan is included in ERCOT Protocols, Section 6.5.9.6. 61

154 Attachment H

Assessment of Reliability and Adequacy of the ERCOT System during Extremely Cold or Extremely Hot Weather Conditions

155 Extreme Weather Reliability Assessment

(H) An assessment of the reliability and adequacy of the ERCOT system during extremely cold or extremely hot weather conditions, including information regarding steps to be taken by power generation companies and utilities to prepare their assets for extreme weather events.

Overview

ERCOT's assessment of system reliability during extreme weather is based primarily on its summer and winter Seasonal Assessments of Resource Adequacy (SARA), which are issued on May 1 and November 1 of each year, respectively. The most recent versions of each of these reports are attached. To further assist in evaluating grid reliability during extreme weather conditions, and to verify implementation of generator weatherization procedures, ERCOT has scheduled site visits for approximately 48 generators between October 2013 and February 2014. The methodology and results of these visits are described below. Prior to starting these visits, ERCOT held a workshop in conjunction with Texas RE to highlight issues that were identified during the 2012 site visits.

Assessment of Generator Weatherization Plan Implementation

ERCOT used the following criteria to select sites for weatherization plan review this winter:

• Black start generator resources that are under contract for 2014 - 2015. • New generator resources. • Generator resources that experienced freeze issues during winter 2012 - 2013. • Generators that were undergoing improvements during previous year site visits. • A randomly selected group of generators.

ERCOT also made site visits to plants which were not originally on the list but were added because they experienced problems during cold weather in early December 2013.

In all cases, ERCOT's goal has been to determine if plants have implemented the weatherization plans they have provided. As part of these visits, ERCOT asked to see any checklists of elements that needed to be protected, whether these preparations had been completed, and whether procedures were in place to ensure that the checklists were followed.

ERCOT's review includes the following items:

• Identify the cause of the unit trip during February 2 01 1 cold weather event, if applicable. Physically examine element. Is it sufficiently protected? • Did this unit experience any equipment freeze issues due to frozen equipment during Winter 2012/2013? • Does the plant have a checklist of elements to be protected? • What type of heat tracing, if any, does the plant use on critical instrumentation? • Is there a procedure to confirm heat tracing is functioning properly? • Is there a maintenance record of amperage reading compared to design criteria?

156 • Will procedure detect if heat tracing is interrupted mid-length? • Is there a record of maintenance on instrument air? • Identify how moisture is removed from instrument air. Verify periodic blow downs, air dryers, dew point monitoring. • Have all work orders related to weatherization been completed? • Has all insulation been inspected during the Fall? • What improvements has the plant made based on experiences in February 2011? • Are winter weather supplies listed on the checklist and are they stored on-site? • Does the plant do an annual extreme cold weather drill or training? • Do the operators train for the loss of a drum level, steam flow or feedwater transmitter? • Does the unit have capability for alternate fuel? If so, when was the last time fuel oil capability tested? • Has plant management and maintenance personnel reviewed the NERC Guideline Generator Unit Winter Weather Readiness - Current Industry Practices? • Has plant management and maintenance personnel reviewed the NERC lessons learned for Resource Entities related to cold weather?

ERCOT's review of plants indicates that the majority of plants are following their weatherization plans. ERCOT has identified no plants that have substantially failed to implement their weatherization plans.

ERCOT's common recommendations to plants include: • Develop yearly records for heat trace maintenance amperage readings comparing to design criteria. • Conduct annual table top or plant drill for an extreme cold weather event with records of attendance. • Maintain records detailing when extreme cold weather procedures were put into place. • Incorporate lessons learned into plant weatherization plan.

Recommended Steps to Prepare Generators for Extreme Weather

Rule 25.362(i)(2)(H) requires ERCOT to describe "information regarding steps to be taken by power generation companies and utilities to prepare their assets for extreme weather events." Below is a list of general steps generating entities can follow to ensure their assets are prepared for extreme weather:

• Adequate maintenance and inspection of its freeze protection elements be conducted on a timely and repetitive basis. • Inspect and maintain each generating unit's heat tracing equipment. • Inspect and maintain each unit's thermal insulation. • Erect adequate wind breaks and enclosures where needed. • Develop and annually conduct winter-specific and plant-specific operator awareness and maintenance training.

157 • Take steps to ensure that winterization supplies and equipment are in place before the winter season, that adequate staffing is in place for cold weather events, and that preventative action in anticipation of such events is taken in a timely manner. • Ensure all insulating materials and wind breaks are removed before operation during the summer season.

Conclusion

Based on the most recent SARA for winter 2013/2014, ERCOT has concluded that, with a normal forced outage rate and under expected weather conditions, ERCOT should have sufficient generation capacity to serve forecasted peak demand.

ERCOT's review of plant weatherization through site visits suggests that the units visited have made progress in addressing weatherization deficiencies. These units appear to be better equipped to withstand extreme conditions such as those experienced in February 2011.

158 Seasonal Assessment of Resource Adequacy for the ERCOT Region Summer 2013

Released May 1, 2013

SUMMARY

ERCOT expects tight reserves this summer. Based on current information regarding resource availability and anticipated demand levels, there is a significant chance that ERCOT will need to declare an Energy Emergency Alert (EEA) during the summer of 2013 and issue corresponding public appeals for conservation.

If conditions warrant, ERCOT and transmission providers may need to call upon resources that have contracted to reduce demand on the system in an emergency situation, either as Load Resources, Emergency Response Service providers, or participants in other demand response programs and pilots. If a higher-than-normal number of forced generation outages occur during a period of high demand or record-breaking weather conditions similar to the summer of 2011 lead to even higher-than-expected peak demands, rotating outages could become necessary to maintain the integrity of the system as a whole.

Note that unit capacity ratings are reduced by higher ambient temperatures in the summer, resulting in a lower installed capacity relative to the amount reported for the final spring resource adequacy assessment.

ERCOT stakeholder committees are currently reviewing the Effective Load Carrying Capability (ELCC) estimates for wind generation in light of results from the recently concluded Loss-of- Load Expectation (LOLE) Study for the ERCOT Region. The potential impact of a revision to the current wind ELCC of 8.7% is not included in this seasonal assessment. If the ELCC estimates from the recent LOLE Study (14.2% for non-coastal wind generation resources and 32.9% for coastal wind generation resources) were incorporated into this spring assessment, the estimate of available resources would be increased by 926 MW.

ERCOT continues to monitor the continuing drought conditions. While reservoir levels are not expected to drop below power plant physical intake limits during summer 2013, potential risks to generation capacity persist while Texas remains in widespread drought conditions.

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161 ... Unit Code .:: Piant Name Primary Energy Smmer cap" .. ^ . . .. ^ Source W .^.. Status em e^ ^ ^^ 38 Existing AZ_AZ_G2 AIRPRO NG 38 Existing AZ_AZ_G3 AIRPRO NG 38 Existing Key to Abbreviations A_AZ_G4 AIRPRO NG 38 Existing BID Biomass AMISTAD_AMISTAG1 AMISTAD WAT 38 Existing BIT AMISTAD_AMISTAG2 Bituminous Coal AMISTAD WAT 38 Existing LFG Land-fill Gas APD_APD_PS1 APPLIED ENERGY NA 1 Existing LIG HB_DG1 Lignite Coal ATASCOCITA LFG 10 Nonmod MTE Methanol ATKINS_ATKINSG7 ATKINS NG 20 Existing MTH DG_SPRIN_4UNITS Methane AUSTIN LANDFILL GAS UNK 6 Nonmod NG Natural Gas AUSTPL_AUSTING1 AUSTIN PLANT WAT 8 Existing NUC AUSTPL_AUSTING2 Nuclear AUSTIN PLANT WAT 9 Existing OG Other Gas B_DAVIS_B_DAVIG1 BARNEY DAVIS NG 335 Existing OTH B_DAVIS_B_DAVIG2 Other BARNEY DAVIS NG 319 Existing PC Pulverized Coal B_DAVIS_B_DAVIG3 BARNEY DAVIS NG 157 Existing SUB B_DAVIS_ _ Sub-bituminous Coal B DAVIG4 BARNEY DAVIS NG 157 Existing SUN Sun (Solar Resource) BASTEN_GTG1100 BASTROP ENERGY CENTER NG 150 Existing UNK BASTEN_GTG2100 Unknown BASTROP ENERGY CENTER NG 150 Existing WAT Water (Hydro Resource) BASTEN_STOS00 BASTROP ENERGY CENTER WH 233 Existing WDS TRN_DG1 Wood Biomass BAYTOWN MTH 4 Nonmod WH Waste Heat BBSES_UNIT1 BIG BROWN SES LIG 600 Existing WND BBSES_UNIT2 Wind BIG BROWN SES LIG 595 Existing NA Unknown CARBN_BSP_1 BIG SPRING WH 18 Existing DG BIOE_2UNITS BID ENERGY PARTNERS NG 6 Nonmod - °° DG_BROOK_1UNIT BLUE WING SOLAR I Note^Capacity information is current as of 4/19/2013 SUN 8 Nonmod _ _ ...# DG_ELMEN_1UNIT BLUE WING SOLAR 2 SUN 7 Nonmod ^ LB_DG1 BLUEBONNET LFG 4 Nonmod BOSQUESW_BSQSU_1 BOSQUE SWITCH NG 149 Existing BOSQUESW_BSQSU_2 BOSQUE SWITCH NG 149 Existing BOSQUESW_BSQSU_3 BOSQUE SWITCH NG 145 Existing BOSQUESW_BSQSU_4 BOSQUE SWITCH WH 78 Existing BOSQUESW BSQSU_5 BOSQUE SWITCH WH 205 Existing BVE_UNIT1 BRAZOS VALLEY ENERGY LP NG 166 Existing BVE_UNIT2 BRAZOS VALLEY ENERGY LP NG 166 Existing BVE_UNIT3 BRAZOS VALLEY ENERGY LP NG 270 Existing BUCHAN_BUCHANG1 BUCHANAN WAT 16 Existing BUCHAN_BUCHANG2 BUCHANAN WAT 16 Existing BUCHAN_BUCHANG3 BUCHANAN WAT 17 Existing FLCNS_UNIT1 CALENERGY NG 75 Existing FLCNS_UNIT2 CAL ENERGY NG 75 Existing FLCNS_UNIT3 CALENERGY NG 70 Existing CALAVERS_OW51 CALAVERAS NG 420 Existing CALAVERS_OW52 CALAVERAS NG 420 Existing CALAVERS_JKSl CALAVERAS SUB 555 Existing CALAVERS_1KS2 CALAVERAS SUB 775 Existing CALAVERS_JTD1 CALAVERAS SUB 425 Existing CALAVERS_1TD2 CALAVERAS SUB 420 Existing CANYHy_CANYHYGI CANYON WAT 6 Nonmod CBY4_CT41 CEDAR BAYOU 4 NG 163 Existing CBY4_CT42 CEDAR BAYOU 4 NG 163 Existing CBY4_ST04 CEDAR BAYOU 4 NG 178 Existing CBY_CBY_G1 CEDAR BAYOU PLANT NG 745 Existing CBY_CBY_G2 CEDAR BAYOU PLANT NG 749 Existing CVC_CVC_G1 CHANNELVIEW COGEN NG 156 Existing CVC CVC_G2 CHANNELVIEW COGEN NG 158 Existing CVC_CVC_G3 CHANNELVIEW COGEN NG 160 Existing CVC_CVC_G5 CHANNELVIEW COGEN NG 122 Existing AV_DG1 COASTAL PLAINS RDF LFG 7 Nonmod COLETO_COLETOG1 COLETO CREEK SUB 650 Existing CBEC_GT1 COLORADO BEND ENERGY CENTER NG 76 Existing CBEC_GT2 COLORADO BEND ENERGY CENTER NG 69 Existing CBEC GT3 COLORADO BEND ENERGY CENTER NG 72 Existing CBEC_GT4 COLORADO BEND ENERGY CENTER NG 72 Existing CBEC_STG1 COLORADO BEND ENERGY CENTER NG 103 Existing CBEC_STG2 COLORADO BEND ENERGY CENTER NG 106 Existing CPSES_UNIT1 COMANCHE PEAK SES NUC 1205 Existing CPSES_UNIT2 COMANCHE PEAK SES NUC 1195 Existing DG_MEDIN_1UNIT COVEL GARDENS LG POWER STATION LINK 10 Nonmod DANSBY_DANSBYG1 DANSBY NG 110 Existing DANSBY_DANSBYG2 DANSBY NG 48 Existing DANSBY_DANSBYG3 DANSBY NG 48 Existing DECKER_DPG1 DECKER POWER PLANT NG 315 Existing DECKER_DPG2 DECKER POWER PLANT NG 420 Existing DECKER_DPGT_1 DECKER POWER PLANT NG 48 Existing DECKER_DPGT_2 DECKER POWER PLANT NG 48 Existing DECKER_DPGT_3 DECKER POWER PLANT NG 48 Existing DECKER_DPGT_4 DECKER POWER PLANT NG 48 Existing DCSES_CT10 DECORDOVA SES CONSTELLATION NG 71 Existing DCSES_CT20 DECORDOVA SES CONSTELLATION NG 70 Existing DCSES_Cf30 DECORDOVA SES CONSTELLATION NG 69 Existing

