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Howard Gugel DRAFT Letter for 21-day notice to FERC from

1. Country Name Abbreviation Canada CA Mexico MX United States US Table 2 1 States United States Name Abb Name Abb Name Abb Alabama AL Kentucky KY Oklahoma OK Alaska AK Louisiana LA Oregon OR American Samoa AS Maine ME Pennsylvania PA Arizona AZ Maryland MD Puerto Rico PR Arkansas AR Massachusetts MA Rhode Island RI California CA Michigan MI South Carolina SC Colorado CO Minnesota MN South Dakota SD Connecticut CT Mississippi MS Tennessee TN Delaware DE Missouri MO Texas TX District of Columbia DC Montana MT Utah UT Florida FL Nebraska NE Vermont VT Georgia GA Nevada NV Virgin Islands VI Guam GU New Hampshire NH Virginia VA Hawaii HI New Jersey NJ Washington WA Idaho ID New Mexico NM West Virginia WV Illinois IL New York NY Wisconsin WI Indiana IN North Carolina NC Wyoming WY lowa IA North Dakota ND Kansas KS Ohio OH Table 3 2 Provinces Canada Name Abb Name Abb Alberta AB Nova Scotia NS British Columbia BC Ontario ON Manitoba MB Prince Edward Island PE New Brunswick NB Quebec OC Newfoundland and Labrador NL Saskatchewan SK NERC GADS W Data Reporting Instructions November 2014 59 Appendix F Reference Tables Table 4 3 States Mexico Name Abb Name Abb Name Abb Aguascalientes AG Guerrero GR Quintana Room QR Baja
2. Equipment Equivalent Forced Outage Factor EEFOF of period that the WTG equipment was forced off line Including low and high winds FTH EFDTH PDTH EEFOF 100 Equipment Equivalent Unplanned Outage Factor EEUOF of period that the WTG equipment was unavailable due to forced and maintenance downtime For generation resource planning FTH MTH EFDTH EMDTH PDTH EEUOF x 100 Equipment Equivalent Scheduled Outage Factor EESOF of period that the WTG equipment was unavailable due to maintenance and planned downtime MTH PTH EMDTH EPDTH PDTH EESOF x 100 Equipment Generating Factor EGF of period that the WTG equipment was online and in a generating state EGF ett x 100 PDTH RUTH Equipment Net Capacity Factor ENCF of actual WTG equipment generation while on line ENCF Bee x100 PDTH RUTH Iw TNMC NERC GADS W Data Reporting Instructions November 2014 38 Appendix E Performance Equations 1 B Equipment Performance Rates 1 B 10 1 B 11 1 B 12 1 B 13 1 B 14 Equipment Equivalent Planned Outage Rate EEPOR Probability of planned WTG equipment downtime when needed for load PTH EPDTH EEPOR CTH PTH RUTH x 100 Equipment Equivalent Maintenance Outage Rate EEMOR Probability of maintenance WTG equipment downtime when needed for load MTH EMDTH EEMOR CTH MTH RUTH x 100
3. The site is de energized The site is on a PO except for the turbine with the bad generator which is FO During the first week of the PO the generator gets replaced and aligned At the point where the generator turbine is available for service it moves from a FO to PO NERC GADS W Data Reporting Instructions November 2014 73 Appendix G Outside Management Control 3 The plant will be down for annual substation maintenance The outage will take 3 weeks and is a PO event During inspection the main transformer failed the Doble test and will need to be replaced Power Transformer Found Defective During Annual Substation Maintenance Annual Substation Maintenance PO Transformer Failure FO Annual Substation Maintenance Ends FO for the transformer begins Time During a PO other work can take place The PO can even be extended if the predefined work is taking longer than expected If additional items are found in need of repair an MO or an FO decision needs to be made At the end of the PO the new outage type becomes primary 4 Aturbine pad mount transformer fails de energizing all the turbines on the circuit The failed transformer was removed and bypassed so the remaining turbines could be re energized During the repair period there was a snow storm followed by an ice storm and these problems prevented the crews from getting to the site A Pad Mount Transfor
4. Column 22 Height of the highest anemometer on the reference meteorological tower NERC GADS W Data Reporting Instructions November 2014 9 Chapter 3 Performance Reporting Performance data provide sub group information in a summarized format pertaining to overall wind turbine operation during a particular month in a given year These data are needed to calculate sub group group and plant performance reliability and availability statistics Performance data are required for all unit types and sizes reported to the GADS W program Performance Record Layout CSV Format Column Field Name Entry Type Mandatory or Optional 1 Plant ID Alpha Numeric 10 Mandatory 2 Group ID Alpha Numeric 10 Mandatory 3 Sub Group ID Alpha Numeric 10 Mandatory 4 NERC Utility Code Alpha Numeric 3 Mandatory 5 NERC Unit Code Alpha Numeric 3 Mandatory 6 Report Period month Numeric 2 Mandatory 7 Report Year Numeric 4 Mandatory 8 Sub Group Status Alpha Numeric 2 Mandatory 9 Gross Actual Generation GAG Numeric 10 2 decimals Mandatory 10 Net Actual Generation NAG Numeric 10 2 decimals Mandatory 11 Net Maximum Capacity NMC Numeric 8 2 decimals Mandatory 12 Period Turbine Hours PDTH Numeric 10 2 decimals Mandatory 13 Contact Turbine Hours CTH Numeric 12 2 decimals Mandatory 14 Reserve Shutdown Turbine Hours RSTH Num
5. Component Outage Reporting 15 Component Record Layout CSV Format 15 Component Turbine Hours and Occurrences esses nennen ener nnns nnne nra a assesses aaua daa sensa sanas snnt 16 Component Derates and Delay Turbine Hours essen eene nennen enne nhan nnne sentita sanas esse sinas n snnt 16 Appendix A GADS W Data Release Guidelines eene nnne enne nennen nhan nsns ennt sanas nn 18 NERC GADS W Data Reporting Instructions November 2014 ii Preface ugeet UL ON EE 18 Data Release GUICGliN eS xccseecetsevceassiessens vessxeeds oapset s oaagnasvaceeetedoanneatvactusucisvasaavencessvecnentasiutesasbesue ENEE EE dE 18 Appendix B Utility and Unit Identitication enne en nnne nnne enters SSE ENKAN ENES enne 19 Utility Identification Kee LEE 19 Getting a New Utility Identification Code eee ener ennt stent istis nnns enne 19 Plant Identification Codes iaiia e aa panaia aa ea a Ra aa aaa a aa i ai 19 Appendix C System Component Codes ccccsssssceecesseseaeeeeeeecessesaaeeeeeceseeseaaeaeeeeesesesaeaeeesecsseeseaaeaeeesseeseaaaeeeeess 20 Appendix D Terms and Definitions eere nnne nnne nnrn enne tenen EAEEREN seni nn s sese tenere sanant 24 Gefieralcstees emitidas eere E 24 Capacity and EE e BEE 24 Group or Sub Group KEE 25 Turbine States and Hours Collection esee eene enne nnne enne nnne en nenren nennen nennen nnne enne 26 Appendix E Performance Equations een 34 SECTION 1 Resource and Equipment Calculations for sub grou
6. Equipment Equivalent Forced Outage Rate EEFOR Probability of forced WTG equipment downtime when needed for load FTH EFDTH EEFOR CTH FTH RUTH x 100 Equipment Equivalent Unplanned Outage Rate EEUOR Probability of forced or maintenance WTG equipment downtime including high or low winds when needed for load FTH MTH EFDTH EMDTH CTH FTH MTH RUTH EEUOR x 100 Equipment Equivalent Scheduled Outage Rate EESOR Probability of maintenance or planned WTG equipment downtime when needed for load MTH PTH EMDTH EPDTH CTH MTH PTH RUTH EESOR x 100 NERC GADS W Data Reporting Instructions November 2014 39 Appendix E Performance Equations SECTION 2 Pooled Resource and Equipment Calculations Pooling refers to the method of grouping units together into cumulative indexes For instance a cumulative or aggregate index for a plant or fleet may be made by pooling the data from all related sub groups This section provides un weighted pooling of turbine hours which gives the same weight to each unit in the group regardless of size Sums gt in this section refer to the summation for each sub group 2 A Pooled Resource Performance Factors 2 A 1 Pooled Resource Equivalent Availability Factor PREAF of period that the plant was available Y PDTH FTH MTH PTH EFDTH EMDTH EPDTH RUTH PREAF x 100 3 PDTH 100 PREUF
7. NERC GADS W Data Reporting Instructions November 2014 65 Appendix H Outage Classification Guidelines General Considerations 1 Segregating maintenance outages MO from forced outages FO is the single largest area for misunderstanding and abuse MO s are defined as outages that can be deferred until the following week or if they occur on the weekend they can be deferred through the next not current weekend When equipment breaks it cannot be deferred and is a FO so the problem comes when equipment is close to breaking For example during an annual maintenance 3 teeth were found missing from the gearbox high speed gear The turbine was running fine before inspection If it is turned off for repair is it an MO or a FO This is where good judgment and engineering support helps What is the risk of failure if the equipment is allowed to run for another week If the risk is high then the event is an FO Weather downtime is another area for abuse The tendency is to attribute every event that occurs during Weather OMC to the storm There should be clear predefined linkage between the event and the storm For example a blade icing event occurs and some of the turbines shut down so the ice clearly has impacts Another example would be cable twist faults caused by a frozen wind direction sensor Equipment failure or Weather OMC can also be tricky For example a turbine shuts down on a wind speed error caused by ice on the ane
8. SOMCHrs oPTH oMTH SOMCDerate Hrs oEPDTH oEMDTH 3 SOHrs SODerateHr s SOMCHrs SOMCDerate Hrs PXRESOR x100 gt CTH_ SOHrs SOMCHrs 4 B Pooled Equipment Performance Factors without OMC hours 4 B 1 Pooled OMC Equipment Equivalent Availability Factor PXEEAF of period that the WTG equipment was available OutageHrs FTH MTH PTH DeratedHrs EFDTH EMDTH EPDTH OMCHrs oFTH oMTH oPTH DeratedOMCHrs oEFDTH oEMDTH oEPDTH ps PDTH OutageHrs DeratedHrs OMCHrs DeratedOMCHrs PXEEAF gt PDTH x100 100 PXEEUF NERC GADS W Data Reporting Instructions November 2014 55 Appendix E Performance Equations 4 B 2 Pooled OMC Equipment Equivalent Unavailability Factor PXEEUF of period that the WTG equipment was unavailable OutageHrs FTH MTH PTH DeratedHrs EFDTH EMDTH EPDTH OMCHrs oFTH oMTH o0PTH DeratedOMCHrs oEFDTH oEMDTH oEPDTH H OutageHrs DeratedHrs OMCHrs DeratedOMCHrs i x PXEEUF 00 3 PDTH 100 PXEEAF 4 B 3 Pooled OMC Equipment Equivalent Planned Outage Factor PXEEPOF of period that the WTG equipment was in planned downtime Y PTH EPDTH oPTH oEPDTH x AA x100 PXEEPOF 4 B 4 Pooled OMC Equipment Equivalent Maintenance Outage Factor PXEEMOF of period that the WTG equipment was in maintenance downtime 3 MTH EM
9. Total number of turbine hours in a period being reported that the sub group is in the retired state Derated Turbine Hours Equivalent Forced Derated Turbine Hours EFDTH Column 31 Total number of equivalent forced hours during one period month Equivalent Maintenance Derated Turbine Hours EMDTH Column 32 Total number of equivalent maintenance hours during on period month Equivalent Planned Derated Turbine Hours EPDTH Column 33 Total number of equivalent planned hours during one period month OMC Equivalent Forced Derated Turbine Hours oEFDTH Column 34 Total number of OMC equivalent forced hours during one period month OMC Equivalent Maintenance Derated Turbine Hours oEMDTH Column 35 Total number of OMC equivalent maintenance hours during one period month OMC Equivalent Planned Derated Turbine Hours oEPDTH Column 36 Total number of OMC equivalent planned hours during one period month Equivalent Reserve Shutdown Derated Turbine Hours ERSDTH Column 37 Optional Total number of equivalent hours during one period month See definitions for a clear definition NERC GADS W Data Reporting Instructions November 2014 13 Chapter 3 Performance Reporting Delayed Turbine Hours Forced Delay Turbine Hours FXDTH Column 38 Optional Total number of delay hours during one period month See definitions for a clear definition Maintenance Delay Turbine Hours MXDTH Column 39 Optional Total n
10. 2 A 2 Pooled Resource Equivalent Unavailability Factor PREUF of period that the plant was unavailable Y FTH MTH PTH EFDTH EMDTH EPDTH RUTH PREUF x 100 3 PDTH 100 PREAF 2 A 3 Pooled Resource Equivalent Planned Outage Factor PREPOF of period that the plant was in planned downtime 3 PTH EPDTH x 100 gt PDTH 2 A 4 Pooled Resource Equivalent Maintenance Outage Factor PREMOF of period that the plant was in maintenance downtime PREPOF MTH EMDTH 2 3 PDTH PREMOF x100 NERC GADS W Data Reporting Instructions November 2014 40 2 A 5 2 A 6 2 A7 2 A 8 2 A 9 2 A 10 Appendix E Performance Equations Pooled Resource Equivalent Forced Outage Factor PREFOF of period that the plant was forced off line Including low and high winds 3 FTH EFDTH RUTH PREFOF 3 PDTH x100 Pooled Resource Equivalent Unplanned Outage Factor PREUOF of period that the plant was unavailable due to forced and maintenance downtime For generation resource planning 3 FTH MTH EFDTH EMDTH RUTH PREOUF gt x 100 3 PDTH Pooled Resource Equivalent Scheduled Outage Factor PRESOF of period that the plant was unavailable due to maintenance and planned downtime ER 3 MTH PTH EMDTH EPDTH e Y PDTH i Pooled Resource Generating Factor PRGF of period that the plant was online and in a generating state