162 Primary Energy $urraner Capacity Unit Code Plain Nartre Slatm Source (mm

DCSES_CF40 DECORDOVA SES CONSTELLATION NG 68 Existing DDPEC_GT1 DEER PARK ENERGY CENTER NG 183 Existing DDPEC_GT2 DEER PARK ENERGY CENTER NG 199 Existing DDPEC_GT3 DEER PARK ENERGY CENTER NG 183 Existing DDPEC_GT4 DEER PARK ENERGY CENTER NG 199 Existing DDPEC_STI DEER PARK ENERGY CENTER WH 290 Existing DNDAM_DENISOG1 DENISON DAM WAT 40 Existing DNDAM_DENISOG2 DENISON DAM WAT 40 Existing DG_BI02_4UNITS DFW GAS RECOVERY LFG 6 Nonmod DUKE_DUKE_GT1 DUKE (NOW HIDALGO) NG 143 Existing DUKE_DUKE_GT2 DUKE (NOW HIDALGO) NG 143 Existing DUKE_DUKE_STI DUKE (NOW HIDALGO) WH 172 Existing DG_SCHUM_2UNITS DUNLOP (SCHUMANSVILLE) WAT 4 Nonmod EAGLE_HY_EAGLE_HY1 EAGLE PASS WAT 10 Nonmod FALCON_FALCONG1 FALCON PLANT WAT 12 Existing FALCON_FALCONG2 FALCON PLANT WAT 12 Existing FALCON_FALCONG3 FALCON PLANT WAT 12 Existing DG_HBR_2UNITS FARMERS BRANCH LANDFILL LFG 6 Nonmod FPPYDI_FPP_G1 FAYETTE PLANT 1 & 2 SUB 604 Existing FPPYD1_FPP_G2 FAYETTE PLANT 1 & 2 SUB 599 Existing FPPYD2_FPP_G3 FAYETTE PLANT 3 SUB 441 Existing FERGUS_FERGUSG1 FERGUSON NG 354 Existing FRNYPP_GT31 FORNEY NG 160 Existing FRNYPP_GT12 FORNEY NG 160 Existing FRNYPP_GT13 FORNEY NG 160 Existing FRNYPP_GT21 FORNEY NG 160 Existing FRNYPP_GT22 FORNEY NG 160 Existing FRNYPP_GT23 FORNEY NG 160 Existing FRNYPP_ST10 FORNEY NG 401 Existing FRNYPP_ST20 FORNEY NG 401 Existing FREC_GT3 Freestone Energy Center NG 152 Existing FREC_GT2 Freestone Energy Center NG 152 Existing FREC_GT4 Freestone Energy Center NG 152 Existing FREC_GT5 Freestone Energy Center NG 152 Existing FREC_ST3 Freestone Energy Center WH 176 Existing FREC_ST6 Freestone Energy Center WH 174 Existing FRONTERA_FRONTEG1 FRONTERA NG 170 Existing FRONTERA_FRONTEG2 FRONTERA NG 170 Existing FRONTERA_FRONTEG3 FRONTERA WH 184 Existing DG_RDLML_1UNIT FW REGIONAL LEG GENERATION FACILITY UNK 2 Nonmod DG_LKWDT_2UNITS GBRA WAT 5 Nonmod STEAM_ENGINE_i GEUS NG 8 Existing STEAM_ENGINE_2 GEUS NG 8 Existing STEAM_ENGINE_3 GEUS NG 8 Existing STEAM-STEAM 2 GEUS NG 26 Existing STEAM_STEAM_3 GEUS NG 41 Existing STEAM1A_STEAM_1 GEUS NG 20 Existing GIBCRK_GIB_CRG1 GIBBONS CREEK SUB 470 Existing GRSES_UNIT1 GRAHAM SES NG 225 Existing GRSES_UNIT2 GRAHAM SES NG 390 Existing GBY_GBY_5 GREENS BAYOU NG 406 Existing GBY_GBYGT73 GREENS BAYOU NG 46 Existing GBY_GBYGT74 GREENS BAYOU NG 46 Existing GBY_GBYGT81 GREENS BAYOU NG 46 Existing 6BY_GBYGT83 GREENS BAYOU NG 56 Existing GBY_GBYGT84 GREENS BAYOU NG 58 Existing GUADG GAS3 GUADALUPE GEN NG 151 Existing GUADG_GA52 GUADALUPEGEN NG 151 Existing GUADG_GAS3 GUADALUPE GEN NG 149 Existing GUADG_GAS4 GUADALUPE GEN NG 152 Existing GUADG_STMS GUADALUPE GEN NG 170 Existing GUADG_STM6 GUADALUPE GEN NG 169 Existing HLSES_UNIT3 HANDLEY SES NG 395 Existing HLSES_UNIT4 HANDLEY SES NG 435 Existing HLSES_UNITS HANDLEY SES NG 435 Existing HAYSEN_HAYSENGI HAYSENERGY NG 216 Existing HAYSEN_HAYSENG2 HAYS ENERGY NG 216 Existing HAYSEN_HAYSENG3 HAYS ENERGY NG 225 Existing HAYSEN_HAYSENG4 HAYS ENERGY NG 225 Existing INKSDA_INKS_G1 INKS DAM WAT 14 Existing JACKCNTY_CT1 JACK COUNTY PLANT NG 166 Existing JACKCNTY_CT2 JACK COUNTY PLANT NG 165 Existing JCKCNTY2_Cf3 JACK COUNTY PLANT NG 166 Existing JCKCNTY2_CT4 JACK COUNTY PLANT NG 165 Existing JACKCNTY_STG JACK COUNTY PLANT WH 295 Existing JCKCNTY2_ST2 JACK COUNTY PLANT WH 295 Existing DG_KMASB_1UNIT KMAYBTO OG 0.1 Nonmod LH2SES_UNIT2 LAKE HUBBARD 2 SES NG 515 Existing LHSES_UNIT1 LAKE HUBBARD SES NG 392 Existing LPCCS_Cill LAMAR POWER PARTNERS NG 154 Existing

163 Primary En^gy Sunmter CapaMy Unit Code Plant Name sowre Staws mm 7 1 LPCCG_Ci 12 LAMAR POWER PARTNERS NG 154 Existing LPCCS_CT21 LAMAR POWER PARTNERS NG 154 Existing LPCCS_CT22 LAMAR POWER PARTNERS NG 154 Existing LPCCS_UNIT1 LAMAR POWER PARTNERS NG 193 Existing LPCCS_UNIT2 LAMAR POWER PARTNERS NG 193 Existing LARDVFTN_G4 LAREDO ENERGY CENTER NG 94 Existing LARDVFTN_G5 LAREDO ENERGY CENTER NG 94 Existing LEON_CRK_LCPCTI LEON CREEK NG 46 Existing LEON_CRK_LCPCT2 LEON CREEK NG 46 Existing LEON_CRK_LCPCl3 LEON CREEK NG 46 Existing LEON_CRK_LCPCT4 LEON CREEK NG 46 Existing DG_LWSVL_1UNIT LEWISVILLE WAT 2 Nonmod LEG_LEG_G1 LIMESTONE PLANT LIG 831 Existing LEG_LEG_G2 LIMESTONE PLANT LIG 858 Existing LOSTPI_LOSTPGT1 LOST PINES NG 170 Existing LOSTPI_LOSTPGT2 LOST PINES NG 170 Existing LOSTPI_LOSTPST1 LOST PINES NG 188 Existing LFBIO_UNIT1 LUFKIN BIOMASS WDS 45 Existing MARBFA_MARBFAG1 MARBLE FALLS WAT 21 Existing MARBFA_MARBFAG2 MARBLE FALLS WAT 20 Existing MARSFO_MARSFOG1 MARSHALL FORD WAT 36 Existing MARSFO_MARSFOG2 MARSHALL FORD WAT 36 Existing MARSFO_MARSFOG3 MARSHALL FORD WAT 29 Existing MLSES_UNIT1 MARTIN LAKE SES LIG 800 Existing MLSES_UNIT2 MARTIN LAKE SES LIG 805 Existing MLSES_UNIT3 MARTIN LAKE SES LIG 805 Existing DG_MKNSW_2UNITS MCKINNEY LANDFILL LFG 3 Nonmod DG_MCQUE_SUNITS MCQUEENEY(ABBOTF) WAT 8 Nonmod DG_FREIH_2UNITS MESQUITE CREEK LANDFILL LFG 3 Nonmod MDANP_CT3 MIDLOTHIAN ANP NG 216 Existing MDANP_CT2 MIDLOTHIAN ANP NG 216 Existing MDANP_CT3 MIDLOTHIAN ANP NG 216 Existing MDANP_CT4 MIDLOTHIAN ANP NG 216 Existing MDANP_QS MIDLOTHIAN ANP NG 225 Existing MDANP_CT6 MIDLOTHIAN ANP NG 225 Existing MIL_MILLERG1 MILLER NG 75 Existing MIL_MILLERG2 MILLER NG 120 Existing MIL_MILLERG3 MILLER NG 208 Existing MIL_MILLERG4 MILLER NG 104 Existing MIl_MILLERGS MILLER NG 104 Existing MNSES UNIT3 MONTICELLO SES SUB 795 Existing MNSES_UNIT1 MONTICELLO SES SUB 535 Existing MNSES_UNIT2 MONTICELLO SES SUB 535 Existing MGSES_CT1 MORGAN CREEK SES NG 68 Existing MGSES_CT2 MORGAN CREEK SES NG 68 Existing MGSES_CT3 MORGAN CREEK SES NG 68 Existing MGSES_CF4 MORGAN CREEK SES NG 68 Existing MGSES_Q5 MORGAN CREEK SES NG 68 Existing MGSES_Ci6 MORGAN CREEK SES NG 67 Existing MCSES_UNIT6 MOUNTAIN CREEK SES NG 120 Existing MCSES_UNIT7 MOUNTAIN CREEK SES NG 115 Existing MCSES_UNITB MOUNTAIN CREEK SES NG 565 Existing NEDIN_NEDIN_G1 N EDINBURG NG 209 Existing NEDIN_NEDIN_G2 N EDINBURG NG 209 Existing NEDIN_NEDIN_G3 N EDINBURG WH 253 Existing NACPW_UNIT1 NACOGDOCHES POWER WDS 105 Existing NWF_NBS NoTrees Battery Storage OTH 36 Existing NUECES_B_NUECESG7 NUECES BAY NG 319 Existing NUECES_B_NUECESGB NUECES BAY NG 157 Existing NUECES_B_NUECESG9 NUECES BAY NG 157 Existing OGSES_UNITIA OAK GROVE SES LIG 840 Existing OGSES_UNIT2 OAK GROVE SES LIG 825 Existing OECCS_Cttl ODESSA ECTOR CCS NG 151 Existing OECCS_Ci12 ODESSA ECTOR CCS NG 140 Existing OECCS CT21 ODESSA ECTOR CCS NG 145 Existing OECCS_CT22 ODESSA ECTOR CCS NG 142 Existing OECCS_UNIT1 ODESSA ECTOR CCS NG 210 Existing OECCS_UNIT2 ODESSA ECiOR CCS NG 210 Existing OKLAOKLA_G1 OKLAUNION BIT 650 Existing OLINGR_OLING_1 OLINGER NG 78 Existing OLINGR_OLtNG_2 OLINGER NG 107 Existing OLINGR_OLING 3 OLINGER NG 146 Existing OLINGR_OLING 4 OLINGER NG 75 Existing PSG_PSG_GT2 PASGEN NG 164 Existing PSG_PSG_GT3 PASGEN NG 164 Existing PSG_PSG_ST2 PASGEN WH 167 Existing PEARSALL_PEARS_1 PEARSALL NG 25 Existing PEARSALL_PEARS_2 PEARSALL NG 25 Existing PEARSALL_PEARS_3 PEARSALL NG 25 Existing PEARSAL2 AGR A PEARSALL POWER PLANT 2 NG 51 Existing

164 ....^ Primary^EnengY Summe^pacity ...... unit Code Plant Name Sta[us I PEARSAL2_AGR_B PEARSALL POWER PLANT 2 NU Di txistmg PEARSAL2_AGR_C PEARSALL POWER PLANT 2 NG 51 Existing PEARSAL2_AGR_D PEARSALL POWER PLANT 2 NG 51 Existing PB2SES_CT1 PERMIAN BASIN SES RELIANT NG 68 Existing PB2SES_CT2 PERMIAN BASIN SES RELIANT NG 65 Existing PB2SE5_CT3 PERMIAN BASIN SES RELIANT NG 68 Existing PB2SE5_CF4 PERMIAN BASIN SES RELIANT NG 69 Existing PB25ES_CF5 PERMIAN BASIN SES RELIANT NG 70 Existing QALSW_GT1 QUAILSWITCH NG 74 Existing QALSW_GT2 QUAIL SWITCH NG 74 Existing QALSW_GT3 QUAILSWITCH NG 72 Existing QALSW_GT4 QUAILSWITCH NG 72 Existing QALSW_STG1 QUAILSWITCH NG 98 Existing QALSW_STG2 QUAILSWITCH NG 98 Existing RIONOG_CT1 RIO NOGALES POWER PROJECT NG 154 Existing RIONOG_CF2 RIO NOGALES POWER PROJECT NG 154 Existing RIONOG_CT3 RIO NOGALES POWER PROJECT NG 154 Existing RIONOG_STl RIO NOGALES POWER PROJECT WH 323 Existing RAYBURN_RAYBURG1 SAM RAYBURN SWITCHYD NG 11 Existing RAYBURN_RAYBURG2 SAM RAYBURN SWITCHYD NG 11 Existing RAYBURN_RAYBURG7 SAM RAYBURN SWITCHYD NG 50 Existing RAYBURN_RAYBURGB SAM RAYBURN SWITCHYD NG 50 Existing RAYBURN_RAYBURG9 SAM RAYBURN SWITCHYD NG 50 Existing RAYBURN_RAYBURG10 SAM RAYBURN SWITCHYD WH 40 Existing SIS_SJS_G1 SAN JACINTO STEAM NG 81 Existing SJS_SIS_G2 SAN JACINTO STEAM NG 81 Existing SANMIGL_SANMIGG1 SAN MIGUELGEN LIG 391 Existing SANDHSYD_SH_5A SANDHILL POWER STATION NG 150 Existing SANDHSYD_SH_SC SANDHILL POWER STATION NG 145 Existing SANDHSYD_SH1 SANDHILL POWER STATION NG 45 Existing SANDHSYD_SH2 SAN DH ILL POWER STATION NG 45 Existing SANDHSYD_SH3 SANDHILL POWER STATION NG 45 Existing SANDHSYD_SH4 SANDHILL POWER STATION NG 45 Existing SANDHSYD_SH6 SANDHILL POWER STATION NG 45 Existing SANDHSYD_SH7 SANDHILL POWER STATION NG 45 Existing SD5SE5_UNITS SAN DOW 5 SES LIG 570 Existing SILASRAY_SILAS_10 SILAS RAY NG 48 Existing SILASRAY_SILAS_9 SILAS RAY NG 38 Existing SILASRAY_SILAS_6 SILAS RAY WH 20 Existing GIDEON_GIDEONGI SIM GIDEON NG 130 Existing GIDEON_GIDEONG2 SIM GIDEON NG 135 Existing GIDEON_GIDEONG3 SIM GIDEON NG 332 Existing DG_FERIS_4UNIT5 SKYLINE LANDFILL GAS UNK 6 Nonmod DG_SOME3_1UNIT SOMERSET NORTH SUN 6 Nonmod DG_SOME2_1UNIT SOMERSET SOUTH SUN 5 Nonmod STP_STP_G1 SOUTH TEXAS PROJECT NUC 1375 Existing STP_STP_G2 SOUTH TEXAS PROJECT NUC 1375 Existing SPNCER_SPNCE_4 SPENCER NG 61 Existing SPNCER_SPNCE_5 SPENCER NG 61 Existing SR8_SRB_G1 SR BERTRON NG 118 Existing SRB_SRB_G2 SR BERTRON NG 174 Existing SRB_SRB_G3 SR BERTRON NG 211 Existing SRB_SRB_G4 SR BERTRON NG 211 Existing SRB_SRBGT_2 SR BERTRON NG 13 Existing SCSES_UNIT1A STRYKER CREEK SES NG 167 Existing SCSES_UNIT2 STRYKER CREEK SES NG 502 Existing DG_VALL1_1UNIT SUNEDISON RABEL ROAD SUN 10 Nonmod DG_VALL2_1UNIT SUNEDISON VALLEY ROAD SUN 10 Nonmod TEN_CT1 TENASKA (BRAZOS) NG 163 Existing TEN_STG TENASKA (BRAZOS) WH 106 Existing TNSKA_GT1 TENASKA (TXU) NG 76 Existing TNSKA_GT2 TENASKA(TXU) NG 76 Existing TNSKA_STG TENASKA (TXU) WH 87 Existing DG_WALZE_4UNITS TESSMAN ROAD MTE 10 Nonmod TXCTY_C7A TEXAS CITY GEN NG 97 Existing TXCTY_CFB TEXAS CITY GEN NG 97 Existing T%CTY_CTC TEXAS CITY GEN NG 97 Existing TXCFY_ST TEXAS CITY GEN WH 132 Existing TGF_TGFGT_1 TEXAS GULF SULPHUR NG 79 Existing THW_THWGT_1 TH WHARTON NG 13 Existing THW_THWGT31 TH WHARTON NG 57 Existing THW_THWGT32 TH WHARTON NG 57 Existing THW_THWGT33 TH WHARTON NG 57 Existing THW_THWGT34 TH WHARTON NG 57 Existing THW_THWGT41 TH WHARTON NG 57 Existing THW_THWGT42 TH WHARTON NG 57 Existing THW_THWGT43 TH WHARTON NG 57 Existing THW_THWGT44 TH WHARTON NG 57 Existing THW_THWGT51 TH WHARTON NG 57 Existing THW THWGT52 TH WHARTON NG 57 Existing

165 . Primzo rcnergy Summe^pac+ty Unit Code ^^ ^ .. PlantName...... Slaws.....

THW_THWGT53 TH WHARTON NG 57 Existing THW_THWGT54 TH WHARTON NG 57 Existing THW_THWGT55 TH WHARTON NG 57 Existing THW_THWGT56 TH WHARTON NG 57 Existing THW_THWST_3 TH WHARTON NG 104 Existing THW_THWST_4 TH WHARTON NG 104 Existing TNP_ONE_TNP_O_1 TNP ONE PLANT LIG 156 Existing TNP_ONE_TNP_O_2 TNP ONE PLANT LIG 156 Existing ETCCS_CT1 TRACTEBEL NG 196 Existing ETCCS_UNIT1 TRAClEBEL NG 116 Existing TRSES_UNIT6 TRINIDAD SES NG 226 Existing DG_KLBRG_1UNIT TRINITY OAKS LFG LFG 3 Nonmod BRAUNIG_AVR3_CT1 VH BRAUNIG NG 155 Existing BRAUNIG_AVR3_Ci2 VH BRAUNIG NG 155 Existing BRAUNIG_VHB1 VH BRAUNIG NG 220 Existing BRAUNIG_VHB2 VH BRAUNIG NG 230 Existing BRAUNIG_VHB3 VH BRAUNIG NG 412 Existing BRAUNIG_VHB6CT5 VH BRAUNIG NG 48 Existing BRAUNIG_VHB6CT6 VH BRAUNIG NG 48 Existing BRAUNIG_VHB6C77 VH BRAUNIG NG 48 Existing BRAUNIG_VHB6CT8 VH BRAUNIG NG 48 Existing BRAUNIG_AVR3_ST VH BRAUNIG WH 180 Existing VICTORIA_VICTORG6 VICTORIA NG 160 Existing VIClORIA_VICTORGS VICTORIA WH 125 Existing WAP_WAP_G5 WA PARISH BIT 659 Existing WAP_WAP_G6 WA PARISH BIT 658 Existing WAP_WAP_G7 WA PARISH BIT 577 Existing WAP_WAP_G8 WA PARISH BIT 610 Existing WAP_WAP_G1 WA PARISH NG 169 Existing WAP_WAP_G2 WA PARISH NG 169 Existing WAP_WAP_G3 WA PARISH NG 258 Existing WAP_WAP_G4 WA PARISH NG 552 Existing WAP_WAPGT_1 WA PARISH NG 13 Existing WEBBER_5_WSP1 WEBBERVILLE SUN 29 Existing DG_WSTHL_3UNIT5 WESTSIDE LFG 5 Nonmod WND_WHITNEY2 WHITNEY DAM WAT 15 Existing WFCOGEN_UNIT1 WICHITA FALLS COGEN SWITCH NG 20 Existing WFCOGEN_UNIT2 WICHITA FALLS COGEN SWITCH NG 20 Existing WFCOGEN_UNIT3 WICHITA FALLS COGEN SWITCH NG 20 Existing WFCOGEN_UNIT4 WICHITA FALLS CO6EN SWITCH WH 17 Existing WIPOPA_WPP_G1 WINCHESTER POWER PARK NG 44 Existing WIPOPA_WPP_G2 WINCHESTER POWER PARK NG 44 Existing WIPOPA_WPP_G3 WINCHESTER POWER PARK NG 44 Existing WIPOPA_WPP_G4 WINCHESTER POWER PARK NG 44 Existing WIRTZ_WIRTZ_G1 WIRTZ WAT 29 Existing WIRTZ_WIRTZ_G2 WIRTZ WAT 29 Existing WCPP_Ctt WISE COUNTY POWER PLANT NG 212 Existing WCPP_CT2 WISE COUNTY POWER PLANT NG 212 Existing WCPP_ST1 WISE COUNTY POWER PLANT NG 241 Existing WHCCS_CT1 WOLF HOLLOW GEN NG 213 Existing WHCCS_CT2 WOLF HOLLOW GEN NG 213 Existing WHCCS_STG WOLF HOLLOW GEN WH 280 Existing Total Existing Resources 65002

SCES-UNITI SANDY CREEK SUB 925 New Total Planned non-Wind Resources 925

PUN AGGREGATE PUN OUTPUT TO GRID OTH 4390 PUN Adjustment based on PUN info request, 4/5/13 OTH -59 PUN Total Private Use Networks 4331

FTR_FTR_G1 FRONTIER NG 165 Switchable FTR_FTR_G2 FRONTIER NG 165 Switchable FTR_FTR_G3 FRONTIER NG 165 Switchable KMCHI_1Cf101 KIAMICHI ENERGY FACILITY NG 153 Switchable KMCHI_1CT201 KIAMICHI ENERGY FACILITY NG 155 Switchable KMCHI_2CT101 KIAMICHI ENERGY FACILITY NG 153 Switchable KMCHI_2CT201 KIAMICHI ENERGY FACILITY NG 155 Switchable TGCCS_Ctt TENASKA GATEWAY NG 156 Switchable TGCCS_Ci2 TENASKA GATEWAY NG 135 Switchable TGCCS_Ci3 TENASKAGATEWAY NG 153 Switchable FTR_FTR_G4 FRONTIER WH 390 Switchable KMCHI_1ST KIAMICHI ENERGY FACILITY WH 315 Switchable KMCHI_2ST KIAMICHI ENERGY FACIUTY WH 315 Switchable TGCCS_UNIT4 TENASKA GATEWAY WH 402 Switchable Total Switchable Resources 2977

ANACACHO_ANA Anacacho Windfarm WND 101 Wind BRAZ_WND_WND1 Green Mountain Energy 1 WND 99 Wind