11. Acciona AC Table 6 Wind Turbulence Turbulence Entry Intensity Low 1 lt 0 10 Mild 2 gt 0 10 lt 0 15 Moderate 3 gt 0 15 lt 0 20 Strong 4 gt 0 20 lt 0 25 Severe 5 gt 0 25 Per NREL Handbook Turbulence Intensity Wind turbulence is the rapid disturbances or irregularities in the wind speed direction and vertical component It is an important site characteristic because high turbulence levels may decrease power output and cause extreme loading on wind turbine components The most common indicator of turbulence for siting purposes is the standard deviation o of wind speed Normalizing this value with the mean wind speed gives the Turbulence Intensity TI This value allows for an overall assessment of a site s turbulence TI is a relative indicator of turbulence with low levels indicated by values less than or equal to 0 10 moderate levels to 0 25 and high levels greater than 0 25 Tl is defined as o V NERC GADS W Data Reporting Instructions November 2014 61 Appendix F Reference Tables o the standard deviation of wind speed V the mean wind speed Table 7 Wind Shear Turbulence Entry Intensity Smooth 1 0 30 Moderately Rough 2 gt 0 20 lt 0 30 Rough 3 gt 0 10 lt 0 20 Very Rough 4 gt 0 10 Shear exponent lower blade tip to hub height As a first approximation the wind shear exponent is often assigned a value of 0 143 known as the 1 7th power law to pre
12. Information NERC shall provide a proposed request for data or information or a proposed modification to a previously authorized request including the information specified in paragraph 1602 2 1 or 1602 2 2 as applicable to the Commission s Office of Electric Reliability at least twenty one 21 days prior to initially posting the request or modification for public comment Submission of the proposed request or modification to the Office of Electric Reliability is for the information of the Commission NERC is not required to receive any approval from the Commission prior to posting the proposed request or modification for public comment in accordance with paragraph 1602 2 or issuing the request or modification to reporting entities following approval by the Board of Trustees NERC shall post a proposed request for data or information or a proposed modification to a previously authorized request for data or information for a forty five 45 day public comment period A proposed request for data or information shall contain at a minimum the following information i a description of the data or information to be requested how the data or information will be used and how the availability of the data or information is necessary for NERC to meet its obligations under applicable laws and agreements ii a description of how the data or information will be collected and validated iii a description of the entities by functional class and j
13. emm emm mmm mmm mmm i l l l i l I ia Sub Group 2A Sub Group 28 Sub Group 2C a v v m 3 3 et er 3 aa S 5 Group 2 a a t e t 2 Substation z Sub Group 1A l m 2 Plant A e l 3 o i i i l O ae 9I l l Transformer l LE l Sub Group 18 Sub Group 3A l _ Plant Boundary wem e PlantBoundary J Off Taker Figure 2 Typical Wind Plant Layout In figure 2 the diagram represents a typical plant with the plant boundary at the revenue meter Groups usually represent different phases of development For example in Group 1 there are two sub groups where each sub group contains different turbine types installed the same year If a sub group is repowered the sub group is retired and a new sub group created under the same group GADS W recognizes that there are many potential layouts of wind plants so there are no strict rules for plant group and sub group layout other than a sub group can only contain turbines of a specific make model version and commissioning date Although Figure 2 shows the sub groups as being electrically isolated this need not be the case A feeder may have multiple turbine types The plant is responsible for allocating production and hourly distributions using feeder meters turbine meters SCADA systems manual logs or other means into the proper sub groups Plant Boundaries The following is taken from the GADS Data Reporting Instructions as a suggestion of plan
14. 1 Rer m H Gseeead Dateerieasdees 1 Chapter 2 Plants Groups and sub groupes eene nnne nennen nenne ne th nina sensn seti sa assa assa sinis ga assa sn nn na 2 Pl nt lee e 2 drift Em 3 ET e ie EPI 3 Group Record Layout CSV Format 5 Ide M 5 LOCALO e L ss 6 Wind Site Characteristics cccccccccccccscccscccccssssssccccsssseceesssuccesesucceusesuceeusauceusesuceusasuceessucecssssucecssasucecesausecseaceneass 6 SUD GROU o AAEE sacs Dnm 7 Sub Group Record Layout CSV Format 7 Scie 8 Typical DESIG tice cc cenis deu IPIE HIEMIS ME 9 IUsa AVIEIerrrce E Nn 9 Chapter 3 Performance Reporting ette to eege eebe 10 Performance Record Layout CSV Format 10 Teen REENEN 11 Available Turbine Hours Active 12 Unavailable Turbine Hours Acte 12 Outside Management Control OMC Active nsssnnnsseneasensnsseennssennssserersrrnnssernnssennnssennnsennnssernnssennnsseeensrennnne 12 Big E 13 T rbine Hours InactiVe iiie tasa ctt rr R SR ERR 13 D rat di Turbine TE 13 Delayed T rbine HO rs i ee eter Ee sedvaessaurs RR ERE REI ERE eaaa E ER RE GERNE RR Ee REESE KEEN WR edes 14 Chapter 4
15. 1048 Control Cabinet Filtration o Added 1049 Control Slip Rings Drive Train o Change 615 High Speed changed to Rotor Coupling Electrical o Change 662 Transformers changed to Individual Turbine Transformers o Added 1050 Current Transformers o Added 1051 Power Transformers o Added 1052 Converter Cooling o Added 1053 Power Supply External o Change 681 Add OMC Out of Management to the end o Change 675 Add OMC to the end o Change 678 Add OMC to the end o Change 676 Add OMC to the end o Delete 680 Catastrophic o Delete 677 Weather Ice o Added 1054 Bat Bird OMC o Added 1055 Noise Flicker OMC o Added 1056 3rd Party OMC o Added 1057 External Communication OMC NERC GADS W Data Reporting Instructions November 2014 84 O Appendix G Outside Management Control Added 1076 External Weather Turbulence Generator Exciter O O O Moved From 641 VRCC Vestas Rotor Current Control moved from Control System Added 1058 High Speed Coupling Added 1059 Power Slip Rings Hydraulic System O Added 1060 Hydraulic Slip Ring Pitch System o Change 624 Mechanical Electrical to Mechanical o Added 1061 Battery Backup o Added 1062 Pitch Controller o Added 1063 Pitch Motor o Added 1064 Pitch Gearbox Rotor o Change 602 Add Tip brake Spoilers to the end o Added 1065 Coatings Structures o Added 1066 La
16. 3 CTH PRGF x100 3 PDTH Pooled Resource Net Capacity Factor PRNCF of actual plant generation 3 NAG x 3 PDTH x TNMC PRNCF 100 Pooled Net Output Factor PNOF of actual plant loading when on line 3 NAG PNOF __ 3 CTH xTNMC x 100 NERC GADS W Data Reporting Instructions November 2014 41 Appendix E Performance Equations 2 A Pooled Resource Performance Rates 2 A 11 2 A 12 2 A 13 2 A 14 2 A 15 Pooled Resource Equivalent Planned Outage Rate PREPOR Probability of planned plant downtime when needed for load 3 PTH EPDTH 100 3 CTH PTH PREPOR Pooled Resource Equivalent Maintenance Outage Rate PREMOR Probability of maintenance plant downtime when needed for load 3 MTH EMDTH PREMOR amp IO gt CTH MTH Pooled Resource Equivalent Forced Outage Rate PREFOR Probability of forced plant downtime when needed for load 3 FTH EFDTH RUTH 100 CTH FTH RUTH I Pooled Resource Equivalent Unplanned Outage Rate PREUOR Probability of forced or maintenance plant downtime including high and low winds when needed for load FTH MTH EFDTH EMDTH RUTH 3 CTH FTH MTH RUTH PREUOR 2 x100 Pooled Resource Equivalent Scheduled Outage Rate PRESOR Probability of maintenance or planned plant downtime when needed for load MTH PTH EMDTH EPDTH 3 CTH MT
17. California BC Hidalgo HG San Luis Potosi SL Baja California Sur BS Jalisco JA Sinaloa Sl Campeche cP Mexico EM Sonora SO Chiapas CH Michoac n MH Tabasco TA Chihuahua CI Morelos MR Tamaulipas TM Coahuila CU Nayarit NA Tlaxcala TL Colima CL Nuevo Leon NL Veracruz VZ Distrito Federal DF Oaxaca OA Yucatan YC Durango DG Puebla PU Zacatecas ZT Guanajuato GJ Queretaro QA Table 3 Wind Regimes Wind Regime Entry Seashore 1 Plain 2 Plateau 3 Hills 4 Mountain 5 Ridge 6 Off Shore 7 Table 5 SCADA Manufacturers SCADA Manufacturer Entry Emerson ES Garrard Hassan GH General Electric Co GE Mita Teknik MTK Scadabase SCB Second Wind SC Vestas VES Siemens SIE Proprietary PRO Enercon EN Nordex NOR Fenway FEN Mitsubishi MHI Honeywell HON Gamesa GAM Other OT NERC GADS W Data Reporting Instructions November 2014 60 Appendix F Reference Tables Table 6 Turbine Manufacturers Turbine Manufacturer Entry Clipper CL DanWin DW Denertec S A C DT Earth Wind and Power LLC EWP Enercon Gmbh EC General Electric GE Green Energy Technologies GET Kennetech KE MHI MHI Micon MI Nordex NX Prime Wind Power International PW R E Power Systems Ag REP Siemens Corp SC Stock Equipment Co SE Urban Green Energy UGE Vestas VES Wind Energy Solutions WES Winwind WW Zond ZD Other OTHER Goldwind GW Gamesa GM
18. Derated Turbine Hours ERSDTH Optional ERSDTH are the equivalent reserve shutdown hours when turbine output is reduced for economic reasons Reduced output for economic reasons is a real issue with wind energy and can have a significant impact on income Different SCADA systems implement economic shutdowns using one of two methods 1 Complete shutdown of turbines to meet the RS requirement This is already accounted for in the RS hours 2 The second method reduces or limits the output of a plant Turbine output is not reduced to zero but is derated as a percent of total capacity These equivalent hours are usually equal to or greater than RS hours This optional metric is not used in any equation listed in this document but when added to RS gives the plant a better understanding of the impact due to economic shutdowns Delays Due to the locations and environments wind turbines reside in repairs and maintenance events are often delayed These delays can add significant time to these events and tracking them helps NERC understand their impact The delay hours are not used in any of the listed equations Individual delay types are not tracked at this time but can take many forms Environment Ice on towers blades and nacelles High winds snow and flooding Access The inability to get to the turbines and or the site people equipment Equipment Availability and or permitting ez 4 moe Labor Limited availability of la
19. FTH is a subset of FTH Be sure the FTH are included in the FTH Maintenance OMC Turbine Hours MTH MTH is a subset of MTH Be sure the MTH are included in the MTH Planned OMC Turbine Hours PTH PTH is a subset of PTH Be sure the PTH are included in the PTH Equivalent Forced Derated OMC Turbine Hours EFDTH SEFDTH is a subset of EFDTH Be sure the EFDTH are included in the EFDTH Equivalent Maintenance Derated OMC Turbine Hours EMDTH EMDTH is a subset of EMDTH Be sure the SEMDTH are included in the EMDTH Equivalent Planned Derated OMC Turbine Hours EPDTH SEPDTH is a subset of EPDTH Be sure the EPDTH are included in the EPDTH Generation Generation at the turbine GAG gt Net Actual Generation NAG GAG is the generation measured at the turbine NAG is GAG minus line losses transformer losses and auxiliary load losses Capacity Gross installed capacity GIC gt Net Maximum Capacity NMC GIC is the Wind Turbine Generator WTG rated capacity times the number of turbines NMC is GIC minus line losses transformer losses and auxiliary load losses ID Missing An error will be generated if the Plant Group or sub group ID is missing ID Not Found The Plant Group or sub group ID has not been registered with the data base Performance ID Not Found The performance record is missing a Plant Group sub group year or period Bad Period Year This error may occur when impo
20. Probability of maintenance or planned plant downtime when needed for load SOHrs PTH MTH SODerateHrs EPDTH EMDTH SOMCHrs oPTH oMTH SOMCDerateHrs oEPDTH oEMDTH SOHrs SODerateHrs SOMCHrs SOMCDerateHrs 100 CTH SOHrs SOMCHrs XRESOR 3 B Equipment Performance Factors without OMC hours These are performance rates and factors that highlight the effect of the equipment and reduce the effect of the resource availability plant view In order to do that Resource Unavailable Turbine Hours RUTH are considered available non generating hours rather than forced outage hours This gives the maximum number of hours the equipment could have operated normally The equations also remove OMC events from the calculations This leaves a clean plant view NERC GADS W Data Reporting Instructions November 2014 48 Appendix E Performance Equations 3 B 1 OMC Equipment Equivalent Availability Factor XEEAF of period that the WTG equipment was available OutageHrs FTH MTH PTH DeratedHrs EFDTH EMDTH EPDTH OMCHrs oFTH 0MTH oPTH DeratedOMCHrs oEFDTH oEMDTH oEPDTH PDTH OutageHrs DeratedHrs OMCHrs DeratedOM CHrs XEEAF x100 PDTH 100 XEEUF 3 B 2 OMC Equipment Equivalent Unavailability Factor XEEUF 26 of period that the WTG equipment was unavailable OutageHrs FTH MTH PTH DeratedHrs EFDTH EMDTH EPDTH OMCHr
21. be rejected Reporting is done on a monthly basis submitted no later than 45 days after the end of the quarter At the time of the writing of this document reporting is voluntary 1 Calendar Turbine Hours CalTH The total number of turbine hours in a month is equal to the number of turbines times the number of hours in a month Example January has 31 days or 744 hours If the plant has 100 turbines than there would be 74 400 turbine hours for January CalTH Hours in Month X Number of Turbines 2 Turbine State Turbines are either in an Active state PDTH or an Inactive state ITH The sum of the two equals the CalTH CalTH PDTH ITH 3 Inactive State The sum of all inactive states should equal ITH ITH Inactive Reserve IRTH Mothball MBTH Retired RTH 4 Active State The sum of all active states should equal PDTH CTH Contactor Turbine Hours RSTH Reserve Shutdown Turbine Hours FTH Forced Turbine Hours MTH Maintenance Turbine Hours PTH Planned Turbine Hours RUTH Resource Unavailable Turbine Hours PDTH CTH RSTH FTH MTH PTH RUTH 5 RUTH Hours RUTH is usually calculated by subtracting the known values from PDTH RUTH PDTH CTH RSTH FTH MTH PTH NERC GADS W Data Reporting Instructions November 2014 76 10 11 12 13 14 15 16 17 18 19 Appendix G Outside Management Control Forced OMC Turbine Hours FTH
22. data existing under the group Group Name Column 3 Enter the name given to the group that you are reporting NERC Utility Code Column 4 Enter the three character alpha numeric code NERC assigned to your utility Appendix B contains a guide for selecting utility codes NERC Unit Code Column 5 Enter the three character alpha numeric code your utility assigned for the unit that you are reporting This code distinguishes one plant from another in your utility Appendix B contains a guide for selecting unit codes ISO Resource I D Column 6 If applicable enter the unique identifier given to the group by the ISO s NERC GADS W Data Reporting Instructions November 2014 5 Chapter 2 Plants Groups and sub groups Capacity Column 7 Enter the total capacity for the entire group measured in megawatts MW For example one hundred 1 MW Type A turbines would have an installed capacity of 100 MW Auxiliary Capacity Column 8 Enter the combined capacities for all the auxiliary turbines spare turbines not normally connected and not part of Gross Installed Capacity GIC measured in megawatts MW Commissioning year Column 9 Enter the year YYYY that the first sub group came online and entered into active status Location Country Column 10 Using Table 1 in Appendix F enter the two letter country abbreviation where the group is located We recommend that all values reported to NERC match any values that also m
23. ee ai 79 What roll up method should be used for multiple technologies esssseeeseeeeeen nennen 79 Appendix L Performance Data 82 NERC GADS W Data Reporting Instructions November 2014 iii Preface Appendix M Major Changes from the Previous Version NERC GADS W Data Reporting Instructions November 2014 iv Preface The North American Electric Reliability Corporation NERC is a not for profit international regulatory authority whose mission is to ensure the reliability of the bulk power system BPS in North America NERC develops and enforces Reliability Standards annually assesses seasonal and long term reliability monitors the BPS through system awareness and educates trains and certifies industry personnel NERC s area of responsibility spans the continental United States Canada and the northern portion of Baja California Mexico NERC is the electric reliability organization ERO for North America subject to oversight by the Federal Energy Regulatory Commission FERC and governmental authorities in Canada NERC s jurisdiction includes users owners and operators of the BPS which serves more than 334 million people The North American BPS is divided into several assessment areas within the eight Regional Entity RE boundaries as shown in the map and corresponding table below FRCC Florida Reliability Coordinating Council MRO Midwest Reliability
24. events that are outside management control such as abnormal weather or off taker planned or unplanned downtime See Appendix H for further details OMC Forced Turbine Hours oFTH Column 18 Subset of FTH accounting for Forced Turbine Hours that are due to events deemed to be outside of management control NERC GADS W Data Reporting Instructions November 2014 12 Chapter 3 Performance Reporting OMC Maintenance Turbine Hours oMTH Column 19 Subset of MTH accounting for Maintenance Turbine Hours that are due to events deemed to be outside of management control OMC Planned Turbine Hours oPTH Column 20 Subset of PTH accounting for Planned Turbine Hours that are due to events deemed to be outside of management control Other Resource Unavailable Turbine Hours RUTH Column 21 The number of turbine hours that the turbines are available but not producing electricity for environmental conditions that are outside the operating specifications of the wind turbine i e low high wind low high ambient temperature and column wind shutdown Turbine Hours Inactive Inactive Reserve Turbine Hours RTH Column 22 Total number of turbine hours in a period being reported that the sub group is in the inactive reserve state Mothballed Turbine Hours MBTH Column 23 Total number of turbine hours in a period being reported that the sub group is in the mothballed state Retired Unit Turbine Hours RTH Column 24
25. only For example a wind turbine is derated 2596 for 5 days The equivalent hours 5 days x 24 hrs day x 25 30 hrs What roll up method should be used for multiple technologies Roll up calculations for metrics that have physical characteristics are straightforward Simply sum the metric and divide by the number of sites A metric with physical characteristics would be dollars kilowatts etc Hour type metrics have something happening during a period of time and its value or has been the point of contention Some have said an hour is an hour everywhere therefore the roll up should be the same as the physical characteristic metrics An example of this is comparing one hour of run time for a 2 000 MW nuclear plant to a 1 MW wind turbine Clearly 1 hour of EFOR at the nuclear plant has greater consequences then 1 hour of EFOR at the wind turbine Another way of looking at this is a 2 000 MW nuclear plant compared to a wind plant with 2 000 1MW wind turbines The pooling equations previously listed work reasonably well when rolling up hourly metrics with turbines of the same installed capacity but errors can be introduced when plant net capacity factors NCF vary widely Wind is different from conventional generation in several aspects such as large numbers of smaller units a variable fuel source and temperature constraints The impact to the wind turbine is no different than adjusting a conventional plant s capacity based upon inlet water tempe
26. planned downtime PTH EPDTH oPTH 0EPDTH PXREPOF H 3 PDTH x100 NERC GADS W Data Reporting Instructions November 2014 52 4 A 4 4 A 5 4 A 6 Appendix E Performance Equations Pooled OMC Resource Equivalent Maintenance Outage Factor PXREMOF of period that the plant was in maintenance downtime 3 MTH EMDTH oMTH oEMDTH PXREMOF Y PDTH x 100 Pooled OMC Resource Equivalent Forced Outage Factor PXREFOF of period that the plant was forced off line Including low and high winds FTH EFDTH oOFTH oEFDTH RUTH SS o PXREFOF 2 00 3 PDTH Pooled OMC Resource Equivalent Unplanned Outage Factor PXREUOF of period that the plant was unavailable due to forced and maintenance downtime For generation resource planning UOHrs FTH MTH UDerateOHrs EFDTH EMDTH PXREOUF UOMCHrs oFTH oMTH 4 A7 UOMCDerateHrs OEFDTH oEMDTH mt Resource Y UOHrs UDerateOHrs RUTH UOMCHrs UOMCDerateHrs mo Y PDTH X100 scheduled Outage Factor PXRESOF of period that the plant was unavailable due to maintenance and planned downtime SOHrs PTH MTH SODerateHrs EPDTH EMDTH SOMCHrs oPTH oMTH SOMCDerateHrs OEPDTH oEMDTH PXRESOF gt SOHrs SODerateHrs SOMCHrs SOMCDerateHrs y SPI x100 NERC GADS W Data Reporting Instructions November 2014 53 Appendix E Performance Equations 4 A Po
27. to consider how you lay your groups out The ISO Resource ID is used to link your group of plants with an ISO in the event your ISO requires mandatory GADS reporting NERC GADS W Data Reporting Instructions November 2014 4 Chapter 2 Plants Groups and sub groups Group Record Layout CSV Format ene eee Column Field Name Entry Type 1 Associated Plant ID Alpha Numeric 10 2 Turbine Group ID Alpha Numeric 10 3 Turbine Group Name Alpha Numeric 45 4 NERC Utility Code Alpha Numeric 3 5 NERC Unit Code Alpha Numeric 3 6 ISO Resource ID Alpha Numeric 30 7 Installed Capacity Numeric 8 2 decimals 8 Auxiliary Capacity Numeric 8 2 decimals 9 Commissioning year Alpha Numeric 4 10 Country Alpha Numeric 2 11 Nearest City Alpha Numeric 40 12 State Province Alpha Numeric 2 13 Location Longitude Numeric 4 4 decimals 14 Location Latitude Numeric 3 4 decimals 15 Elevation Numeric 8 2 decimals 16 Wind Regime topography Numeric 3 17 Annual Average Wind Speed AAWS Numeric 3 2 decimals 18 Left Blank Intentionally Alpha Numeric 10 19 SCADA Manufacturer Alpha Numeric 5 20 SCADA Model Alpha Numeric 10 Group ID Plant I D Column 1 Enter the Plant ID as previously defined Group I D Column 2 Enter a unique ID for the group that you are reporting This ID is referenced in all sub groups performance data and hours
28. was unavailable OutageHrs FTH MTH PTH DeratedHrs EFDTH EMDTH EPDTH OMCHrs oF TH oMTH oPTH DeratedOMCHrs oEFDTH oEMDTH oEPDTH XREUF QutageHrs DeratedHrs Ruth OMCHrs DeratedOMCHrs x100 PDTH 100 XREAF 3 A 3 OMC Resource Equivalent Planned Outage Factor XREPOF of period that the plant was in planned downtime XBEPOF PTH EPDTH oPTH oEPDTH Eas PDTH 3 A 4 OMC Resource Equivalent Maintenance Outage Factor XREMOF of period that the plant was in maintenance downtime SEENEN MTH EMDTH oMTH oEMDTH 160 PDTH 3 A 5 OMC Resource Equivalent Forced Outage Factor XREFOF of period that the plant was forced off line Including low and high wind FTH EFDTH oFTH oEFDTH RUTH a PDTH XREFOF 0 NERC GADS W Data Reporting Instructions November 2014 46 Appendix E Performance Equations 3 A 6 OMC Resource Equivalent Unplanned Outage Factor XREUOF of period that the plant was unavailable due to force and maintenance downtime For generation resource planning UOHrs FTH MTH UDerateOHrs EFDTH EMDTH UOMCHrs oFTH oMTH UOMCDerateHrs OEFDTH oEMDTH EEN UOHrs UDerateOHrs RUTH UOMCHrs UOMCDerateHrs zin PDTH 3 AJ OMC Resource Equivalent Scheduled Outage Factor XRESOF of period that the plant was unavailable due to maintenance and planned downtime
29. without further action by a Submitting Entity A Submitting Entity may designate any other data or information as Confidential Information pursuant to the provisions of Section 1500 and NERC or the Regional Entity shall treat that data or information in accordance with Section 1500 NERC or a Regional Entity may utilize additional protective procedures for handling particular requests for data or information as may be necessary under the circumstances 1606 Expedited Procedures for Requesting Time Sensitive Data or Information In the event NERC or a Regional Entity must obtain data or information by a date or within a time period that does not permit adherence to the time periods specified in Section 1602 the procedures specified in Section 1606 may be used to obtain the data or information Without limiting the circumstances in which the procedures in Section 1606 may be used such circumstances include situations in which it is necessary to obtain the data or information in order to evaluate a threat to the reliability or security of the Bulk Power System or to comply with a directive in an order issued by the Commission or by another Applicable Governmental Authority within a shorter time period than possible under Section 1602 The procedures specified in Section 1606 may only be used if authorized by the NERC Board of Trustees prior to activation of such procedures Prior to posting a proposed request for data or information or a modi
30. 5 NERC Unit Code Alpha Numeric 3 6 Sub Group Number Numeric 3 NERC GADS W Data Reporting Instructions November 2014 7 Chapter 2 Plants Groups and sub groups 7 Sub Group Name Alpha Numeric 45 8 Commissioning Year Numeric 4 9 Nameplate Capacity Numeric 3 3 decimals 10 Total Number of Turbines Numeric 7 11 Turbine Manufacturer Alpha Numeric 5 12 Model Alpha Numeric 20 13 Version Alpha Numeric 20 14 Rotor Height meters Numeric 7 2 decimals 15 Rotor Diameter meters Numeric 7 2 decimals 16 Cut in Wind Speed meters second Optional Numeric 7 2 decimals 17 Low Cut out Wind Speed meters second Optional Numeric 7 2 decimals 18 High Cut out Wind Speed meters second Optional Numeric 7 2 decimals 19 Turbulence Intensity Optional Numeric 3 20 Average Wind Speed Optional Numeric 3 2 decimal 21 Wind Shear Optional Numeric 3 22 Reference Anemometer Height meters Optional Numeric 3 Sub Group ID Plant I D Column 1 Enter the Plant ID as previously defined Group I D Column 2 Enter the Group ID as previously defined Sub Group I D Column 3 Enter a unique ID for the sub group that you are reporting This ID is referenced in all performance and component data existing under the sub group NERC Utility Code Column 4 Enter the three character alpha numeric code NERC assigne
31. 6 9693 If the respondent believes that any of the responses to this survey should remain confidential contact the project manager directly for further instructions Official correspondence may be mailed to NERC ATTN RAPA Department C O Howard Gugel 3353 Peachtree Road Suite 600 North Tower Atlanta GA 08540 Authority Under Section 215 of the Federal Power Act 16 U S C 8240 Congress entrusted FERC with the duties of approving and enforcing rules to ensure the reliability of the Nation s Bulk Power System and with the duties of certifying an Electric Reliability Organization ERO that would be charged with developing and enforcing mandatory Reliability Standards subject to FERC approval NERC was certified as the ERO on July 20 2006 NERC s authority for issuing this survey is derived from Section 215 of the Federal Power Act and from the following sources NERC is requesting this information in accordance with its authority provided in 18 C F R 39 2 d which provides Each user owner or operator of the Bulk Power System within the United States other than Alaska and Hawaii shall provide the Commission the Electric Reliability Organization and the applicable Regional Entity such information as is necessary to implement section 215 of the Federal Power Act as determined by the Commission and set out in the Rules of the Electric Reliability Organization and each applicable Regional Entity The Electric R