166 Primary Ena^gp Sumner Capacity Unit Code Plant Name Status

BRAZ_WND_WND2 Green Mountain Energy 2 WND 61 Wind BRTSW_BCW1 Barton Chapel Wind WND 120 Wind BCATWIND_WIND_1 Bobcat Bluff WND 163 New BUFF_GAP_UNIT1 Buffalo Gap Wind Farm 1 WND 121 Wind BUFF_GAP UNIT2_1 Buffalo Gap Wind Farm 2 WND 116 Wind BUFF_GAP_UNIT2_2 Buffalo Gap Wind Farm 2 WND 117 Wind BUFF_GAP_UNIT3 Buffalo Gap Wind Farm 3 WND 170 Wind BULLCRK_WND1 Bull Creek Wind Plant WND 88 Wind BULLCRK_WND2 Bull Creek Wind Plant WND 90 Wind CAPRIDG4_CR4 Capricorn Ridge Wind 4 WND 113 Wind CAPRIDGE_CR1 Capricorn Ridge Wind I WND 215 Wind CAPRIDGE_CR2 Capricorn Ridge Wind 3 WND 150 Wind CAPRIDGE_CR3 Capricorn Ridge Wind 2 WND 186 Wind CEDROHIL_CHW1 Cedro Hill Wind WND 150 Wind CHAMPION_UNIT1 Champion Wind Farm WND 127 Wind CSEC_CSECG1 Camp Springs 1 WND 134 Wind CSEC_CSECG2 Camp Springs 2 WND 124 Wind DG_ROSC2_1UNIT TSTC West Texas Wind WND 2 Wind DG_TURL_UNIT1 WOLFE FLATS WND 1 Wind ELB_ELBCREEK Elbow Creek Wind Project WND 119 Wind ENAS_ENA1 Snyder Wind Farm WND 63 Wind EXGNWTL_WIND_1 Whitetail Wind Energy Project WND 91 Wind FLTCK_SSI Silver Star WND 60 Wind GOAT_GOATWIN2 Goat Wind 2 WND 70 Wind GOAT_GOATWIND Goat Wind WND 80 Wind HHGT_CALLAHAN Horse Hollow Wind Callahan WNO 114 Wind HHGT_HHOLLOW1 Horse Hollow Wind 1 WND 213 Wind HHGT_HHOLLOW2 Horse Hollow Wind 2 WND 184 Wind HHGT_HHOLLOW3 Horse Hollow Wind 3 WND 224 Wind HHGT_HHOLLOW4 Horse Hollow Wind 4 WND 115 Wind HWF_HWFG1 Hackberry Wind Farm WND 162 Wind INDL_INADALEI Inadale Wind WND 197 Wind INDNENR_INDNENR Desert Sky Wind Farm 1 WND 84 Wind INDNENR_INONENR_2 Desert Sky Wind Farm 2 WND 77 Wind INDNNWP_INDNNWP Indian Mesa Wind Farm WND 83 Wind KEO_KEO_SM1 Sherbino I WND 150 Wind KEO_SHRBINO2 Sherbino 2 WND 150 Wind KING_NE_KINGNE King Mountain NE WND 79 Wind KING_NW KINGNW King Mountain NW WND 79 Wind KING_SE_KINGSE King Mountain SE WND 40 Wind KING_SW KINGSW King Mountain SW WND 79 Wind KUNITZ_WIND_LGE Kunitz Wind WND 40 Wind KUNITZ_WIND_NWP Delaware Mountain Wind Farm WND 30 Wind LGD_LANGFORD Langford Wind Power WND 155 Wind LNCRK_G83 Mesquite Wind WND 200 Wind LNCRK2_G871 Post Oak Wind 1 WND 100 Wind LNCRK2_G872 Post Oak Wind 2 WIND 100 Wind LONEWOLF_G1 Loraine Windpark I WND 50 Wind LONEWOLF_G2 Loraine Windpark II WND 51 Wind LONEWOLF_G3 Loraine Windpark III WND 26 Wind LONEWOLF_G4 Loraine Windpark IV WND 24 Wind MCDLD_FCW1 Forest Creek Wind Farm WND 124 Wind MCDLD_SBW1 Sand Bluff Wind Farm WND 90 Wind MOZART_WIND_1 WKN Mozart WND 30 Wind MWEC_G1 McAdoo Wind Farm WND 150 Wind NWF_NWF1 Notrees-1 WND 153 Wind OWF_OWF Ocotillo Wind Farm WND 60 Wind PC_NORTH_PANTHERI Panther Creek 1 WND 143 Wind PC_SOUTH_PANTHER2 Panther Creek 2 WND 116 Wind PC_SOUTH_PANTHER3 Panther Creek 3 WND 200 Wind PYR_PYRON1 Pyron Wind Farm WND 249 Wind RDCANYON_RDCNY1 Red Canyon WND 84 Wind SENATEWD_UNIT1 Senate Wind Project WND 150 Wind SGMTN_SIGNALMT Texas Big Spring WND 34 Wind STWF_T1 South Trent Wind Farm WND 101 Wind SW_MESA_SW_MESA West Texas Wind Energy WND 74 Wind SWEC_G1 Stanton Wind Energy WND 124 Wind SWEETWN2_WND2 Sweetwater Wind 3 WND 98 Wind SWEETWN2_WND24 Sweetwater Wind 2 WND 16 Wind SWEETWN3_WND3A Sweetwater Wind 4 WND 30 Wind SWEETWN3_WND3B Sweetwater Wind 4 WND 101 Wind SWEETWN4_WND4A Sweetwater Wind 7 WND 118 Wind SWEETWN4_WND4B Sweetwater Wind 6 WND 104 Wind SWEETWN4_WNDS Sweetwater Wind 5 WND 79 Wind SWEETWND_WND1 Sweetwater Wind 1 WND 37 Wind TKWSWI_ROSCOE Roscoe Wind Farm WND 209 Wind TRENT_TRENT Trent Wind Farm WND 151 Wind TRINITY_TH1_BUS1 Trinity Hills WND 118 Wind TRINITY TH1_BU52 Trinity Hills WND 108 Wind TTWEC_G1 Turkey Track Wind Energy Center WND 170 Wind

167 Unit Code Pr'n^7 EnN'9Y Sunmier Capaaty Plant Na- S1aws ^ Source (MM vv K_wcw• Wmnwmd Energy WND 57 Wind WHTTAIL_WR3 Wolfe Ridge WND 113 Wind WOODWRD3_WOODWRD1 Pecos Wind (Woodward 1) WND 83 Wind WOODWRD2_WOODWRD2 Pecos Wind (Woodward 2) WND 77 Wind COTTON_PAP2 Papalote Creek Wind WND 200 Wind* DG_NUECE_6UNITS Harbor Wind WND 9 Wind* PAP1_PAP1 Papalote Creek Wind Farm WND 180 Wind* PENA_UNIT1 Penascal Wind WND 161 Wind' PENA_UNIT2 Penascal Wind WND 142 Wind* PENA3_UNIT3 Penascal Wind WND 101 Wind* REDFISH_MV1A Magic Valley Wind WND 103 Wind* REDFISH_MV1B Magic Valley Wind WND 103 Wind* TGW_T1 Gulf Wind I WND 142 Wind* TGW_T2 Gulf Wind II WND 142 Wind* Total Wind Resources 10570 BLSUMMIT_BLSMT1_5 Blue Summit Windfarm 1 WND 9 New BLSUMMIT_BLSMT1_6 Blue Summit Windfarm 2 WND 126 New LV1_LV1B Los Vientosl WND 202 New* LV1_LV1A Los Vientos 2 WND 200 New* Total Planned Wind Resources S37

* Coastal Wind

168 Seasonal Assessment of Resource Adequacy for the ERCOT Region

Background

The Seasonal Assessment of Resource Adequacy (SARA) report is a deterministic approach to considering the impact of potential variables that may affect the sufficiency of installed resources to meet the peak electrical demand on the ERCOT System during a particular season.

The standard approach to assessing resource adequacy for one or more years into the future is to account for projected load and resources on a normalized basis and to require sufficient reserves (resources in excess of peak demand, on this normalized basis) to cover the uncertainty in peak demand and resource availability to meet a one-in-ten-years loss-of-load event criteria on a probabilistic basis.

For seasonal assessments that look ahead less than a year, specific information may be available (such as seasonal climate forecasts or anticipated common-mode events such as drought) which can be used to consider the range of resource adequacy in a more deterministic manner.

The SARA report is intended to illustrate the range of resource adequacy outcomes that might occur. Several sensitivity analyses are developed by varying the values of certain parameters that affect resource adequacy. The variation in these parameters are based on historic values, adjusted by any known or expected change.

169 Seasonal Assessment of Resource Adequacy for the ERCOT Region Winter 2013 - 2014

Released November 1, 2013

SUMMARY

The ERCOT region is expected to have sufficient installed generating capacity to serve forecasted peak demands with a historically typical amount of generation outages. It is unlikely that ERCOT will need to declare an Energy Emergency Alert (EEA) during the winter of 2013- 14. The results of this study indicate that an extreme higher-than-normal number of forced generation outages occurring during a period of unusually high demand would result in sufficient resources available to serve those demands.

The ongoing drought conditions throughout the State are not expected to affect generation output during the Winter 2013-14 season. ERCOT is closely monitoring the availability of cooling water at generating resources.

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172 Prim.try Ener9Y Winlw Capaoty, ^^...... Uit Cnee...... Plant Name Sour e

AZ_AZ_G1 AIRPRO NG 45 Ezisting AZ_AZ_G2 AIRPRO NG 45 Existing AZ_AZ_G3 AIRPRO NG 45 Ezisting to Abbreviations AZ_AZ_G4 AIRPRO NG 45 Ezisting Biomass AMISFAD_AMISTAG1 AM ISTAD WAT 38 Existing Bituminous Coal AMISiAD_AMISfAG2 AMISTAD WAT 38 Existing Land-fill Gas HB_DG1 ATASCOCITA LFG 10 Nonmod Lignite Coal ATKINS_ATKINSG7 ATKINS NG 20 Existing Methanol DG_SPRIN_4UNIT5 AUS17N LANDFILL GAS UNK 6Nonmod Methane AUSfPL AUSiING1 AUSTIN PLANT WAT 8 Existing Natural Gas AUSTPL_AUSTING2 AUSi7N PLANT WAT 9 Existing Nuclear B_DAVIS_B_DAVIGI BARNEYDAVIS NG 335 Existing Other Gas B_DAVIS_B_DAVIG2 BARNEyDAVIS NG 320 Existing Other B_DAVIS_B_DAVIG3 BARNES DAVIS NG 165 Existing Pulverized Coal B_DAVIS_B_DAVIG4 BARNEY DAVIS NG 165 Existing Sub-bituminous Coal BAST EN_GTG1100 BASTROP ENERGY CENTER NG 167 Existing Sun (Solar Resource) BASTEN_GTG2100 BASTROP ENERGY CENTER NG 167 Existing Unknown BASfEN_Sf0100 BASTROP ENERGY CENTER WH 234 Existing Water (Hydro Resource) TRN_DG1 BAYTOWN MTH 4 Nonmod Wood Biomass BBSES UNIT1 BIG BROWN SEA LIG 606 Existing Waste Heat BBSES_UNIT2 BIG BROWN SES LIG 602 Existing Wind CARBN_BSP_1 BIGSPRING WH 18 Existing DG_BIOE_2UNIT5 RIO ENERGY PARTNERS NG 6 Nonmod DG_BROOK_1UNIT BLUE WING SOLAR 1 SUN 8 Nonmod Note -Capacity Information is current as of 10/30/2013 DG_ELMEN_1UNIT BLUE WING SOLAR 2 SUN 7 Nonmod LB_DG1 BLUEBONNET LFG 4 Nonmod BOSQUESW_BSO$US BOSQUESWITCH NG 160Existing BOSQUESW_BSQSU_2 BOSQUESWITCH NG 160 Existing BOSQUESW_BSQSU_3 BOSQUESWITCH NG 156 Existing BOSQUESW_BSQSU4 BOSQUE SWITCH WH 79 Ezisting BOSQUESW_BSQSU_5 BOSQUE SWITCH WH 209 Ezisting BVE UNIT1 BRA2OS VALLEY ENERGY LP NG 168 Ezisting BVE UNIT2 BRA2OS VALLEY ENERGY LP NG 168 Existing BVE_UNIT3 BRAZOS VALLEY ENERGY LP NG 270 Existing 13DGRO001 Bryan Solar Solar 10 Ezisting BUCHAN_BUCHANG1 BUCHANAN W 16 Existing BUCHAN_BUCHANG2 BUCHANAN WAT 16 Existing BUCHAN_BUCHANG3 BUCHANAN WAT 17 Existing FLCNS_UNIT1 CAL ENERGY NG 78 Existing FLCNS_UNIT2 CAL ENERGY NG 78 Existing FLCNS_UNIT3 CAL ENERGY NG 74 Existing CALAVERS_OWS1 CALAVERAS NG 420 Existing CALAVERS_OWS2 CALAVERAS NG 420 Existing CALAVERS_JK51 CALAVERAS SUB 562 Existing CALAVERS_JK52 CALAVERAS 5UB 775 Existing CALAVERS_1TD1 CALAVERAS SUB 430 Existing CALAVERSJTD2 CALAVERAS SUB 420 Existing CANYHYCANYHYGI CANYON WAT 6 Nonmod CBY4_CT41 CEDAR BAYOU 4 NG 173 Existing CBY4_Cf42 CEDAR BAYOU 4 NG 173 Existing CBY4_ST04 CEDAR BAYOU 4 NG 186 Existing CBV_CBY_G1 CEDAR BAYOU PLANT NG 745 Existing CBY_CBY_G2 CEDAR BAYOU PLANT NG 749 Existing CVC_CVC_G1 CHANNELVIEW COGEN NG 180 Existing CVC_CVC_G2 CHANNELVIEW COGEN NG 175 Existing CVCCVCG3 CHANNELVIEW COGEN NG 174 Existing CVCCVCG5 CHANNELVIEW COGEN NG 118 Existing AV_DG1 COASTAL PLAINS RDF LFG 7 Nonmod COLETO_COLETOG1 COLETO CREEK SUB 650 Existing CBEC_GT1 COLORADO BEND ENERGY CENTER NG as Existing CBECGTI COLORADO BEND ENERGY CENTER NG 84 Existing CBECGT3 COLORADO BEND ENERGY CENTER ING 88 Existing CBEC_GT4 COLORADO BEND ENERGY CENTER ING 83 Existing CBEC_STG1 COLORADO BEND ENERGY CENTER NG 105 Existing CBEC_STGZ COLORADO BEND ENERGY CENTER ING 108 Existing CPSES_UNIT1 COMANCHE PEAK SES NUC 1235 Existing CPSES_UNIT2 COMANCHEPEAK SES NUC 1225 Existing DG_MEDIN_1UNIT COVELGARDENS LGPOWER STATION UNK 10 Nonmod DANSBy_DANSBYG1 DANSBY NG 110 Existing DANSBV_DANSBYG2 DANSBY NG 48 Existing DANSBY_DANSBYG3 DANSBY NG 48 Existing DECKER_DPG1 DECKER POWER PLANT NG 320 Existing DECKER_DPG2 DECKER POWER PLANT NG 428 Existing DECKER_DPGT_3 DECKER POWER PLANT NG 54 Existing DECKER_DPGT_2 DECKERPOWER PLANT NG 54 Existing DECKER_DPGT_3 DECKER POWER PLANT NG 54 Existing DECKER_DPGT_4 DECKER POWER PLANT NG 54 Existing DC5ES_CT10 DECORDOVASESCONSTELLATION NG 80 Existing DCSES_CRO DECORDOVASESCONSTELLATION NG 79 Existing DCSES_Cf30 DECORDOVASESCONSTELLATION NG 78 Existing DCSES_CT40 DECORDOVASESCONSTELLATION ING 77 Existing DDPECGT1 DEER PARK ENERGY CENTER ING 190 Existing DDPEC_GT2 DEER PARK ENERGY CENTER NG 206 Existing DDPEC_GT3 DEER PARK ENERGY CENTER NG 190 Existing DDPEC_GT4 DEER PARK ENERGY CENTER NG 206 Existing DDPEC_Sf1 DEER PARK ENERGY CENTER WHI 290 Existing DNDAM_DENISOG1 DENISON DAM WAT 40 Existing DNDAM_DENISOG2 DENISON DAM WAT 40 Existing DG_BIO2_4UNITS DFW GAS RECOVERY LFG 6Nonmod DUKE_DUKE_GT1 DUKE (NOW HIDALGO) NG 150 Ecisting DUKE_DUKE_GT2 DUKE (NOW HIDALGO) NG 150 Ezisting DUKE_DUKE_Si1 DUKE (NOW HIDALGO) WH 176 Existing DG_SCHUM_2UNITS DUNLOP (SCHUMANSVILLE) WAT 4 Nonmod EAGLE_HV_EAGLE_HY1 EAGLE PASS WAT 10 Nonmod FALCON_FALCONG1 FALCON PLANT WAT 12 Existing FALCON_FALCONG2 FALCON PLANT WAT 12 Existing FALCON_FALCONG3 FALCON PLANT WAT 12 Existing DG HBR 2UNITS FARMERS BRANCH LANDFILL LEG 6 Nonmod