32. DTH oMTH oEMDTH Ka 3 PDTH SC PXEEMOF 4 B 5 Pooled OMC Equipment Equivalent Forced Outage Factor PXEEFOF of period that the WTG equipment was forced off line Including low and high winds gt ETH EFDTH oF TH 0EFDTH SD x100 PXEEFOF NERC GADS W Data Reporting Instructions November 2014 56 Appendix E Performance Equations 4 B 6 Pooled OMC Equipment Equivalent Unplanned Outage Factor PXEEUOF of period that the WTG equipment was unavailable due to forced and maintenance downtime For generation resource planning UOHrs FTH MTH UDerateOHrs EFDTH EMDTH UOMCHrs oFTH oMTH UOMCDerateHrs oEFDTH oEMDTH Y uonrs UDerateOHrs UOMCHrs UOMCDerateHrs PXEEOUF PDTH x100 4 B 7 Pooled OMC Equipment Equivalent Scheduled Outage Factor PXEESOF of period that the WTG equipment was unavailable due to maintenance and planned downtime SOHrs PTH MTH SODerateHrs EPDTH EMDTH SOMCHrs oPTH oMTH SOMCDerateHrs OEPDTH oEMDTH Y SOHrs SODerateHrs SOMCHrs SOMCDerateHrs 3 PDTH PXEESOF x 100 4 B Pooled Equipment Performance Rates without OMC hours 4 B 8 Pooled OMC Equipment Equivalent Planned Outage Rate PXEEPOR Probability of planned WTG equipment downtime when needed for load Y PTH EPDTH oPTH oEPDTH PXEEPOR 3 CTH PTH oPTH RUTH x100 4 B 9 Pooled OMC Equipm
33. Data Reporting Instructions November 2014 29 Appendix D Terms and Definitions Note Equivalent hours are only used in the numerator of equations as the hours are already counted as contactor hours in the denominator Turbine output is reduced but the unit is still on line Equivalent Forced Derated Turbine Hours EFDTH EFDTH are the equivalent forced turbine hours when turbine output is reduced for forced issues Equivalent Maintenance Derated Turbine Hours EMDTH EMDTH are the equivalent maintenance turbine hours when the turbine output is reduced for maintenance turbine hours EMDTH must meet the requirements for a maintenance outage The turbine must be capable of running until the following week unless the outage occurs on the weekend the turbine must be capable of running through the following week Equivalent Planned Derated Turbine Hours EPDTH EPDTH are the equivalent planned turbine hours when turbine output is reduced for a planned issue OMC Equivalent Forced Derated Turbine Hours oEFDTH oEFDTH are OMC equivalent forced turbine hours when turbine output is reduced for OMC forced issues OMC Equivalent Maintenance Derated Turbine Hours OEMDTH oEMDTH are OMC equivalent maintenance hours when turbine output is reduced for OMC maintenance issues OMC Equivalent Planned Derated Turbine Hours oEPDTH oEPDTH are OMC equivalent planned hours when turbine output is reduced for OMC planned issues Equivalent Reserve Shutdown
34. EMDTH oEPDTH XEESOR CTH MTH PTH oMTH oPTH RUTH x 100 NERC GADS W Data Reporting Instructions November 2014 51 Appendix E Performance Equations SECTION 4 Pooled Resource and Equipment Calculations without OMC Hours This section provides un weighted pooling of turbine hours which gives the same weight to each unit in the group regardless of size Sums gt in this section refer to the summation for each sub group Only turbines of equal capacities should use this type of pooling 4 A Pooled Resource Performance Factors without OMC hours 4 A 1 Pooled OMC Resource Equivalent Availability Factor PXREAF of period that the plant was available OutageHrs FTH MTH PTH DeratedHrs EFDTH EMDTH EPDTH OMCHrs 0FTH oMTH oPTH DeratedOMCHrs oEFDTH oEMDTH oEPDTH PDTH OutageHrs DeratedHrs Ruth OMCHrs DeratedOMCHrs 10 x PXREAF H 3 PDTH 0 100 PXREUF 4 A 2 Pooled OMC Resource Equivalent Unavailability Factor PXREUF of period that the plant was unavailable OutageHrs FTH MTH PTH DeratedHrs EFDTH EMDTH EPDTH OMCHrs oFTH oMTH oPTH DeratedOMCHrs oEFDTH 0EMDTH oEPDTH Y QutageHrs t DeratedHrs Ruth OMCHrs DeratedOMCHrs i EEN x PXREUF 00 3 PDTH 100 PXREAF 4 A 3 Pooled OMC Resource Equivalent Planned Outage Factor PXREPOF of period that the plant was in
35. ESOF x 100 NERC GADS W Data Reporting Instructions November 2014 35 1 A 8 1 A 9 1 A 10 Appendix E Performance Equations Resource Generating Factor RGF of period that the plant was online and in a generating state CTH RGF x 100 PDTH Resource Net Capacity Factor RNCF of actual plant generation NAG RNCF x10 PDTH x TNMC 0 Net Output Factor NOF of actual plant loading when on line NOF M x100 CTH x TNMC 1 A Resource Performance Rates T A 11 1 A 12 1 A 13 Resource Equivalent Planned Outage Rate REPOR Probability of planned plant downtime when needed for load PTH EPDTH REPOR CTH PTH x 100 Resource Equivalent Maintenance Outage Rate REMOR Probability of maintenance plant downtime when needed for load MTH EMDTH REMOR CTH MTH x 100 Resource Equivalent Forced Outage Rate REFOR Probability of forced plant downtime when needed for load FTH EFDTH RUTH REFOR CTH FTH RUTH x 100 NERC GADS W Data Reporting Instructions November 2014 36 1 A 14 1 A 15 Appendix E Performance Equations Resource Equivalent Unplanned Outage Rate REUOR Probability of forced or maintenance plant downtime including high and low winds when needed for load FTH MTH EFDTH EMDTH RUTH CTH FTH MTH RUTH REUOR x 100 Resource Equivalent Schedul
36. Enter the sum of all turbine hours for turbines that are off line for economic reasons but available for service although the sub group is available to the system Do not include RSTH in the same equations with CTH because this would double count turbine hours Unavailable Turbine Hours Active Forced Turbine Hours FTH Column 15 Forced Turbine Hours is the sum of all turbine hours that the sub group is off line due to forced events FTH are all forced events where the Wind Turbine Generator WTG must be removed from service for repairs before the next Sunday at 23 59 just before Sunday becomes Monday Note FTH includes OMC Forced Turbine Hours oFTH Maintenance Turbine Hours MTH Column 16 Maintenance Turbine Hours is the sum of all turbine hours that the sub group is off line due to a maintenance event The turbine must be capable of running until the following week unless the outage occurs on the weekend the turbine must be capable of running through the following week Note MTH includes OMC Maintenance Turbine Hours oMTH Planned Turbine Hours PTH Column 17 Planned Turbine Hours is the sum of all turbine hours that the sub group is off line due to a planned event A PTH event is scheduled well in advance and is of a predetermined duration and can occur several times a year Note PTH includes OMC Planned Turbine Hours oPTH Outside Management Control OMC Active OMC hours are hours that the subgroup is off line due to
37. H PTH x100 PRESOR ZA NERC GADS W Data Reporting Instructions November 2014 42 Appendix E Performance Equations 2 B Pooled Equipment Performance Factors 2 B 1 Pooled Equipment Equivalent Availability Factor PEEAF of period that the WTG equipment was available Y PDTH FTH MTH PTH EFDTH EMDTH EPDTH PEEAF 3 PDTH z 100 PEEUF 2 B 2 Pooled Equipment Equivalent Unavailability Factor PEEUF 26 of period that the WTG equipment was unavailable FTH MTH PTH EFDTH EMDTH EPDTH PEEUF 2 3 PDTH x 100 100 PEEAF 2 B 3 Pooled Equipment Equivalent Planned Outage Factor PEEPOF of period that the WTG equipment was in planned downtime 3 PTH EPDTH PEEPOF x 100 3 PDTH 2 B 4 Pooled Equipment Equivalent Maintenance Outage Factor PEEMOF of period that the WTG equipment was in maintenance downtime 3 MTH EMDTH PEEMOF S amp S n x 100 3 PDTH 2 B 5 Pooled Equipment Equivalent Forced Outage Factor PEEFOF of period that the WTG equipment was forced off line Including low and high winds 3 ETH EFDTH PEEFOF PDTH x100 NERC GADS W Data Reporting Instructions November 2014 43 x100 2 B 6 2 B 7 2 B 8 2 B 9 Appendix E Performance Equations Pooled Equipment Equivalent Unplanned Outage Factor PEEUOF of period that the WTG equipment was unavailable due to forced and maintenance dow
38. I etc federal governmental organizations and state and local governmental organizations To avoid the potential misuse of individual equipment data the component outage and performance data are restricted and available only as specified in these guidelines Data Release Guidelines Unless expressly permitted in the following sections data by power generator pool Region or specific unit will be provided only with the authorization of the appropriate power generator pool or Region Power generators are any owners or operators of electric generating units owned operated by investor owned independent power producer IPP municipals cooperative federal state and all other groups of electric providers Special reports or studies which describe or rank power generators pools or regions by performance or other attributes and in which specific units power generators pools or regions are identifiable either by inclusion or exclusion will be provided only with the authorization of the appropriate power generators pools or regions Obtaining these approvals is the responsibility of the requester S However NERC may be directed to provide such information pursuant to 18 C F R 8 375 303 a 2 v 2014 NERC GADS W Data Reporting Instructions November 2014 18 Appendix B Utility and Unit I dentification Utility I dentification Codes NERC assigns each utility participating in the wind turbine generation databas
39. MDTH 36 OMC Equivalent Planned Numeric 10 2 decimals Mandatory Derated Turbine Hours OEPDTH 37 Equivalent Reserve Shutdown Numeric 10 2 decimals Optional Derated Turbine Hours ERSDTH Optional 38 Forced Delay Numeric 10 2 decimals Optional Turbine Hours FDTH Optional 39 Maintenance Delay Numeric 10 2 decimals Optional Turbine Hours MDTH Optional 40 Planned Delay Turbine Hours PDTH Optional Numeric 10 2 decimals Optional Plant I D Column 1 Enter the Plant ID as previously defined Group I D Column 2 Enter the Group ID as previously defined Sub Group I D Column 3 Enter the sub group ID as previously defined NERC Utility Code Column 4 Enter the three character alpha numeric code NERC assigned to your utility See Appendix B NERC Unit Code Column 5 Enter the three character alpha numeric code your utility assigned for the plant that you are reporting This code distinguishes one plant from another in your utility See Appendix B Report Period Column 6 Enter the two digit month MM in which the performance data is being entered See Appendix F Table 8 Report Year Column 7 Enter the four digit year YYYY in which the performance data is being entered Sub Group Status Column 8 From the table below select the status of the entire sub group during the year period for which the data is entered See Appendix F Table 9 Capacity and Generation Gross Actual Gene
40. NERC Howard Gugel NORTH AMERICAN ELEcTRIc Director Performance Analysis RELIABILITY CORPORATION DRAFT Letter for 21 day notice to FERC from January 21 2015 to February 11 s and for 45 day public posting and comment to Industry Stakeholders from February 17 2015 to amp p 26 To Generator Owners Generator Operators Industry Stakeholders RE Request for Public Comment on the Addition of Wind Turbine Generation to the Generating Availability Data Systems GADS Section 1600 Data Request To All Interested Parties The North American Electric Reliability Corporation NERC requests public comment by 8 00 p m EST April 3 2015 on its proposal to add Generator Operators that operate wind turbine facilities of 75 MW or greater to the existing Generating Availability Data System herein referred to as GADS W Comments must be submitted in an electronic document to gads nerc net In accordance with Section 1600 of the North American Electric Reliability Corporation NERC Rules of Procedure NERC may request data or information Data Request that is necessary to meet its obligations under Section 215 of the Federal Power Act as authorized by Section 39 2 d of the Federal Energy Regulatory Commission s FERC or Commission regulations NERC s mission is to ensure the reliability of the North American bulk power system With that responsibility NERC and its stakeholders require high quality accurate data pro
41. Off Taker OMC a required communication system may need work and the plant is notified and shuts down at the appropriate time Code as External External Communication OMC MO 3 Economic Potentially a labor strike could meet the MO rules Planned Events PO Planned events are events that are scheduled well in advance and are usually specifically listed in the plant budget 1 Substation HV Maintenance HV maintenance schedules are usually determined well in advance by NERC regulations This is coded as Balance of Plant Substation PO 2 Turbine Preventative Maintenance Most turbines have a biannual maintenance schedule This happens every year and is planned well in advance This is coded as Wind Turbine Preventative Maintenance PO 3 Retrofit Some retrofit projects require long term planning An example could be replacing all the gearboxes at a plant That would be coded as Gearbox Gearbox PO Planned Events OMC 1 Off Taker Off Taker planned event like a system upgrade This is coded as External Off Taker OMC PO NERC GADS W Data Reporting Instructions November 2014 70 Appendix G Outside Management Control Equivalent Hours Equivalent hours come from events where the turbine output is limited The causes of equivalent hours are the same as other outages except that the hours are accounted for only in the numerator of equations Since the turbine is running the contactor or on line hours are alread
42. Organization NPCC Northeast Power Coordinating Council RF Reliability First SERC SERC Reliability Corporation SPP Southwest Power Pool Regional Entity TRE Texas Reliability Entity WECC Western Electricity Coordinating Council NERC GADS W Data Reporting Instructions November 2014 v Introduction These GADS Wind Turbine Generation GADS W Data Reporting Instructions were developed to assist plant personnel in reporting information to the North American Electric Reliability Corporation s NERC GADS W database The instructions detail the procedures schedule and format to follow when reporting data to the wind turbine database Who Must Report GADS W is mandatory for all Generator Operators on the NERC registered entities that operate wind turbine facilities of 75 MW or greater Participating organizations must be prepared to commit the necessary effort to provide timely accurate and complete data The reporting instructions detail the data elements collected by GADS W and have been identified by the industry as being vital to the understanding and interpretation of wind turbine performance FRCC SERC Florida Reliability Coordinating Council SERC Reliability Corporation MRO SPP Midwest Reliability Organization Southwest Power Pool NPCC TRE Northeast Power Coordinating Council Texas Regional Entity RF WECC Reliability First Western Electricity Coordinatin
43. SOHrs PTH MTH SODerateHrs EPDTH EMDTH SOMCHrs oPTH oMTH SOMCDerateHrs oOEPDTH oEMDTH s OHrs SODerateHrs SOMCHrs SOM CDerateHrs PDTH XRESOF x100 3 A Resource Performance Rates including resources without OMC hours 3 A 8 OMC Resource Equivalent Planned Outage Rate XREPOR Probability of planned plant downtime when needed for load SPORE PTH EPDTH oPTH oEPDTH ifa CTH PTH oPTH 3 A 9 OMC Resource Equivalent Maintenance Outage Rate XREMOR Probability of maintenance plant downtime when needed for load MTH EMDTH oMTH o0EMDTH x100 CTH MTH oMTH J XREMOR NERC GADS W Data Reporting Instructions November 2014 47 Appendix E Performance Equations 3 A 10 OMC Resource Equivalent Forced Outage Rate XREFOR Probability of forced plant downtime when needed for load FTH EFDTH oFTH oEFDTH RUTH XREFOR K CTH FTH oFTH RUTH x 100 3 A 11 OMC Resource Equivalent Unplanned Outage Rate XREUOR Probability of forced or maintenance plant downtime including high or low winds when needed for load UOHrs FTH MTH UDerateOHrs EFDTH EMDTH UOMCHrs oFTH oMTH UOMCDerateHrs OEFDTH oEMDTH UOHrs UDerateOHrs RUTH UOMCHrs UOMCDerateHrs XREUOR CTH UOHrs RUTH UOMCHrs x 100 3 A 12 OMC Resource Equivalent Scheduled Outage Rate XRESOR
44. TG equipment downtime including high or low winds when needed for load mn Y FTH MTH EFDTH EMDTH I e LO 3 CTH FTH MTH RUTH 2 B 14 Pooled Equipment Equivalent Scheduled Outage Rate PEESOR Probability of maintenance or planned WTG equipment downtime when needed for load 3 MTH PTH EMDTH EPDTH PEESOR 3 CTH MTH PTH RUTH x100 SECTION 3 Resource and Equipment Calculations without OMC Hours 3 A Resource Performance Factors including resources without OMC hours These are performance rates and factors that highlight the effect of the resource and are primarily used by planners system view In order to do that Resource Unavailable Turbine Hours RUTH are treated as forced outage hours This defines the ability of the technology to deliver power to the bulk power system These equations also remove the effect of OMC on system performance 3 A 1 OMC Resource Equivalent Availability Factor XREAF 26 of period that the plant was available OutageHrs FTH MTH PTH DeratedHrs EFDTH EMDTH EPDTH OMCHrs oFTH oMTH oPTH DeratedOMCHrs oEFDTH oEMDTH oEPDTH PDTH OutageHrs DeratedHrs Ruth OMCHrs DeratedOMCHrs PDTH XREAF x 100 100 XREUF NERC GADS W Data Reporting Instructions November 2014 45 Appendix E Performance Equations 3 A 2 OMC Resource Equivalent Unavailability Factor XREUF of period that the plant
45. TH SOMCDerateHrs oOEPDTH oEMDTH SOHrs SODerateH rs 2 s OMCHrs SOM CDerateHrs XEESOF K x100 PDTH NERC GADS W Data Reporting Instructions November 2014 50 Appendix E Performance Equations 3 B Equipment Performance Rates without OMC hours 3 B 8 3 B 9 3 B 10 3 B 11 3 B 12 OMC Equipment Equivalent Planned Outage Rate XEEPOR Probability of planned WTG equipment downtime when needed for load PTH EPDTH oPTH oEPDTH XEEPOR CTH PTH oPTH RUTH x 100 OMC Equipment Equivalent Maintenance Outage Rate XEEMOR Probability of maintenance WTG equipment downtime when needed for load MTH EMDTH oMTH A oEMDTH XEEMOR CTH MTH oMTH RUTH x 100 OMC Equipment Equivalent Forced Outage Rate XEEFOR Probability of forced WTG equipment downtime when needed for load FTH EFDTH oFTH oEFDTH XEEFOR CTH FTH oFTH RUTH x 100 OMC Equipment Equivalent Unplanned Outage Rate XEEUOR Probability of forced or maintenance WTG equipment downtime including high or low winds when needed for load FTH MTH EFDTH EMDTH oFTH 0MTH oEFDTH o0EMDTH XEEUOR i x100 CTH FTH MTH oFTH oMTH RUTH OMC Equipment Equivalent Scheduled Outage Rate XEESOR Probability of maintenance or planned WTG equipment downtime when needed for load MTH PTH EMDTH EPDTH oMTH 0PTH o
46. aged components that need to be de energized to complete the repairs safely BOP failures usually impact many turbines and their repairs are usually not delayed Under this condition the parallel circuits are part of the FO If the primary repair will be delayed for a week or 2 the parallel circuit outage could be considered a MO No Wind Turbine repairs often occur during no or low wind periods Although there are no production losses the turbine s FO hours still accumulate For example if turbine fails a hydraulic motor but there is no wind anywhere in the area it is still a FO Repeating Faults Occasionally turbines fault multiple times from the same problem over a short period of time For example imagine that crews are dispatched to repair a turbine but the turbine is running when the crew arrives One might think to call this MO because the turbine is running but due to the repetitive nature of the fault it is FO Here s another example A turbine has been repeatedly faulting on pitch asymmetry The previous night it faulted 6 times The turbine is later shut down to determine root cause of the problem and repair it Therefore the turbine cannot be restarted until repaired so it is FO Outside Contractors Sometimes non related contractors have access to the plant to service non turbine equipment Oil equipment gas lines telephone When digging or work occurs around high voltage HV or communication lines it is the responsi
47. agencies such as the EIA EPA etc SCADA Model Column 20 Enter the model name of the SCADA system Sub Groups A sub group is a collection of wind turbine machines with the same manufacturer designs model number and phase of construction Each sub group will have a unique identifier and be associated with its parent group The sub group should submit component outage and performance data For example suppose that manufacturers A B and C supply your utility with turbines Your group contains 27 A turbines as well as 100 B turbines constructed in 2000 In 2013 the 100 B turbines were replaced with 10 C turbines The A B and C turbines would be three separate sub groups under the same group When all the B turbines are replaced their sub group would be put into an inactive status Wind Turbine Sub Group Sub groups report the following design data Plant Group and Sub Group ID NERC Utility and Unit Codes Sub Group Number and Name Commissioning Year Nameplate Capacity Total number of Turbines Turbine Manufacturer Make Model Rotor Height and Diameter Cut in and Cut out Wind Speed Turbulence Intensity Wind Speed Range Wind Shear Reference Anemometer Height Sub Group Record Layout CSV Format Column Field Name Entry Type 1 Plant ID Alpha Numeric 10 2 Group ID Alpha Numeric 10 3 Sub Group ID Alpha Numeric 10 4 NERC Utility Code Alpha Numeric 3
48. aker limits the plant to 830MW but the plant capacity is IOOMW Therefore 20 of the hours are OMC SEFDTH 4 Equipment Maintenance Planned work is being done on one of the 3 parallel transformers in the substation During this time output from the plant is limited to 2 3 of the plant s capacity In this example 1 3 of the turbine hours would be counted as EPDTH Delays Delays are optional fields that help NERC staff understand extended outages and help management run the plant more efficiently Delays can take many forms such as environmental site access equipment labor and materials The delay does not change the original outage type but helps NERC Staff understand the issues that are driving cost Here are several examples 1 A turbine is down for a FO gearbox event The crane gearbox and technicians are available to complete this task tomorrow During the night a storm moves in and covers the area in 3 feet of snow delaying work for 3 weeks The original outage does not change and is coded as Gearbox Gearbox FO 3 weeks of the FO hours are explained as Force Delay Turbine Hours FDTH The hours for the original FO begin when the gearbox failed and end when the turbine is returned to service 2 Cranes cannot be on the roads during the fall freeze and spring thaw in some locations Equipment failures during this time can be extended due to crane availability The primary event still starts when the equipment failed and ends whe
49. bility of the plant to be aware of and coordinate these events Consider this example a local phone company is installing a new fiber optic line that crosses the plant and the contractor hits an underground HV cable The site trips off and the cable requires repair Were the crossings marked and flagged Was the digging monitored The event is FO even if all the proper safe guards are in place human error Security Damage caused by theft or vandalism is FO It is the plant s responsibility to secure its equipment For example turbines going off line from cable theft is under plant management control Human Error Human error falls under plant management control For example if a technician leaves an oily rag in a nacelle that spontaneously catches fire and burns it up the event is FO Weather Weather events are often difficult to categorize When labelling an outage as FO determine what equipment caused the failure For example if a turbine has an anemometer with a heater to prevent icing but it ices up anyway then the heater failed and the outage would be NERC GADS W Data Reporting Instructions November 2014 67 Appendix G Outside Management Control FO Control System If lightning were to strike a blade with lightning protection and cause damage then the protection system failed and the outage would be FO Rotor 11 Safety Shutdown Safety shutdowns usually occur when neighboring equipment is in danger of harm As a
50. bor or inadequate labor NERC GADS W Data Reporting Instructions November 2014 30 5 Appendix D Terms and Definitions Material High failure rates deplete inventory long lead times for repairs or parts availability Force Delay Turbine Hours FDXTH Optional FDTH are the delay hours that extend repairs beyond their expected repair period Maintenance Delay Turbine hour MDXTH Optional MDTH are the delay hours that extend repairs beyond their expected maintenance period Planned Delay Turbine Hours PDXTH Optional PDTH are the delay hours that extend repairs beyond their expected planned period Priority of Outage Reporting In some instances there may be more than one event occurring at the same time In such cases the turbine remains in its current state until it is cleared and then moves to the next applicable state 1 2 3 4 5 6 Contact Turbine Hours Forced Turbine Hours Maintenance Turbine Hours Planned Turbine Hours Reserve Shutdown Turbine Hours Resource Unavailable Turbine Hours Relationships Between Types of Hours amp Capacity Turbine Specific amp Site Wide Outages All Types Reserve Shutdown Outages and Derations Installed Capacity 8 5 SZ e A ii WY Derated Wind Loss Generation lt Rated Capacity Less than Rated Capacity Wind Time Figure D 2 NERC GADS W Data Reporting Instructions November 2014 31 Installed Capacity Appendix D Term
51. d when labor and cranes are available Code as Rotor Blades MO b The main bearing temperature has been rising and inspection indicates that the bearing should be replaced Experience has shown that the turbine will run for several months in this condition but there is a chance that the bearing could spin on the main shaft significantly increasing the cost of repair The turbine is shutdown under MO and repairs NERC GADS W Data Reporting Instructions November 2014 69 Appendix G Outside Management Control completed when a bearing and crane are available Code as Drive Train Main Bearings MO c Agearbox is making noise During inspection metal flakes are found and spalding is occurring on the intermediate bearings Engineering indicates that the gearbox could run for several weeks in this condition but the risk of a catastrophic failure will become significant loss of core The turbine is shutdown under MO and repairs are completed when a gearbox and crane are available Code as Gear Box Gear Box MO Maintenance OMC Events Maintenance OMC Events are MO events that occur beyond the plant boundaries They must also qualify under the MO rules and are a subset of MO 1 Off Taker Off Taker events are the most likely OMC MO event to occur Some items on their system may need maintenance or repair and the plant is notified ahead of time of the outage Code as External Off Taker OMC MO 2 Communication Just like
52. d defines this statement to mean that some action may be needed to prepare the group for service because it had been sitting idle for a period of time and some equipment parts have deteriorated or need replacing before the group can be operated The group should be operable at the time the IR begins This does not include groups that may be idle because of a failure and dispatch did not call for operation group that is not operable or is not capable of operation at a moment s notice should be on a forced maintenance or planned outage and remain on that outage until the proper repairs are completed and the group is able to operate The group must be on RS Reserve Shutdown a minimum of 60 days before it can move to IR status e Mothballed MB MB is defined by IEEE 762 and GADS as The State in which a group or individual WTG is unavailable for service but can be brought back into service after some repairs with appropriate amount of notification typically weeks or months GADS added after some repairs and defines this statement to mean that some action may be needed to prepare the group for service because it had been sitting idle for a period of time and some equipment parts may have deteriorated or need replacing before the group can be operated The group may have also experienced a series of mechanical problems for which management may wish to wait for a period of time to determine if the group should be repaired or retired A group