173 Pnmary Energy wrcn Cal,aary :S^ .•: um Cnee ...... %ax Namr ...... 5ourcc 1^9

FPPYDI FPP G1 FAYETTE PLANT 1& 2 5UB 603 Existing FPPYDl_FPP G2 FAYETTE PLANT 1& 2 SUB 605 Exist, ": FPPYD2_FPP G3 FAYETTE PLANT 3 SUB 449 Existing FRNYPP_GT11 FORNEY NG 178 Existing FRNYPP_GT12 FORNEY NG 178 Existing FRNYPP_GT13 FORNEY NG 178 Existing FRNYPP_GT21 FORNEY NG 178 Existing FRNYPP_GT22 FORNEY NG 17g Existing FRNYPP_GT23 FORNEY NG 17B Existing FRNYPP_St10 FORNEY NG 405 Existing FRNYPP_SI20 FORNEY NG 405 Existing FREC_G71 FreestonEEnefgyCenter NG 161 Existing FREC_GT2 Freestone Energy Center NG 161 Ezisting FREC_GT4 Freestone Energy Center NG 161 Existing FREC GTS Freestone Energy Center NG 161 Existing FREC Si3 Freestone Energy Center WH 180 Existing FREC_5T6 Freestone Energy Center WH 180 Existing FRONTERA_FRONTEGl FRONTERA NG 170 Existing FRONTERA_FRONTEG2 FRONTERA NG 170 Existing FRONTERA_FRONTEG3 FRONTERA WH 180 Existing DG_RDLML_1UNIT FW REGIONAL IFO GENERATION FACILITY UNK 2NOnmod DG_LKWDT_2UNITS GBRA WAT 5 Nonmod STEAM_ENGINE_3 GEUS NG 8 Existing STEAM_ENGINE_2 NG 8 Existing STEAM_ENGINE_3 GE US NG 8 Existing STEAM-STEAM-2 GEGEUS US NG 26 Existing S7EAM_STEAM_3 GEUS NG 41 Existing STEAMIA_S7EAM_1 GEUS NG 20 Existing GIBCRK_GIB_CRG1 GIBBONSCREEK SUB 470 Existing GRSES_UNIT1 GRAHAM SES NG 225 Existing GRSES_UNIT2 GRAHAM SES NG 390 Est", GBYGBY_5 GREENS BAYOU NG 406 Existing GBYGBYGT73 GREEN SBAYOU NG 54 Existing GBYGBYGT74 GREENS BAYOU NG 54 Existing GBYGBYGT81 GREENS BAYOU NG 54 Existing GBY_GBYGT83 GREENS BAYOU NG 64 Existing GBY_GBYGT84 GREENS BAYOU NG 58 Existing GUADG_GAS1 GUADALUPE GEN NG 167 Existing GUADG_GAS2 GUADALUPE GEN NG 167 Existing GUADG_GAS3 GUADALUPE GEN NG 167 E[isting GUADG_GAS4 GUADALUPE GEN NG 167 Existing GUADG_STM5 GUADALUPE GEN NG 203 Existing GUADG_SiM6 GUADALUPE GEN NG 203 Existing HLSES_UNIT3 HANDLEYSES NG 395 Existing HLSES UNIT4 HANDLEYSES NG 435 Existing HLSES_UNITS HANDLEYSES NG 435 Existing FIAYSEN_HAYSENG1 HAYSENERGY NG 237 Existing HAYSEN_HAYSENG2 HAYSENERGY NG 237 Existing HAYSEN_HAYSENG3 HAYS ENERGY NG 247 Existing HAYSEN_HAYSENG4 HAYSENERGY NG 247 Existing INKSDA INKS G1 l DAM WAT 14 Existing JACKCNTY_CT1 JACKCOUNTYA PLANT NG 165 Existing JACKCNTY_CT2 IACK COUNTY PLANT NG 165 Existing JCKCNTY2_CT3 JACK COUNTY PLANT ING 115 Existing JCKCNTY2_CT4 JACK COUNTY PLANT NG 165 Existing JACKCNTY STG JACKCOUNTYPLANT Wit 310 Existing JCKCNTY2 ST2 JACK COUNTY PLANT WH 330 Existing DG KMASB_SUNIT KMAYBTO OG 0.1 Nonmod LH2SE5_UNIT2 LAKEHUBBARD2SES NG 515 Existing LHSES_UNIT1 LAKEHUBBARDSES NG 392 Existing LPCCS_Ct11 LA AR POWER PARTNERS NG 177 Existing LPCCS_CT12 LAMAR POWER PARTNERS NG 177 Existing LPCCS_CR1 LAMAR POWER PARTNERS ING 177 Existing LPCCS_CT22 LA AR POWER PARTNERS ING 177 Existing LPCCS UNITl LA AR POWER PARTNERS NG 195 Ealsting LPCCS_UNIT2 LA AR POWER PARTNERS NG 195 Existing LARDVFTN_G4 LAREDOENERGYCENTER NG 99 Existing LARDVFTN_G5 LARE DO ENERGY CENTER NG 99 Existing LEON_CRK_LCPCf1 LEON CREEK NG 48 Existing LEON_CRK_LCPCR LEON CREEK NG 48 Existing LEON_CRK_LCPC73 LEON CREEK NG 48 Existing LEON_CRK_LCPCT4 LEON CREEK NG 48 Existing DG_LWSVL_1UNIT LEWISVILLE WAT 2 No mod LEG_LEG_Gt LIMESTONE PLANT LIG 831 Existing LEG_LEG_G2 LIMESTONE PLANT LIG 858 Existing LOSTPI_LOSTPGTI LOST PINES NG 183 Existing LOSTPI LOSTPGT2 LOST PINES NG 183 Existing LOSTPI_LOSTPST1 LOST PINES NG 192 Existing LFBIO_UNIT1 LUFKIN BIOMASS WDS 45 Existing MARBFA MARBFAGI MARBLE FALLS WAT 21 Existing MARBFA_MARBFAG2 MARBLE FALLS WAT 20 Existing MARSFO_MARSFOGI MARSHALL FORD WAT 36 Existing MARSFO_MARSFOG2 MARSHALL FORD WAT 36 Existing MARSFO_MARSFOG3 MARSHALL FORD WAT 29 Existing MLSES_UNIT1 MARTIN LAKE SES LIG 815 Existing MLSES_UNIT2 MARTINLAKE SES LIG 820 Existing DG_MKNSW_2UNIT5 MCKINNEYLANDFILL LFG 3 Nornnod DG_MCQUE_SUNITS MCQUEENEY (ABBOTT) WAT 8 Nonmod DG_FREIH_2UNITS MESQUITE CREEK LANDFILL LEG 3 Nonmod MDANP_CR MIDLOTHIAN ANP NG 237 Existing MDANP_CT2 MIDLOTHIAN ANP NG 237 Existing MDANP_CT3 MIDLOTHIAN ANP NG 237 Existing MDANP_CT4 MIDLOTHIAN ANP NG 237 Existing MDANP_Cf5 MIDLOTHIAN ANP NG 247 Existing MDANP_CT6 MIDLOTHIANANP NG 247 Existing MIL_MILLERGI MILLER NG 75 Existing MIL_MILLERG2 MILLER NG 120 Existing MIL MILLERG3 MILLER NG 208 Existing

174 P ^^^ ^- (W14 -7 MIL MILLERG4 F MILLER NG 115 Existing MIL_MILlERGS MILLER NG 115 Existing MNSES_UNIT3 MONTICELLOSES SUB 795 Existing MGSES_CTl MORGANCREEK SES NG 81 Existing MGSES_CT2 MORGANCREEK SES NG 81 Existing MGSES_3 C MORGANCREEK SES NG 81 Ezisting MGSES_CT4 MORGANCREEK SES NG 81 Existing MGSES_C5 MORGANCREEK SES NG 81 Ezisting MGSES_CT6 MORGAN CREEK SES NG 81 Existing MCSES UNIT6 MOUNTAIN CREEK SES NG 122 Existing MCSES_UNIT7 MOUNTAIN CREEK SES NG 118 Existing MCSES_UNITB MOUNTAIN CREEK SES NG 568 Existing NEDIN_NEDIN_G1 N EDINBURG NG 219 Existing NEDIN_NEDIN_G2 N EDINBURG NG 219 Exlsting NEDIN_NEDIN_G3 N EDINBURG WH 258 Existing NACPW_UNIT1 NACOGDOCHES POWER WDS 105 Existing NWF_NBS NoTrees Battery Storage OTH 36 Existing NUECES_B_NUECESG7 NUECES BAY NG 320 Existing NUECES_B_NUECESGB NUECES BAY NG 165 Existing NUECES_8_NUECESG9 NUECES BAY NG 165 Existing OGSES_UNITIA OAK GROVE SES LIG 840 Existing OGSES_UNIT2 OAK GROVE SEt LIG 825 Existing OECCS_R11 ODESSA ECTOR CCS NG 163 Existing OECCS_CT12 ODESSA ECTOR CCS NG 151 Existing OECCS_CR1 ODESSAECTORCCS NG 156 Existing OECCS_CI22 ODESSA ECTOR CCS NG 153 Existing OECCS_UNIT1 ODESSAECTORCCS NG 216 Existing OECCS_UNIT2 ODESSA ECTOR CCS NG 216 Existing OKLA_OKLA_G1 OKLAUNION BIT 650 Existing Z NGR_OLING_1 OLINGER NG 78 Existing NGR_OLING_2 OLINGER NG 107 Existing OLINGR_OLING_3 OLINGER NG 146 Existing OLINGR_OLING_4 OLINGER NG 84 Existing P5G_PSG_GT2 PAS EN NG 176 Existing PSG_PSG_GT3 PAS EN NG 176 Existing PSG_PSG_SR PASGEN WH 169 Existing PEARSALL_PEARS_1 PEARSALL NG 25 Existing PEARSALL_PEARS_2 PEARSALL NG 25 Existing PEARSALL_PEARS_3 PEARSALL NG 25 Existing PEARSAL2_AGR_A PEARSALL POWER PLANT 2 NG 51 Existing PEARSAL2_AGR_B PEARSALL POWER PLANT 2 NG 51 Existing PEARSAL2_AGR_C PEARSALLPOWER PLANT 2 NG 51 Existing PEARSAL2_AGfl D PEARSALLPOWER PLANT 2 NG 51 Existing PB25ES_CT1 PERMIAN BASIN SES RELIANT NG 71 Existing PB2SES_CT2 PERMIAN BASIN SES RELIANT NG 71 Existing PB2SE5_CT3 PERMIAN BASIN SES RELIANT NG 74 Existing PB2SE5_Ct4 PERMIAN BASIN SES RELIANT INS 75 Existing PB2SE5 Ct5 PERMIAN BASIN SES RELIANT NIS 75 Existing QALSW GT1 QUAIL SWITCH NG 84 Existing QALSW GT2 QUAIL SWITCH NG 86 Existing QALSW_GT3 QUAIL SWITCH NG g1 Existing OALSW GT4 QUAILS ITCH NG 81 Existing QALSW SrGl QUAIL SWITCH ING 98 Existing OALSW_SFG2 QUAILSWITCH NG 9g Existing RIONOG_CTI RIO NOGALES POWER PROJECT NG 175Existing RIONOG_CR RIO NOGALES POWER PROJECT NG 175 Existing RIONOG_CT3 RIO NOGALES POWER PROJECT NG 175 Existing RIONOG_Si1 RIO NOGALES POWER PROJECT WH 323 Existing RAYBURN_RAYBURG1 SAM RAYBURN SWITCHYD NG 14 Existing RAYBURN_RAYBURG2 SAMRAYBURNSWITCHYD NG 14 Existing RAYBURN_RAYBURG7 SAM RAY URN SWITCHYD NG 50 Existing RAYBURN_RAYBURGB SAM RAY URN SWITCHYD NG 51 Existing RAYBURN_RAYBURG9 SAM RAY URN SWITCHYD NG 50 Existing RAYBURN_RAYBURG10 SAM RAYBURN SWITCHYD WH 40 Existing SJS SJS G1 SANJACINTOSTEAM NG 81 Existing SIS S15 G2 SAN JACINTO STEAM NG 81 Existing SANMIGL_SANMIGGI SANMIGUELGEN LIG 391 Existing SANDHSVD_SH 5A SANDHILLPOWER STATION NG 170 Existing SANDHSYD_SM_5C SANOHILL POWER STATION NG 160 Existing SANDHSYD_SH1 SANOHILL POWER STATION NG 48 Existing SANDHSYD_SH2 SANDHILLPOWER STATION NG 48 Existing SANDHSYD_SH3 SANDHILL POWER STATION NG 4g Existing SANDHSYD_SH4 SANDHILL POWER STATION NG 48 Existing SANDHSYD_SH6 SANDHILLPOWERSTATION NG 48 Existing SANDHSYD_5H7 SANDHILL POWER STATION NG 48 Existing SDSSES_UNITS SAND OW55ES LIG 570 Existing SCES_UNIT1 SAND CREEK SUB 970 Existing SIUSRAY_SILAS_10 SILASRAY NG 46 Existing SILASRAY SIIAS_9 SILAS RAY NG 49 Existing SIIASRAY_SRAS_6 SILAS RAY WH 21 Existing GIDEON_GIDEONG1 SIM GIDEON NG 130 Existing GIDEON_GIDEONG2 SIM GIDEON NG 135 Existing GIDEON_GIDEONG3 SIM GIDEON NG 340 Existing DG_FERIS_4UNIT5 SKYLINE LANDFILL GAS UNK 6 Nommod DG_SOME1_1UNIT SOMERSETNORTH SUN 6 Nonmod DG_SOME2_1UNIT SOMERSET SOUTH SUN 5 NonmGd STP_SiP_G1 SOUTH TEXAS PROJECT NUC 1375 Existing STP_STP_G2 SOUTH TEXAS PROJECT NUC 1375 Existing SPNCER_SPNCE_4 SPENCER NG 61 Existing SPNCER_SPNCE_5 SPENCER NG 61 Existing SCSES_UNITIA STRYKER CREEK SES NG 167 Existing SCSES_UNIT2 STRYKER CREEK SES NG 502 Existing DG_VALLI_1UNIT SUNEDISON RABEL ROAD SUN 10 Nonmod DG_VALL2_1UNIT SUNEDISON VALLEY ROAD SUN 10 Nonmod TEN_CT1 TE NASKA (BRAZOS) NG 177 Existing TEN_SFG TENASKA(BRAZOS) WH 106 Existing TNSKA_GT1 TENASKA(TXU) NG 87 Existing TNSKA_GT2 TENASKA(TXU) NG 87 Existing