53. d to replace the transformer the balance of the turbines are MO All of the turbines would have the same system classification which in this case is Electrical Individual Turbine Transformer b A turbine gearbox failed several weeks ago FO In order to safely remove the rotor and gearbox 2 neighboring turbines were shutdown The 2 neighboring turbines are MO The system classification for all turbines is Gearbox Gearbox in this case Retrofits and Upgrades Most of these types of events will fall into the MO category They could include anything from upgrading the turbine software to installing a larger rotor If the items involve long term planning specifically in the budget then consider PO Economic Repair Sometimes it is advantageous to shut down a turbine in order to minimize costly repairs In this case the turbine must clearly meet the MO standards and be able to run for another week If used inappropriately an FO event could be disguised as an MO For example if a turbine is continuously faulting multiple times a day then the outage is FO not MO The following are examples a Aturbine has a trailing edge blade crack and can clearly run but the crack will propagate over time eventually leading to a blade failure Turning the turbine off now will minimize the repair cost and prevent further damage Plant management could decide to keep the turbine in service for another week so the outage is MO not FO Repairs are complete
54. d to your utility Appendix B contains a guide for selecting utility codes NERC Unit Code Column 5 Enter the three character alpha numeric code your utility assigned for the unit that you are reporting This code distinguishes one unit from another in your utility Appendix B contains a guide for selecting unit codes Sub Group Number Column 6 The sub group number identifies all the individual sub groups within a parent group Each sub group is assigned a unique code as they are entered starting with 1 through 999 If you have two groups Group A having 2 sub groups and Group B having 3 sub groups the sub groups associated with Group A would be numbered 1 and 2 while the sub groups associated with Group B would be numbered 1 2 and 3 Sub Group Name Column 7 Enter the name given to the sub group that you are reporting Commissioning Year Column 8 Enter the year YYYY that the sub group was commissioned NERC GADS W Data Reporting Instructions November 2014 8 Chapter 2 Plants Groups and sub groups Nameplate Capacity Column 9 Enter the individual turbine capacity or megawatt MW rating of the typical wind turbine in the group For example if your subgroup is made up of twenty 1 5 MW turbines you would enter 1 5 MW Total Number of Turbines Column 10 Enter the actual number of physical turbines that exist in the sub group For example if your subgroup is made of twenty turbines you would enter 20 Typ
55. data or information The provisions of Sections 1602 3 1602 4 1602 5 and 1602 6 shall be applicable to a request for data or information or modification to a previously authorized request for data or information developed and issued pursuant to Section 1606 except that a if NERC makes minor changes to an authorized request for data or information without Board approval such changes shall require Board approval if a Reporting Entity objects to NERC in writing to such changes within five 5 days of issuance of the modified request and b authorization of the request for data or information shall be final unless an affected party appeals the authorization of the request by the Board of Trustees to the Applicable Governmental Authority within five 5 days following the decision of the Board of Trustees authorizing the request which decision shall be promptly posted on NERC s website NERC NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION GADS Wind Turbine Generation Data Reporting Instructions January 1 2016 RELIABILITY ACCOUNTABILITY 3353 Peachtree Road NE Suite 600 North Tower Atlanta GA 30326 404 446 2560 www nerc com MET V luet UCU o o E vi Abee MUST REDON iore OTRO ein eie d anced te ect ates ex Uem UN Im vi Chapter 1 Data Transmittal and Format 1 Maru a
56. dders o Added 1067 Climb Assist Ladders o Added 1068 Tower Filtration o Added 1069 Lighting o Added 1070 Hoist o Added 1076 Corrosion Control Added new system Human Performance O O O O O Added 1071 General Added 1072 Operator Added 1073 Maintenance Added 1074 Contractor Added 1075 Procedure Error Appendix D Terms and Definitions Added General subsection O O O Added Revenue Meter Added Off Taker Added Utility Added Plant NERC GADS W Data Reporting Instructions November 2014 85 Appendix G Outside Management Control o Added Group o Added Sub Group Capacity and Generation subsection o Added Turbine Net Maximum Capacity TNMC o Added Net Dependable Energy NDE Turbine States and Hours Collection o Clarified the Reserve Shutdown Definition o Moved examples to the appendix Equivalent Hours o Defined Equivalent Hours o Added Equivalent Forced Derated Turbine Hours EFDTH o Added Equivalent Maintenance Derated Turbine Hours EMDTH o Added Equivalent Planned Derated Turbine Hours EPDTH Delays o Defined Delay Hours o Added Forced Delay Turbine Hours FDTH o Added Maintenance Delay Turbine Hours MDTH o Added Planned Delay Turbine Hours PDTH Updated Figures D2 and D3 Added Figure D4 Cross Reference Chart Appendix E Performance Equations Modified equations for equivalent hour derates Add
57. dict wind profiles in a well mixed atmosphere over flat open terrain However higher exponent values are normally observed over vegetated surfaces and when wind speeds are light to moderate i e under 7 m s or 16 mph Per NREL Handbook 1 Vertical wind shear exponent Wind shear is defined as the change in horizontal wind speed with a change in height The wind shear exponent a should be determined for each site because its magnitude is influenced by site specific characteristics The 1 7th power law as used in the initial site screening may not be applied for this purpose as actual shear values may vary significantly from this value Solving the power law equation for a gives a Log10 v2 v1 Log10 z2 z1 Where v2 the wind speed at height z2 and v1 the wind speed at height z1 1 The Wind Resource Assessment Handbook was developed under National Renewable Energy Laboratory NREL Subcontract No TAT 5 15283 01 April 1997 Table 8 Month Reference Monthly Summaries 01 January 07 July 02 February 08 August 03 March 09 September 04 April 10 October 05 May 11 November 06 June 12 December NERC GADS W Data Reporting Instructions November 2014 62 Appendix F Reference Tables Table 9 Sub group Status Status Entry Active AC Inactive Reserve IR Mothballed MB Retired RU NERC GADS W Data Reporting Instruction
58. down Outages and and Derates RSTH Derates PTH Resource Maintenance Unavailable Outage MTH RUTH Scheduled Outages Figure D 1 Time Spent in Various Turbine Unit States Calendar Hours CalH Calendar Hours are the total number of hours within a given range of dates These are typically shown as the number of hours in a month quarter or year Inactive Hours Inactive Hours are the total number of calendar hours that a unit is in an inactive state IA Period Hours Active Hours PH Period Hours account for the number of calendar hours that the equipment is in an active state Turbine Hours TH Turbine Hours are equal to the number of turbines in the group or sub group times the number of Calendar Hours in the period TH for any given condition for a given sub group is equal to the total number of Calendar Hours that each wind turbine WTG in the sub group spent in the given condition All of the following time condition classifications are considered to be in turbine hours For example the number of TH for a group of 12 WTG in January with 744 hours in January would be 12 x 744 or 8 928 TH If one of those turbines were mothballed the Period Turbine Hours PTH would be 11 x 744 or 8 184 PTH with 744 Inactive Turbine Hours Calendar Turbine Hours CalTH CalTH is equal to the sum of Period Turbine Hours PDTH and Inactive Turbine Hours ITH In most cases PDTH and CalTH will be the same number Peri
59. e ID for the plant that you are reporting This ID is referenced in all groups sub groups performance and component data existing under the plant Plant Name Column 2 With help from NERC staff enter a unique name which may be more descriptive than the Plant ID given to the plant that you are reporting Groups A group is one or more sub groups that are contained within a common plant boundary There may be any number of groups per wind plant Groups are usually phases that are commissioned during a particular year Each group has a unique number that identifies it as part of a particular wind plant Each group will have a unique turbine group ID that will be associated with its child sub group The reporting utility assigns this ID NERC GADS W Data Reporting Instructions November 2014 3 Chapter 2 Plants Groups and sub groups Wind Turbine Group Groups report the following site data e Associated Plant ID e Turbine Group ID e Turbine Group Name e NERC Utility Code e NERC Unit Code e ISO Resource ID e Installed Capacity e Auxiliary Capacity e Commissioning Year e Country e Nearest City e State Province e Location Longitude and Latitude e Elevation e Wind Regime topography Sub Group 3 e Annual Average Wind Speed e SCADA Manufacturer e SCADA Model Figure 3 Wind Turbine Groups Note The ISO Resource ID is listed at the Group level If you have multiple ISO Resource ID s you may want
60. e a unique identification code This three character alpha numeric code allows each system s data to be uniquely cataloged and filed in the database Please look at the NERC GADS website or contact your Regional Entity for the latest list of utility codes Getting a New Utility I dentification Code NERC assigns each utility participating in the wind turbine generation database a unique identification code This three character alpha numeric code allows each system s data to be uniquely cataloged and filed in the database Plant I dentification Codes With assistance from the NERC staff or Regional Entity each utility participating in the wind turbine generation database assigns their own unique identification codes to its plants This unique three character alpha numeric code allows each plant s data to be cataloged and filed in the database NERC GADS W Data Reporting Instructions November 2014 19 Appendix C System Component Codes The following tables list available components for each system and the code to enter for each component System Component Entry General 674 Underground 650 Metering and Relays 655 Overhead Lines 652 Pad Mount Multiple WTG 651 Preventative Maintenance 682 SCADA 656 Site Reactive Power Comp 654 Substation 653 Wind Park Control System 657 Balance of Plant Break
61. e state 2 Theturbine must be available not in an outage state 3 The turbine must not be in eminent danger of failure Note Disabling a turbine such as removing a processor card immediately puts the turbine in an outage state and makes it no longer available Economic for purposes Reserve Shutdown is defined as demand or market curtailments Examples of RSTH are negative energy pricing contracts agreements Resource Unavailable Turbine Hours RUTH RUTH is the number of turbine hours the sub group is not producing electricity due to the wind being too low or too high or due to reasons outside the manufacturer s operating specifications RUTH is classified as Available Turbine Hours for equipment calculations and Unavailable Turbine Hours for site calculations See Figures D 2 D3and D 4 below Forced Turbine Hours FTH FTH is the sum of all turbine hours that the sub group is off line due to forced events FTH are all forced events where the WTG must be removed from service for repairs before the next Sunday at 23 59 just before Sunday becomes Monday Examples can be found in Appendix H OMC Forced Turbine Hours oFTH OFTH is a sub set of FTH that equals any forced turbine hours that were due to causes deemed to be outside of management control For more information on OMC refer to Appendix G Examples can be found in Appendix H NERC GADS W Data Reporting Instructions November 2014 28 Appendix D Terms and Defini
62. ed Outage Rate RESOR Probability of maintenance or planned plant downtime when needed for load MTH PTH EMDTH EPDTH RESOR x100 CTH MTH PTH 1 B Equipment Performance Factors These are performance rates and factors that highlight the effect of the equipment and reduce the effect of the resource availability plant view In order to do that Resource Unavailable Turbine Hours RUTH are considered available non generating hours rather than forced outage hours This gives the maximum number of hours the equipment could have operated normally 1 B 1 1 B 2 1 B 3 Equipment Equivalent Availability Factor EEAF 26 of period that the WTG equipment was available PDTH FTH MTH PTH EFDTH EMDTH EPDTH H S PDTH EEAF 100 z 100 EEUF Equipment Equivalent Unavailability Factor EEUF of period that the WTG equipment was peer FTH MTH PTH EFDTH EMDTH EPDTH PDTH EEUF x 100 100 EEAF Equipment Equivalent Planned Outage Factor EEPOF of period that the WTG equipment was in planned downtime PTH EPDTH PDTH EEPOF 100 NERC GADS W Data Reporting Instructions November 2014 37 1 B 4 1 B 5 1 B 6 1 B 7 1 B 8 1 B 9 Appendix E Performance Equations Equipment Equivalent Maintenance Outage Factor EEMOF of period that the WTG equipment was in maintenance downtime MTH EMDTH PDTH EEMOF 100
63. ed the word Pooled and the letter P to each of the pooled equations Corrected equations 3 B 8 to 3 B 12 and 4 B 8 to 4 B 12 Added RUTH to the denominator Appendix F Manufacturers Changed the title to Reference Tables Moved tables from the body to appendix Appendix H Examples Changed the title to Outage Classification Guidelines Added a section on General Considerations Updated the entire section with categories of events with general principles Appendix Overlapping Events Appendix J Data Submittal Quality Checks Appendix K Frequently Asked Questions Rate versus factor NERC GADS W Data Reporting Instructions November 2014 86 Appendix G Outside Management Control Equivalent hours Weighting methods NERC GADS W Data Reporting Instructions November 2014 87
64. eliability Organization and each Regional Entity shall provide the Commission such information as is necessary to implement section 215 of the Federal Power Act Section 1600 of NERC s Rules of Procedure provides 1601 Scope of a NERC or Regional Entity Request for Data or Information Within the United States NERC and regional entities may request data or information that is necessary to meet their obligations under Section 215 of the Federal Power Act as authorized by Section 39 2 d of the Commission s regulations 18 C F R 39 2 d In other jurisdictions NERC and regional entities may request comparable data or information using such authority as may exist pursuant to these rules and as may be granted by ERO governmental authorities in those other jurisdictions The provisions of Section 1600 shall not apply to requirements contained in any Reliability Standard to provide data or information the requirements in the Reliability Standards govern The provisions of Section 1600 shall also not apply to data or information requested in connection with a compliance or enforcement action under Section 215 of the Federal Power Act Section 400 of these Rules of Procedure or any procedures adopted pursuant to those authorities in which case the Rules of Procedure applicable to the production of data or information for compliance and enforcement actions shall apply 2 4 Dues 1602 Procedure for Authorizing a NERC Request for Data or
65. ent Equivalent Maintenance Outage Rate PXEEMOR Probability of maintenance WTG equipment downtime when needed for load MTH EMDTH oMTH oEMDTH X CTH MTH oMTH RUTH PXEEMOR 2 k x100 NERC GADS W Data Reporting Instructions November 2014 57 Appendix E Performance Equations 4 B 10 Pooled OMC Equipment Equivalent Forced Outage Rate PXEEFOR Probability of forced WTG equipment downtime when needed for load Y FTH EFDTH oFTH oEFDTH x 100 3 CTH FTH oF TH RUTH PXEEFOR 4 B 11 Pooled OMC Equipment Equivalent Unplanned Outage Rate PXEEUOR Probability of forced or maintenance WTG equipment downtime including high and low winds when needed for load FTH MTH EFDTH EMDTH OFTH oMTH oEFDTH oEMDTH 1 X CTH FTH MTH oFTH oMTH RUTH PXEEUOR H 4 B 12 Pooled OMC Equipment Equivalent Scheduled Outage Rate PXEESOR Probability of maintenance or planned WTG equipment downtime when needed for load MTH PTH EMDTH EPDTH oMTH oPTH oEMDTH oEPDTH x100 X CTH MTH PTH oMTH oPTH RUTH PXEESOR 2 NERC GADS W Data Reporting Instructions November 2014 58 Appendix F Reference Tables If you would like to add an item to any of the tables please e mail your request to GADS at gads nerc net Table 1 Country
66. eral OMC 681 Gatastrophe Leave Blank 680 Catastrophe OMC 1034 Economic 679 Economic OMC 1035 Off Taker Transmission amp Distribution OMC 675 External Weather Ice OMC 1036 Weather Lightning OMC 678 Weather Temperature OMC 676 External Communication OMC 1057 Weather Turbulence OMC 1076 Legal Contractual or Environmental OMC System Component Entry General 669 Gear Box 608 Gear Box Heating Cooling 609 Gear Box Oil System 610 Gear Box Gearbox Filtration 611 Torque Arm System 612 System Component Entry General 668 Exciter 634 P Generator 631 Generator Exciter Generator Bearings 632 Generator Cooling Systems 636 Generator Lube Oil Systems 633 NERC GADS W Data Reporting Instructions November 2014 21 Appendix C System Component Codes Generator Shaft 635 Wiring to Gen Terminals 637 RCC Rotor Current Control 641 High Speed Coupling 1058 Power Slip Rings 1059 System Component Entry General 667 Common Pump and Motor 627 Filtering System 629 5 Hoses Reservoirs Valves 630 Hydraulic System Hydraulic Accumulator 628 Hydraulic Slip Ring 1060 System Component Entry General 666 Electrical 626 Mechanical Eleetrieal 624 Pitch Hydraulics 625 e Battery Backup 1061 Pitch System Pitch Controller 1062 Pitch Motor 1063 Pitch Gea
67. eric 10 2 decimals Mandatory 15 Forced Turbine Hours FTH Numeric 10 2 decimals Mandatory 16 Maintenance Turbine Hours MTH Numeric 10 2 decimals Mandatory 17 Planned Turbine Hours PTH Numeric 10 2 decimals Mandatory 18 OMC Forced Turbine Hours oFTH Numeric 10 2 decimals Mandatory 19 OMC Maintenance Turbine Hours OMTH Numeric 10 2 decimals Mandatory 20 OMC Planned Turbine Hours oPTH Numeric 10 2 decimals Mandatory 21 Resource Unavailable Turbine Hours RUTH Numeric 10 2 decimals Mandatory 22 Inactive Reserve Turbine Hours IRTH Numeric 10 2 decimals Mandatory 23 Mothballed Turbine Hours MBTH Numeric 10 2 decimals Mandatory 24 Retired Unit Turbine Hours RTH Numeric 10 2 decimals Mandatory 25 Blank Blank Blank 26 Blank Blank Blank 27 Blank Blank Blank 28 Blank Blank Blank 29 Blank Blank Blank 30 Blank Blank Blank 31 Equivalent Forced Numeric 10 2 decimals Mandatory Derated Turbine Hours EFDTH 32 Equivalent Maintenance Numeric 10 2 decimals Mandatory Derated Turbine Hours EMDTH 33 Equivalent Planned Numeric 10 2 decimals Mandatory Derated Turbine Hours EPDTH 34 OMC Equivalent Forced Numeric 10 2 decimals Mandatory Derated Turbine Hours oEFDTH NERC GADS W Data Reporting Instructions November 2014 10 Chapter 3 Performance Reporting 35 OMC Equivalent Maintenance Numeric 10 2 decimals Mandatory Derated Turbine Hours OE
68. ers 1037 Main Substation Transformer 1038 Switches 1039 Wave Trap 1040 CT PT 1041 Battery Systems 1042 Site Communication 1043 Fuses 1044 Transmission Gen Tie 1075 System Component Entry General 673 High Speed Shaft Brake 617 Brak Mechanical Lock 618 rane Brake Hydraulic System 1045 System Component Entry General 672 Cabinet Cooling Heating 648 Cold Weather Control 647 Control Com Links Top and Bottom 644 Low Voltage Control Wiring 638 Processor 645 Processor Cooling 646 Reactive Power Control 640 Sensors 642 Control System Software 643 Voltage Regulation 639 Moved to Generator Exciter Wind Vane and Anemometer 649 Hardware 1046 Power Supply 1047 Control Cabinet Filtration 1048 Control Slip Rings 1049 NERC GADS W Data Reporting Instructions November 2014 20 Appendix C System Component Codes System Component Entry General 671 Rotor Coupling 615 Main Bearings 613 Drive Train Main Shaft 614 Transmission Shaft 616 System Component Entry General 670 Circuit Breakers and Switches 661 Individual Turbine Transformers 662 Power Compensation WTG 660 Power Converters 658 e Transmission Cables 659 et Current Transformers SO Power Transformers 0ST Converter Cooling 1 1092 k Power Supply A2L 1093 5 k System Component Entry Gen
69. ever if a reporting entity objects to NERC in writing to such changes within 21 days of issuance of the modified request such changes shall require board approval before they are implemented Authorization of a request for data or information shall be final unless within thirty 30 days of the decision by the Board of Trustees an affected party appeals the authorization under this Section 1600 to the ERO governmental authority 1603 Owners Operators and Users to Comply Owners operators and users of the Bulk Power System registered on the NERC Compliance Registry shall comply with authorized requests for data and information In the event a reporting entity within the United States fails to comply with an authorized request for data or information under Section 1600 NERC may request the Commission to exercise its enforcement authority to require the reporting entity to comply with the request for data or information and for other appropriate enforcement action by the Commission NERC will make any request for the Commission to enforce a request for data or information through a non public submission to the Commission s enforcement staff 1605 Confidentiality If the approved data or information request includes a statement under Section 1602 1 1 v that the requested data or information will be held confidential or treated as Critical Energy Infrastructure Information then the applicable provisions of Section 1500 will apply
70. fication to a previously authorized request for public comment under Section 1606 NERC shall provide the proposed request or modification including the information specified in paragraph 1602 2 1 or 1602 2 2 as applicable to the Commission s Office of Electric Reliability The submission to the Commission s Office of Electric Reliability shall also include an explanation of why it is necessary to use the expedited procedures of Section 1606 to obtain the data or information The submission shall be made to the Commission s Office of Electric Reliability as far in advance up to twenty one 21 days of the posting of the proposed request or modification for public comments as is reasonably possible under the circumstances but in no event less than two 2 days in advance of the public posting of the proposed request or modification 3 NERC shall post the proposed request for data or information or proposed modification to a previously authorized request for data or information for a public comment period that is reasonable in duration given the circumstances but in no event shorter than five 5 days The proposed request for data or information or proposed modification to a previously authorized request for data or information shall include the information specified in Section 1602 2 1 or 1602 2 2 as applicable and shall also include an explanation of why it is necessary to use the expedited procedures of Section 1606 to obtain the
71. fied period of time This method works in all cases See Figure K3 Net Dependable Capacity NDC This gives the same result as Net dependable energy NDC is what the plant was capable of for that month The installed capacity may be much higher but over a period of time a wind plant will never achieve 100 of its installed capacity vs a conventional plant can easily achieve 100 of its rated capacity NERC GADS W Data Reporting Instructions November 2014 80 Appendix G Outside Management Control NERC GADS W Data Reporting Instructions November 2014 81 Appendix L Performance Data Metric Performance System Component Sub Group Status v v v Gross Actual Generation MWh Net Actual Generation MWh l Group Installed Capacity MW Net Maximum Capacity MW Period Turbine Hrs Contactor Turbine Hrs Reserve Shutdown Turbine Hrs Forced Turbine Hrs Maintenance Turbine Hrs Planned Turbine Hrs OMC Forced Turbine Hrs OMC Maintenance Turbine Hrs OMC Planned Turbine Hrs Resource Unavailable Turbine Hrs Inactive Reserve Turbine Hrs Mothball Turbine Hrs Retired Turbine Hrs Equivalent Forced Derated Turbine Hrs Equivalent Maintenance Derated Turbine Hrs Equivalent Planned Derated Turbine Hrs OMC Equivalent Forced Derated Turbine Hrs OMC Equivale
72. g Council Figure 1 Regional Entities Terms Definitions and Equations The terms definitions and equations used throughout this manual can be found in Appendix D amp E Data Release Guidelines The GADS W Data Release Guidelines can be found in Appendix A NERC GADS W Data Reporting Instructions November 2014 vi Chapter 1 Data Transmittal and Format Transmittal There are five different types of data files that you will need to submit 1 Plant 2 Group 3 Sub Group 4 Component Outage 5 Performance Before submitting the component outage and performance data for your wind plants you must report the plant group and sub group data for each plant to the GADS W database You only need to provide the plant group and sub group data initially when you begin reporting data for each plant and then update it when the characteristics of the plant change We strongly recommend that all five of the files be reviewed and reported with each quarterly submittal This data provides information regarding installed equipment design and operating characteristics of the plant that are used in when completing special analysis Once the plant group and sub group data have been reported to the GADS W database you can begin to report the component outage and performance data Submit the component outage and performance data to GADS W within 45 days after the end of every calendar quarter through gads nerc net Report this data throu