175 P knu, ...... „ UC .^ ...... P1arr im... . _ ....•. r Source^ ^ (1Ay ^ry 7-1 TNSKA STG TENASKA(TXU) WH 89 Existing DG_WALZE_4UNIT5 TESSMAN ROAD MTE 10 Nonmod TXCTY_CFA TEXAS CITY GEN NG 102 Exis[ing TXCTYCTB TEXAS CITY GEN NG 102 Existing T%CTY_CFC TEXAS CITY GEN NG 102 Existing TXCTY_ST TEXASCITYGEN WH 131 Existing TGF_TGFGT_1 TEXAS GULF SULPHUR NG 89 Existing THW_THWGT_1 TH WHARTON NG 13 Existing THW_THWGT31 TH WHARTON NG 57 Existing THW_THWGT32 TH WHARTON NG 57 Existing THW_THWGT33 TH WHARTON NG 57 Existing THW_THWGT34 TH WHARTON NG 57 Existing THW_THWGT41 TH WHARTON NG 57 Existing THW_THWGf42 TH WHARTON NG 57 Existing THW_THWGT43 TH WHARTON NG 57 Existing THW_THWGT44 TH WHARTON NG 57 Existing THW_THWGT51 TH WHARTON NG 57 Existing THW_THWGT52 TH WHARTON NG 57 Existing THW_THWGT53 TH WHARTON NG 57 Existing THW_THWGT54 TH WHARTON NG 57 Existing THW_THWGT55 TH WHARTON NG 57 Existing THW_THWGT56 TH WHARTON NG 57 Existing THW_THWSf_3 TH WHARTON NG 104 Existing THW_THWSi_4 TH WHARTON NG 104 Existing TNP_ONE_TNP_O_1 TNP ONE PLANT LIG 158 Existing TNP_ONE_TNP_O_2 TNP ONE PLANT LIG 158 Existing ETCCS_CF1 TRACTEBEL NG 231 Existing ETCCS_UNIT1 TRACTEBEL NG 127 Existing TRSES_UNIT6 TR IDADSESNI NG 226 Existing DG_KLBRG_1UNIT TRINITYOAKS LFG LFG 3 Nonrnnd BRAUNIG_AVRS_CF1 VH BRAUNIG NG 178 Existing BRAUNIG_AVR1_Cr2 VH BRAUNIG NG 178 Existing BRAUNIG_VHB1 VH BRAUNIG NG 220 Existing BRAUNIG_VHB2 VH BRAUNIG NG 230 Existing BRAUNIG_VHB3 VH BRAUNIG NG 412 Existing BRAUNIG_VHB6CF5 VH BRAUNIG NG Al Existing BRAUNIG_VHB6CT6 VH BRAUNIG NG 48 Existing BRAUNIG_VHB6CT7 VH BRAUNIG NG 48 Existing BRAUN IG_VHB6Cf8 VH BRAUNIG NG 48 Existing BRAUNIG_AVR1_ST VH BRAUNIG WH 184 Existing VICTORIA_VICTORG6 VICTORIA NG 169 Existing VICTORIA_VICTORG5 VICfORIA WH 132 Existing WAP_WAP_G5 WAPARISH BIT 659 Existing WAP_WAP_G6 WA PARISH BIT 658 Existing WAP_WAP_G7 WA PARISH BIT 577 Existing WAP_WAP_G8 WA PARISH BIT 610 Existing WAP_WAP_G1 WAPARISH NG 169 Existing WAP_WAP_G2 WAPARISH NG 169 Existing WAP_WAP_G3 WAPARISH NG 258 Existing WAP_WAP_G4 WAPARISH NG 552 Existing WAP_WAPGT_1 WAPARISH NG 13 Existing PNPI_GT2 WA Parish Addition NG 98 Existing WEBBER_S_WSPS WEBBERVILLE SUN 29 Existing DG_WSML_3UNIT5 WESTSIDE LEG 5 Nonrnod WND_WHITNEY2 WHITNEY DAM WAT 15 Existing WFCOGEN_UNIT1 WICHITA FALLS COGEN SWITCH NG 21 Existing WFCOGEN_UNIT2 WICHITA FALLS COGEN SWITCH NG 21 Existing WFCOGEN_UNIT3 WICHITA FALLS COGEN SWITCH NG 21 Existing WFCOGEN_UNIT4 WICHITA FALLS COGEN SWITCH WH 16 Existing WIPOPA_WPP_G1 WINCHESTER POWER PARK NG 46 Existing WIPOPA_WPP_G2 WINCHESTER POWER PARE NG 46 Existing WIPOPA_WPP_G3 WINCHESTER POWER PARK NG 46 Existing WIPOPA_WPP_G4 WINCHESTER POWER PARK NG 46 Existing WIRTZ_WIRT2_G1 WIRTZ WAT 29 Existing WIRTZ_WIRT2_G2 WIRTZ WAT 29 Existing WCPP_CF1 WISE COUNTY POWER PLANT NG 260 Existing WCPP_Cf2 WISE COUNTY POWER PLANT NG 260 Existing WCPP_ST1 WISECOUNTY POWERPLANT NG 290 Existing WHCCS_CT1 WOLFHOLLOWGEN NG 249 Existing WHCCS_CR WOLF HOLLOW GEN NG 249 Existing WHCCS_STG WOLF HOLLOW GEN WH 293 Existing Total Exiating Resouroes 65212

Total Planned non-Wind Resources

PUN AGGREGATE PUN OUTPUT TO GRID OTH 4390 PUN Adjustment based on PUN info request, 4/5/13 OTH -59 PUN Total Private Use Networks 4331

FTR_FTR_G1 FRONTIER NG 180 SwItchable FTR_FTR_G2 FRONTIER NG 180 Switchable FTR_FTR_G3 FRONTIER NG 180 Switchable KMCHI_1CT101 KIAMICHI ENERGY FACILITY NG 178 Switchable KMCHI_1CR01 KIAMICHIENERGYFACILITy NG 180Swltchable KMCHI_2CT101 KIAMICHIENERGYFACILITY NG 178Switchable KMCHI_2CT201 KIAMICHI ENERGY FACILITY NG 180 Switchable TGCCS_CT1 TENPSKAGATEWAY NG 162 Switchable TGCCS_CR TENASKAGATEWAY NG 179 Switchable TGCCS_CF3 TENASKAGATEWAY NG 178 Switchable FTR_FTR_G4 FRONTIER WH 390 Switchable KMCHI_1Sf KIAMICHIENERGY FACILITY WH 307 Switchable KMCHI_2ST KIAMICHI ENERGY FACILITY WH 307 Switthable TGCCS_UNIT4 TENASKA GATEWAY WH 389 Switchable TotalSwitchzbk Resources 3168

ANACACHO_ANA Anacacho Windfarm WND 101 Wind BRAZ WND_WND1 Green Mountain Energy 1 WND 99 Wind BRAZ_WND_WND2 Green Mountain Energy 2 WND 61 Wind

176 I z Z' Pn 1:.ru'.aP^7 IMItCode , PlanNa_... ^^ UM9 ^ BRTSW_BCW1 BartonChapel Wind WND 120 Wind BCATWIND_WIND_1 Bobcat Bluff WND 163 Wind BUFF_GAP_UNIT1 BuffaloGapWind Farm1 WND 121 Wind BUFF_GAP_UNIT2_1 BuffaloGapWind Farm2 WND 116Wind BUFF_GAP_UNIT2_2 Buff31o Gap Wind Farm 2 WND 117 Wind BUFF_GAP_UNIT3 Buffalo Gap Wind Farm 3 WND 170 Wind BULLCRK_WND1 Bull Cr ::. Wind Plant WND 88 Wind BULLCRK_WND2 Bull Creek Wind Plant WND 90 Wind CAPRIDG4_CR4 CapricornRidgeWind4 WND 113 Wind CAPRIDGE_CRI Capricorn Ridge Wind 1 WND 215 Wind CAPRIDGE_CR2 CapricornRidgeWind3 WND 150 Wind CAPRIDGE_CR3 Capricorn Ridge Wind 2 WND 186 Wind CEDROHIL_CHW1 Cedro Hill Wind WND 150 Wind CHAMPION_UNIT1 Champion Wind Farm WND 127Wind CSEC_CSECG1 Camp Springs1 WND 134 Wind CSEC_CSECG2 CampSprings2 WND 124 Wind DG_ROSC2_1UNIT TSTCWest TexasWind WND 2 Wind DG_TURL_UNIT1 WOLFEFIATS WND 1 Wind ELB_ELBCREEK Elbow Creek Wind Projecn WND 119 Wind ENAS_ENA1 Snyder Wind Farm WND 63 Wind E%GNWTL_WIND 1 Whitetail Wind EnHrgy Project WND 91 Wind FLTCK_551 Silver5tar WND 60 Wind GOAT_GOATWIN2 Goat Wind 2 WND 70 Wind GOAT_GOATWIND Goat Wind WND 80 Wind HHGT_CALLAHAN HorseHollowWindCallahan WND 114 Wind HHGT_HHOLLOW1 Huron Hollow Wind 1 WND 213 Wind HHGT_HHOLLOW2 Horse HollowWind2 WIND 184 Wind HHGT_HHOLLOW3 Horse Hollow Wind 3 WND 224 Wind HHGT_HHOLLOW4 HorseHollow Wind4 WND 115 Wind HWF_HWFG1 Hackberry Wind Farm WND 162 Wind INDL_INADALEI Inadale Wind WND 197 Wind INDNENR_INDNENR Desert Sky Wind Farm 1 WND 84 Wind INDNENR_INDNENR_2 Desert Sky Wind Farm 2 WND 77 Wind INDNNWP_INDNNWP Indian Mesa Wind Farm WND B3 Wind KEO_KEO_SMl Sherbino I WND 150 Wind KEO_SHRBINO2 Sher bino2 WND 150 Wind KING_NE_KINGNE King Mountaln NE WND 79 Wind KING_NW_KINGNW King Mountain NW WND 79 Wind KING_SE_KINGSE King Mountain SE WND 40 Wind KING_SW_KINGSW King Mountain SW WND 79 Wind KUNITZ_WIND_LGE Kunitz Wind WND 40 Wind KUNITZ_WIND_NWP Delaware Mountain Wind Farm WND 30 Wind LGD_LANGFORD Langford Wind Power WND 155 Wind LNCRK_G83 Mesquite Wind WND 200 Wind LNCRK2_G871 PostOakWindl WND lOD Wind LNCRK2_G872 Pont Oak Wind 2 WND 100 Wind LONEWOLF_G1 Loraine Windparkl WND 50 Wind LONEWOLF_G2 Loralne Windpark II WND 51 Wind LONEWOLF_G3 Loraine Windpark III WND 26 Wind LONEWOLF_G4 Loraine Windpark IV WOO 24 Wind MCDLD_FCW1 Forest Creek Wind Farm WND 124 Wind MCDLD_SBW1 Sand Bluff Wind Farm WND 90 Wind MOZART_WIND 1 WKNMoiart WND 30 Wind MWEC_G1 McAdoo Wind Farm WND 150 Wind NWF_NWFI Notrees-1 WND 153 Wind OWF_OWF Ocotillo Wind Parer WND 60 Wind PC NORTH_PANTHERI Panther Creek 1 WND 143 Wlnd PC SOUTH_PANTHER2 Panther Creek2 WND 116 Wind PC_SOUTH_PANTHER3 Panther Creek3 WND 200 Wind PYR_PYRON1 Pyron Wind Farm WIND 249 Wind RDCANYON_RDCNYI Red Canyon WND 84 Wind SENATEWD_UNIT1 Senate Wind Project WND 150 Wind SGMTN_SIGNALMT Texas Big Spring WND 34 Wind SNJFT1 South Trent Wind Farm WND 101 Wind SIN MESA SW MESA West Texas Wind Energy WND 74 Wind SWEC_G1 Stanton Wind Energy WND 124 Wind SWEETWN2_WND2 SweetwzterWind3 WND 98 Wind SWEETWN2_WND24 SweetwaterWind 2 WND 16 Wind SWEETWN3_WND3A SweetwaterWind4 WND 30 Wind SWEETWN3_WND3B SweetwaterWind4 WND 101 Wind SWEETWN4_WND4A SweetwaterWlnd7 WND 118 Wind SWEETWN4_WND4B SweetwaterWind6 WND 304 Wind SWEETWN4_WNDS SweetwaterWind 5 WND 79 Wind SWEETWND_WND1 SweetwaterWind l WND 37 Wind TKWSWS_ROSCOE Roscoe Wind Farm WND 209 Wind TRENT TRENT Inert Wind Farm WND 151 Wind TRINITYTH1_BU51 TrinityHilis WND 118 Wind TRINITY THS_BUS2 TrinityHills WND 108 Wind TTWEC_G1 Turkey Track Wind Energy Center WND 170 Wind WECWECG1 Whirlwind Energy WND 57 Wind WHTTAILWRl Wolfe Ridge WND 113 Wind WOODWRDI_WOODWRD1 Pecot Wind (Woodward 0) WND 83 Wind WOODWRD2_WOODWRD2 Pecos Wind (Woodward 2) WND 77 Wind COTTON_PAP2 Papalote Creek Wind WND 200 Wind' 0G_NUECE_6UNIT5 Harbor Wind WND 9 Wind' LVl_LV1B LosVientosl WND 200 Wind" LV1_LV1A LosVientos2 WND 200 Wind' PAPS_PAP1 Papalote Creek Wind Farm WND 180 Wind' PENA_UNITl Penzscal Wind WND 161 Wind' PENA_UNIT2 Penascal Wind WND 142 Wind' PENA3_UNIT3 Penascal Wind WND 101 Wind' REDFISH_MV1A Magic Valley Wind WND 103 Wind' REDFISH_MV1B Magic Valley Wind WND 103 Wind' TGW_Tl GuIPWindl WND 142 Wind' TGW_T2 GulfWindll WND 142 Wind' Total Wind Resources 10970

BLSUMMIT_BLSMT1_5 Blue Summit Windfarm 1 WNO 9 New

177 .... , I ^vr«n.ry^Enerqy wira^c^,arny ^ ^,•^:::^ "'t, Code ^ ...... P1amNmie so^,roe tt^a9

BLSUMMI7 BLSMT7 6 Blue 5ummit Windfarm 2 WND 126 New

Total Planned Wind Resourees 135

' Coastal Wind

178 Seasonal Assessment of Resource Adequacy for the ERCOT Region

Backuound

The Seasonal Assessment of Resource Adequacy (SARA) report is a deterministic approach to considering the impact of potential variables that may impact the sufficiency of installed resources to meet the peak electrical demand on the ERCOT System during a particular season.

The SARA report is intended to illustrate the range of resource adequacy outcomes that might occur, and thus help fulfill the reporting requirement per Public Utility Commission of Texas rule 25.362(i)(2)(H). Several sensitivity analyses are developed by varying the value of certain parameters that affect resource adequacy. The variation in these parameters is either based on historic values of these parameters, adjusted by any known or expected change.

179 Attachment I

2013 Report on Existing and Potential Electric System Constraints and Needs

180 ERCOT

Report on Existing and Potential

Electric System Constraints and Needs

December 2013

181 2013 Electric System Constraints and Needs December 30, 2013

ERCOT Report on Existing and Potential Electric System Constraints and Needs

Executive Summary

The annual Electric System Constraints and Needs report is provided by the Electric Reliability Council of Texas, Inc. (ERCOT) to identify and analyze existing and potential constraints in the transmission system that pose reliability concerns or may increase costs to the electric power market and ultimately, to Texas consumers. This report satisfies the annual reporting requirements of Public Utility Regulatory Act (PURA) Section 39.155(b) and a portion of the requirements of Public Utility Commission Substantive Rules 25.361(i)(2)(I) and 25.505(c).

ERCOT and Transmission Service Providers (TSPs) have been diligently pursuing projects to address demand increases related to oil and natural gas exploration and production in Texas. In 2013, the most significant constraints experienced on the ERCOT System were located in areas that have experienced oil and natural gas correlated load growth. In West Texas the continued expansion of oil and natural gas recovery in the Permian Basin shale play has increased electric demand in the area causing a substantial amount of congestion on some transmission elements. However, the congestion has decreased measurably since 2012 due to the implementation of planned transmission system improvements in the area.

In South Texas the development of the Eagle Ford shale play has continued to cause the need for transmission system improvements. In 2013, three sets of transmission projects in the Eagle Ford Shale area were reviewed and accepted by the Regional Planning Group (RPG) and ERCOT. In total, an estimated $330.8 million worth of transmission system improvements in the Eagle Ford Shale area have been accepted by the RPG since 2012. These projects are expected to be in service between 2014 and 2017.

The Denton area has recently experienced congestion due to an increase in load and due to local transmission circuits being taken out of service so they could be upgraded. Several additional improvements are planned for the area between 2014 and 2016.

Persistent load growth in the Houston area has caused transmission lines by which power is imported into the area from the north to be highly congested in 2013 ($38.5 million in congestion rent through October). Long-term studies have consistently identified the need to increase the import capacity of the transmission system in the area, and more recently several

182 2013 Electric System Constraints and Needs December 30, 2013

TSPs have detailed reliability criteria violations by 2018 if solutions are not implemented. ERCOT and the RPG are currently reviewing several proposals to increase the import capability and expect to have a recommendation in early 2014.

Elsewhere on the ERCOT System, the completion of the Competitive Renewable Energy Zone (CREZ) project at the end of 2013 is expected to resolve the West to North stability limit. The partially completed CREZ project has already had a considerable effect in mitigating congestion in West Texas. Through October 2013 the West to North stability limit was not even in the top 30 highest congested constraints while it had the third highest amount of congestion rent in ERCOT in 2012 and the highest in 2011.

The Panhandle region of the CREZ project is experiencing significantly more interest from wind generation developers as compared to what was initially planned for the area in terms of transmission export capability. This area is also seeing the more generation interconnection activity as compared to other areas of development on the ERCOT System. ERCOT is currently conducting an analysis to determine the next steps for transmission system improvements in order to meet the needs of the system. The report for this study is expected to be released in early 2014.

In the Lower Rio Grande Valley (LRGV), a new 345 kV import line and the upgrade of the two existing 345 kV import lines are part of a project to increase the overall import capability into the area by 2016. Additionally, a new 345 kV line that runs from the west side of the LRGV to the east side is planned to meet reliability needs in and around the Brownsville area. These projects have an estimated capital cost of almost $800 million.

183 2013 Electric System Constraints and Needs December 30, 2013

ERCOT Report on Existing and Potential Electric System Constraints and Needs

Table of Contents

1. Introduction ...... 1

2. ERCOT Transmission Planning ...... 2

3. Recent Constraints ...... 4 3.1 West Texas Load Growth ...... 7 3.2 Houston Import ...... 16 3.3 Denton Area ...... 19 3.4 West-to-North Stability Limit ...... 21

4. Planned Improvements ...... 26 4.1 Eagle Ford Shale Oil and Natural Gas Related Projects ...... 28 4.2 Valley Import Project ...... 31 4.3 Cross Valley Project ...... 32 4.4 Additional Reliability Driven Planned Improvements ...... 33

5. Projected Constraints ...... 35 5.1 2014 Reliability Constraints ...... 35 5.2 2016 and 2018 Projected Constraints ...... 38

6. Long-Term System Assessment ...... 41

7. Contacts and Links ...... 42 7.1 Contacts and Information ...... 42 7.2 Internet Links ...... 42

8. Disclaimer ...... 43

184 2013 Electric System Constraints and Needs December 30, 2013

1. Introduction

The Electric Reliability Council of Texas (ERCOT), as the independent organization (10) under the Public Utility Regulatory Act (PURA), is charged with nondiscriminatory coordination of market transactions, system-wide transmission planning and network reliability, and ensuring the reliability and adequacy of the regional electric network in accordance with ERCOT and North American Electric Reliability Corporation (NERC) Reliability Standards. The IO ensures access to the transmission and distribution systems for all buyers and sellers of electricity on nondiscriminatory terms. In addition, ERCOT, as the NERC registered Planning Coordinator/ Planning Authority, is responsible for assessing the longer-term reliability for the ERCOT Region.

ERCOT supervises and exercises comprehensive independent authority of the overall planning of transmission projects of the ERCOT Transmission System as outlined in PURA and Public Utility Commission of Texas (PUCT) Substantive Rules. ERCOT's authority with respect to transmission projects that are local in nature is limited to supervising and coordinating the planning activities of Transmission Service Providers (TSPs). The PUCT Substantive Rules further indicate that the 10 shall evaluate and make a recommendation to the PUCT as to the need for any transmission facility over which it has comprehensive transmission planning authority. In performing its evaluation of different transmission projects, ERCOT takes into consideration the need for and cost-effectiveness of proposed transmission projects in meeting the ERCOT planning criteria and NERC Reliability Standards.

Transmission planning (60 kV and above) is a complex undertaking that requires significant work by, and coordination between, ERCOT, the TSPs, stakeholders, and other Market Participants. ERCOT works directly with the TSPs, stakeholders, and Market Participants through the Regional Planning Group (RPG). Each of these entities has responsibilities to ensure the appropriate transmission planning and construction occurs.

The Protocols and Planning Guide describe the practices and procedures through which ERCOT meets its requirements related to system planning under PURA, NERC Reliability Standards, and PUCT Substantive Rules.

185 2013 Electric System Constraints and Needs December 30, 2013

2. ERCOT Transmission Planning

Every year ERCOT performs a planning assessment of the transmission system. This assessment is primarily based on three sets of studies:

1. The Regional Transmission Plan (formerly known as the Five-Year Transmission Plan) addresses region-wide reliability and economic transmission needs and includes the recommendation of specific planned improvements to meet those needs for the upcoming five years. The 2013 Regional Transmission Plan report is posted on the ERCOT Planning and Operations Information website. 2. The Long-Term System Assessment (LTSA) uses scenario analysis techniques to assess the potential needs of the ERCOT System up to 20 years into the future. The role of the LTSA is not to recommend the construction of specific system upgrades due to the high degree of uncertainty associated with the amount and location of loads and resources in this timeframe. Instead, the role of the LTSA is to identify upgrades that provide benefits across a range of scenarios or might be more economic than the upgrades that would be determined considering only near-term needs in the Regional Transmission Plan development. The LTSA study is conducted in even-numbered years and reviewed in odd-numbered years. The 2012 Long-Term System Assessment report is posted on the ERCOT website in the following location: http://www.ercot.com/news/presentations/. In 2010 ERCOT received grant funding from the Department of Energy (DOE) to augment and enhance the existing long-range planning efforts for the ERCOT region. The report detailing the results of this endeavor was published in December 2013 and can be found on the ERCOT website at the following location: http://www.ercot.com/committees/other/Its/index. 3. Stability studies are performed to assess the angular, voltage, and frequency response of the ERCOT System. Due to the sensitive nature of the information contained in these study reports, they are not normally published on the ERCOT website.

These studies are conducted using models that represent expected future transmission topology, demand, and generation. The models are tested against reliability and economic planning criteria per NERC Standards and the ERCOT Protocols and Planning Guide. When system simulations indicate a deficiency in meeting the criteria, a corrective action plan will be put in place which typically includes a planned transmission improvement project. TSPs also perform studies to assess the reliability of their portion of the ERCOT System.

Transmission improvement projects that are estimated to cost more than $15 million or that require a Certificate of Convenience and Necessity (CCN) are reviewed by the RPG prior to

186 2013 Electric System Constraints and Needs December 30, 2013 implementation'. The RPG is a non-voting group made up of ERCOT, TSPs, Market Participants, other stakeholders, and PUCT Staff. The RPG reviewed and accepted $349.8 million of transmission improvement projects in 2013.

Transmission system improvements are built by TSPs and are paid for by consumers. During the twelve month period from October 2012 through September 2013, TSPs completed $4.08 billion in transmission projects, of which $3.04 billion is related to the Competitive Renewable Energy Zone (CREZ) project. The total includes the addition or upgrade of 4,156 miles of transmission circuits, the addition of 6,137 MVA of autotransformer capacity, and the addition of 1,539 MVAr of reactive capability. A comprehensive list of recently completed and future transmission projects can be found in the Transmission Project Information Tracking (TPIT) report which is updated three times a year and can be located on the ERCOT Planning and Operations Information website.

1 Per ERCOT Protocol Section 3.11.4 certain projects are exempt from RPG review, such as projects to serve new generation or load customers.

187 2013 Electric System Constraints and Needs December 30, 2013

3. Recent Constraints

Congestion occurs when transmission limitations do not allow for the most efficient dispatch of generation to meet a given demand. The table and maps below show the top 15 congested constraints on the ERCOT System from January through October 2013 based on real-time data.

Map Index Constraint Congestion Rent 1 Odessa - Odessa North 138 kV line $56,980,309 "_d . m . .^^ -^ [ 2 Odessa EHV Switch Big ThrPP Odessa Tap 138 kV line $3 1, 616 390 ^ 3 Singleton - Zenith 345 kV line $28,965,042 4 Jim Christal - North Denton 138 kV line $18,679,874 _.. _ ...... _.. ,. . .. ^... . . ^_- _ 5 Bluff Creek- China Grove 138 kV line 17,681,085 6 Fort Worth -Teasley 138 kV line $16,898,845 7 Moss Switch -Amoco North Cowden Tap 138 kV line $15,801,329 8 Morgan Creek 345/ 138 kV transformer 44 $15,449,781 9 Cagnon 345/ 138 kV transformer #4 $15, 071, 626 10 Morgan Creek 345/ 138 kV transformer #1 $13,856,667^ ^ 11 Austrop 345/ 138 kV transformer $11,898,409 12 Teasley - Pockrus 138 kV line $11,227,954 13 North Edinburg - Lon Hill 345 kV line $7,633,932 14 Hutto - Round Rock Northeast 138 kV line $7,338,051 15 Austrop - Dunlap 138 kV line $6,752,182

188 2013 Electric System Constraints and Needs December 30, 2013

Recent constraints in West Texas

189 2013 Electric System Constraints and Needs December 30, 2013

Recent constraints in North Texas

Recent constraints in Central Texas

190 2013 Electric System Constraints and Needs December 30, 2013

Z-..( cori3u% Christi

,-.

^ Raymondville

Edinburg

McAllen Harlingen

Pharr

Recent constraints in South Texas

The following sections provide more details on recent constraints on the ERCOT System.

3.1 West Texas Load Growth

As in 2012, the most significant congestion on the ERCOT System in 2013 was experienced in West Texas due to the growth in electric demand from the oil and natural gas industry and

191 2013 Electric System Constraints and Needs December 30, 2013

associated economic expansion in residential and commercial developments in the Permian Basin area. However, the congestion experienced in the area in 2013 has decreased since 2012 due to the transmission improvement projects that have been put in place. Of the top 15 constraints on the ERCOT System from January 2013 through October 2013, six were related to constraints serving West Texas load, compared to eight over the same period in 2012. Moreover, the most constrained element on the system in 2012, the Odessa North 138/ 69 kV transformer, had over $134 million in congestion rent before being replaced by a larger transformer in November 2012 while the top constraint in 2013, the Odessa - Odessa North 138 kV line, experienced less than $57 million in congestion rent through the first ten months of the year.

Multiple transmission improvements have contributed to the decrease in congestion experienced in West Texas in 2013. The table and map below shows some of the significant improvements in the area.

Mapindex Transmission Improvement Date Completed p 1 Moss - Westover 138 kV line terminal equipment upgrade September 2012 _.. _. _...... _.._ _- __.. _ ....,_... __.^... :_.^_,.. _.._.. . ,: 2 Odessa North - Holt 69 kV line terminal equipment upgrade September 2012 3 Odessa North - Cowden North 69 kV line terminal equipment September 2012 am . _. . upgrade^.^_ .. ._^.e^ _.._.e ^. _...^ ._.^. 4 Odessa North 138/69kV transformer upgrade November 2012 5 Moss - Odessa EHV 138 kV line uprate December 2012 ^.. a . ^.. nn._ . . ,:: . ^„ .^... ^.. a _^ 6 Reconfigure/ Upgrade system to create new Moss - Goldsmith June 2013 Junction - Holt 138 kV line . - 7 Moss - Holt 138 kV line uprate June 2013 8 Permian Basin - Wink 138 kV line terminal equipment upgrade June 2013 . __ ...... _.... . ^... r ___...... _ 9 Fullerton - Exxon Fullerton 69 kV line upgrade July 2013 10 ^ Install new Willow Valley/ Faraday 345/ 38 kV transformer September 2013

192 2013 Electric System Constraints and Needs December 30, 2013

Gail

Big Spring ,,.. Andrews

Midland -. - ^ , <. - - .,--.-- ^: Odessa

In addition to the above projects, Oncor Electric Delivery installed dynamic line rating (DLR) equipment on five transmission lines in West Texas in June 2013 in an effort to increase transmission capacity in the area. Typically the capacity of a transmission line is limited by the thermal characteristics of the conductor. In many cases a static ambient air temperature, wind speed and wind direction are assumed, usually based on summer peak conditions, when calculating the design capacity of a line. In ERCOT TSPs may elect to utilize an ambient temperature assumption that is adjusted dynamically based on the real-time temperature the line is experiencing to adjust real-time ratings used in operating the grid. Hence, when the air temperature is cooler the transmission line can carry more power without the risk of thermal overload.

193 2013 Electric System Constraints and Needs December 30, 2013

The West Texas project that Oncor Electric Delivery pursued takes this concept a step further by installing equipment on each line to monitor conditions in the field. The equipment not only monitors ambient temperature, but also takes into account solar radiation and wind speed and direction to more accurately calculate the real-time thermal capacity of a line. This has been shown to increase the capacity of a transmission line most of the hours of the year. The project involved installing DLR equipment on the following five transmission lines in order to improve operating flexibility and to reduce congestion:

• Odessa - Odessa North 138 kV line • Moss - Amoco Cowden North - Holt 138 kV line • Holt - Emma Tap 69 kV line • Moss - Odessa Southwest - Odessa EHV 138 kV line • Midland East - Windwood 138 kV line

The chart below shows the percent increase in line capacity due to the installation of the DLR equipment when compared to strictly an ambient temperature adjusted rating (AAR) for the Odessa - Odessa North 138 kV line. The data indicates that from July through September of 2013 the line capacity rating using DLR equipment was higher than the AAR about 80% of the time (red line on chart). This illustrates the benefit that the DLR equipment can provide.

DLR'v OVER AAR ODESSA - ODESSA NORTH 138 kV

-Imtiai{^rutrrn ----.Firs:Se^acnR^'.Snem^ni ^---160';L ...... 101:1 110n ...... 125!^ . . 25M.. ^ . ... _.. ?q'r. ^ ...... _ ......

4IIESSA=DDESSANOltTY113SbV 1:O^...... _...... OPESA ,QDPd7H .. .

i1^v ._...... _.... .__ _ ^ ^ . DlR%OVER AAR 1WhrSeg AAR 8X II 190,. _...... _...... _. .: .^...... __. 305°i; .^^72% , ...... ^. . '. 110% ^ ^. 61:p .^ .^ 1805: . 1dS% 83,a 170% ...... _...... _.... __.... . Q .._. . . . ^...... - *° 1.6014

150°.6 ._.... . ' ...... _ ......

140% ___- _'^...... _ ._. . __.,. _____... .d. ..:......

130%

12056 . .. ^ ...... ^ ..^ ^ 310% ....^.._ _ .... ^® <...... _ ,-. . `'^-^zw.^ . ... ^e ^. c-1-ti-..,. _ .,.-.....m. ^..^. ^,.,w ...... ® . .^ _, .„_ ,_ ___.-<.-.... _ 1k0% ^ ^ ^ I , ...... ^ . , 9W. .... --....^ . $o% ^... . :r.. 1^^. _... i.r, an-: so1-, e^r; , _ . aoc^ ^„n^. ..^^•...

'.OF TIME

194 2013 Electric System Constraints and Needs December 30, 2013

Most of the remaining congestion in the area can be attributed to the significant increase in demand in the Far West weather zone in ERCOT. The chart below shows the annual peak demand increase in the Far West weather zone for years 2007 through 2013. The data shows an average annual peak demand growth rate of 6.7% from 2010 to 2013. It should be noted that other areas in ERCOT saw lower peak demand in 2012 and 2013 than in 2011 because 2011 had an extremely hot summer. Conversely, the Far West weather zone peak demand continued to increase despite the relatively cooler temperatures.

Far West Weather Zone Annual Peak

2300

2200

2100

200C?

1900 ...... : . 1800 1_ ...... _._._ _

1700

1600 ^ - ; --, 2007 2008 2009 2010 2011 2012 2013

195 2013 Electric System Constraints and Needs December 30, 2013

The chart below shows the total annual energy use in the Far West weather zone from 2007 through 2012. The data indicates that total energy usage grew at a faster rate than the peak demand from 2010 to 2012.

Far West Weather Zone Annual Energy

13.5

13 ------^___ - _ ^

12.5 ^------

^ 12

11.5 _ _------^ =----^__ _ -_^.

LU 10.5

10 -^ - ^- j 2007 2008 2009 2010 2011 2012

The majority of the load increase in the area can be ascribed to the increase in the oil and natural gas industry and the associated economic expansion in residential and commercial developments. The chart below illustrates the increase in oil production in Texas District 8, which encompasses much of the Permian Basin and includes the Odessa area, between 2007 and 2013. The crude oil production increase between January 2010 and summer 2013 was nearly 40%.

196 2013 Electric System Constraints and Needs December 30, 2013

Texas District 8 Oil and Gas Monthly Production 16 42

15 V 14 37

13 32 12 ^.._... M ' O 11 G n r 27 Z

0 10 ^" ^ cea? M 7, ^P_....., 22

8 Ni

7 L 17 R R R co co CO 61 0) ;J1 O 0 0 .-i ri ri N N N co M O O O O O O O O O ^ .-1 .-rt3 ri ri .-i ri ..--I r-I e-I r-I C T Q C >- fl. C T Q. C 7• a C >- f3. C T ^ C ?- m ra o^ m ia d rts M ar ^a rts n^ css M ar ^s ea ai t^ so ^ 2 ;n - 2 ^ ^ 2 ^ ^ U-) ^ N Ln

-Crude Oil Production (MMbbL) Source: Texas Raiiraat! Commission -Casinghead Gas Production (BCF)

Because of the upsurge in oil and natural gas production the local economy in the area has experienced a boom. The two largest cities in the area, Midland and Odessa, have been among the fastest growing cities and have seen some of the lowest unemployment rates in the country. Through July, the 2013 Midland unemployment rate has remained below 3.5% and the Odessa rate has not exceeded 4.2%, according to the U.S. Bureau of Labor Statistics.

ERCOT and the TSPs with transmission in the area have been planning system improvements in order to meet the growing needs in West Texas. The table and map below list some of the significant improvements that are expected to be completed between December 2013 and the end of 2014.

197 2013 Electric System Constraints and Needs December 30, 2013

Map__ lndex '. TranszniSsion. ^ . _ Improvement._ . in-service pate 1 Odessa - Odessa North 138 kV line reconductor December 2013 2 Goldsmith South - Goldsmith Junction 69 kV line rebuilt as a 138/ 69 December 2013 kV double circuit line 3 Moss - Holt 138 kV line reconductor January 2014 4 Odessa North Goldsmith Junction 69 kV line rebuilt as a 138/ 69 kV May 2014 double circuit line and Odessa North 138 kV Switch Station 5 Odessa EHV Big 3 Tap Odessa Southwest - Moss 138 kV line May 2014 rebuild y 6 Cactus - Fort Lancaster 69 kV line rebuild May 2014 7 Wink - Pecos 69 kV line rebuild June 2014 8 Wink - Permian Basin 138 kV line reconductor December 2014 9 Odessa -Odessa EHV 138 kV line reconductor December 2014 10 Moss - Westover 138 kV line upgrade December 2014

198 2013 Electric System Constraints and Needs December 30, 2013

The chart below shows the number of original drilling permits issued per month from January 2010 through September 2013 for Texas District 8. The chart shows that permit activity in the Permian Basin has remained strong through summer 2013. This is one indication that demand related to oil and natural gas production is likely to continue to increase.

The demand level utilized in the 2012 Five-Year Transmission Plan, which was completed in December 2012, was based on a forecast dating back to the spring of 2011. In early 2013, ERCOT asked TSPs with assets in West Texas to update the forecast based on the latest information. The updated forecast for 2017 summer peak conditions was 9.4% higher for the West weather zone and 62.8% higher for the Far West weather zone when compared to the forecast used in the 2012 Five-Year Transmission Plan. The map below shows the additional elements overloaded due to the increased load forecast and illustrates a contour map of the increased load on a per-substation basis.

199