73. ghout the life of each plant Format Data should be submitted to NERC in CSV comma separated value file format CSV is a common file type used to import data from one software application to another with commas or tabs separating the values in each record Please ensure that all values are not formatted with any punctuation other than a decimal point and slashes used in dates for example numbers with embedded commas can cause problems such as 12 000 25 In this example the value should be reported as 12000 25 The CSV files should be saved with the name of the data type ex plant csv group csv subgroup csv performance csv component csv as part of the file name to easily differentiate between them Also include the Plant ID in the file name Plant ID s are discussed in Section 3 Wind Generation Data Entry Software NERC has developed the Wind Generation Data Entry software to assist with the collection of wind generation data The software along with the accompanying Wind Generation Data Entry Software User Manual is available free of charge from NERC s web site http www nerc com pa RAPA gads Pages Data 20Reporting 20Instructions aspx Questions and Comments All questions regarding data transmittals and reporting procedures should be directed to gads nerc net NERC GADS W Data Reporting Instructions November 2014 1 Chapter 2 Plants Groups and sub groups r mmm See Plant Boundary em emm mmm mmm emm
74. he period being reported Number of Forced Outage Occurrences Column 10 Enter the total number of forced outage events that are attributed to the system component specified above during the period being reported Maintenance Turbine Hours Column 11 Enter the total number of maintenance turbine hours for the reporting sub group that are attributed to the system component specified above during the period being reported Number of Maintenance Outage Occurrences Column 12 Enter the total number of maintenance outage events that are attributed to the system component specified above during the period being reported Planned Turbine Hours Column 13 Enter the total number of planned turbine hours for the reporting sub group that are attributed to the system component specified above during the period being reported Number of Planned Outage Occurrences Column 14 Enter the total number of planned outage events that are attributed to the system component specified above during the period being reported Component Derates and Delay Turbine Hours Equivalent Forced Derated Turbine Hours Column 15 Enter the total number of equivalent forced outage hours that are attributed to the system component specified above during the period being reported Equivalent Maintenance Derated Turbine Hours Column 16 Enter the total number of equivalent maintenance outage hours that are attributed to the system component specified above during the pe
75. her turbine As soon as the technician removes the board the turbine is no longer RS and is in an outage state no longer available Economic shutdown is an outage due to market or demand issues NERC GADS W Data Reporting Instructions November 2014 72 Appendix Overlapping Events Often events overlap and make it confusing to classify them Sometimes it appears that there is a penalty for something the Plant Management has no control The general rule for overlapping events is first in first out In other words the first issue must be resolved before the second issue can take control Below are some examples 1 A turbine is in the process of having its gearbox replaced when a lightning storm moves in and delays the work for a day The forced outage continues through the lightning storm The outage type does not change but is delayed due to lightning Gearbox Failure with a Parallel Lightening Storm Gearbox Failure Work Completed FO Gearbox Failure ork Stops FO Delayed Gearbox Failure Work Started FO Lightning Storm Shuts Down Work OMC Time 2 The plant is planning a 3 week outage for transmission repairs The day before the outage the generator rotor shorts out and a generator replacement is required Generator Failure with a Parallel Planned Outage Gen Failure FO EENEG Site PO Gen RTS Becomes part of the PO Time 4
76. ical Design Manufacturer Column 11 Using Table 5 in Appendix F enter the name of the manufacturer of the turbines in the sub group Model Column 12 Enter the model of the make of the turbines in the sub group Version Column 13 Enter the version name of the turbines in the sub group Rotor Height Column 14 Enter the height of the rotor hub given in meters Rotor Diameter Column 15 Enter the diameter of the rotor given in meters Cut in Wind Speed Optional Column 16 Enter the lowest wind speed that the turbine will start to generate power in meters per second Low Cut out Wind Speed Optional Column 17 Enter the lowest wind speed that the turbine can continue to generate power before cutting out in meters per second High Cut out Wind Speed Optional Column 18 Enter the highest wind speed at which the turbine is capable of generating power before cutting out in meters per second Turbine Wind Class Turbulence I ntensity Optional Column 19 Using Table 6 in Appendix F select the average wind turbulence where the sub group is located Average Wind Speed Optional Column 20 Enter the average annual wind speed AAWS at 80m measured in meters per second Wind Shear Optional Column 21 Using Table 7 in Appendix F select the average strength of the difference between the speed of wind from the tip of the rotor at its lowest point and its highest point Reference Anemometer Height Optional
77. ind generation is having on Event Driven and Condition Driven risk detailed event information and generation performance characteristics e Monitoring the impact of transmission outages on generators and generator outages on transmission If NERC does not collect this information and wind generation capacity increases according to projections NERC may not be able to adequately assess power system reliability in either the short term or long term horizon Accordingly NERC is posting this proposed Data Request in accordance with the requirements of Section 1600 of the NERC Rules of Procedure for public comment NERC provided this proposed data request to FERC for information on January 20 2014 as required by Section 1602 of the NERC Rules of Procedure The 45 day public comment period will run from February 17 2015 to April 3 2015 NERC will present this proposed Data Request revised as appropriate in response to comments received to the Board for approval as required by Section 1602 of the NERC Rules of Procedure With NERC Board approval this data request will become mandatory for all Generator Operators on the NERC registered entities list that operate wind turbine facilities of 75 MW or greater NERC Contact Information The Data Request must be completed in electronic format Should the submitting entity experience any issues with submitting its data contact Howard Gugel via email at Howard Gugel nerc net or by telephone at 404 44
78. k power system 1 A 1 Resource Equivalent Availability Factor REAF REAF of period that the plant was available PDTH FTH MTH PTH EFDTH EMDTH EPDTH RUTH PDTH x 100 100 REUF NERC GADS W Data Reporting Instructions November 2014 34 1 A 2 REUF Appendix E Performance Equations Resource Equivalent Unavailability Factor REUF of period that the plant was unavailable FTH MTH PTH EFDTH EMDTH EPDTH RUTH PDTH x 100 100 REAF 1 A 3 1 A 4 1 A 5 REFOF Resource Equivalent Planned Outage Factor REPOF of period that the plant was in planned downtime PTH EPDTH PDTH REPOF x100 Resource Equivalent Maintenance Outage Factor REMOF of period that the plant was in maintenance downtime MTH EMDTH PDTH REMOF 00 Resource Equivalent Forced Outage Factor REFOF of period that the plant was forced off line Including low and high winds FTH EFDTH RUTH T 1 A 6 1 AJ PDTH Resource Equivalent Unplanned Outage Factor REUOF of period that the plant was unavailable due to forced and maintenance downtime For generation resource planning FTH MTH EFDTH EMDTH RUTH PDTH REUOF x 100 Resource Equivalent Scheduled Outage Factor RESOF of period that the plant was unavailable due to maintenance and planned downtime MTH PTH EMDTH EPDTH PDTH R
79. le to have a negative NAG value if the group s station service or auxiliary loads are greater than total generation Net Dependable Energy NDE The Net Dependable Energy is defined as the potential energy based upon available resource Group or Sub Group States Active or Commercial State Active Active state is the time from when the group is first declared commercially active until it moves to the inactive state shown below A group is declared commercial when NERC GADS W Data Reporting Instructions November 2014 25 Appendix D Terms and Definitions e The group is capable of reaching 50 of its generator nameplate MW Capacity wind conditions not part of requirement and e Dispatch is notified that the group is capable of providing power wind conditions not part of requirement e Power Purchase Agreement PPA or other distribution agreements satisfied Inactive State 1A Inactive State is called Deactivated Shutdown in IEEE 762 and is defined as The state in which a group or individual WTG is unavailable for service for an extended period of time for reasons not related to the equipment GADS interprets this to include the following e Inactive Reserve IR IR is defined by IEEE 762 and GADS as The State in which a group is unavailable for service but can be brought back into service after some repairs in a relatively short duration of time typically measured in days GADS added after some repairs an
80. ly owned by the off taker Off Taker The entity that receives the power produced by the plant Utility The principal organization that owns one or more plants Plant The energy generating facility that consist of one or more groups or subgroups Group Each plant consist of one or more groups Groups are differentiated by the year they were commissioned Sub Group Each group consist of one or more sub groups Capacity and Generation Group I nstalled Capacity GI C GIC is the sum of all the wind turbines system nameplate rating capability within the group GIC does not include spare wind turbines installed AGIC below For example suppose that you have two sub groups within the group The first sub group is comprised of 20 Vestas V 47 machines rated at 0 66 MW each and the second sub group is comprised of 10 GE 1 5 machines rated at 1 5 MW each The GIC would be 20 x 0 66 MW 10 x 1 5 MW which would be 13 20 MW 15 0 MW This would give you a GIC of 28 2 MW Auxiliary Group I nstalled Capacity AGI C AGIC is the installed capacity of any turbines that are not part of the GIC These turbines must be available and connected to a sub group not in an inactive state and their output can be temporarily added to the sub group at a moment s notice in the event that another turbine becomes unavailable The purpose of auxiliary capacity is to allow producers to use WTGs that may have been phased out but are still in good w
81. mer Fails Taking Out All the Turbines on the Circuit The Example is Complicated by Equipment Delays and Weather Transformer Replaced FO Ice on Blades Weather OMC Transformer Turbine Circuit out until the Transformer Bypass is Completed FO Replaced MO Balance of Turbines on thecircuit Time Events can be complicated but if taken in pieces they are easier to code The original turbine with the failed transformer is an FO until the transformer is replaced and the turbine is available This turbine also experienced storms ice and equipment delays but they do not change the outage type NERC GADS W Data Reporting Instructions November 2014 74 Appendix G Outside Management Control The balance of the turbines on the circuit collateral FO is FO until the bypass is complete and the turbines are returned to service RTS Once the bypass is complete the event is coded as External Weather Ice OMC After the weather event the turbines are available then another icing event occurs When the failed transformer is replaced and the bypass removed the collateral turbines are placed into MO until repairs are completed NERC GADS W Data Reporting Instructions November 2014 75 Appendix J Data Quality Control GADS data should be reviewed for the following potential discrepancies before submission This list is by no means comprehensive but data not meeting these minimum requirements will
82. mometer If the anemometer has a heater to prevent ice build up then the equipment failed EFOR If the anemometer had no heater the event would be classified at Weather OMC Think about other forms of protection such as blade lightning protection Recovering from a site wide event like an outage OMC or a Plant substation breaker trip can be challenging to classify Not all turbines will automatically restart when power is restored The assumption here is that a turbine should be able to handle an unplanned outage without a component failure Electrical conditions during an outage are complex and turbines may fault due to out of spec electrical parameters The OMC ends when one of the following 3 conditions occur a The turbine automatically restarts b The turbine is reset from SCADA and restarts c The turbine is visited and restarted locally If the turbine fails to restart after a local reset a FO event begins at that point Occasionally events will delay resets or repairs Heavy snow is an example of this In the Off Taker outage above snow could have delayed access to the turbine for weeks The Off Taker outage would not end until there is access to the turbine and the turbine reset The event type does not change it is only delayed See Delays Other types of delays could be floods earthquakes fires parts availability equipment availability labor etc At times events will overlap The first in first out rule should apply in
83. n example when a turbine runs away neighboring turbines may be in danger of damage from flying debris If they are shut down they are part of the event and are FO Forced OMC Events These are events that occur beyond the wind plant boundaries or are caused by abnormal weather These events are beyond the plant manager s ability to control Note Forced OMC outages are a subset of FO 1 Off Taker OMC Off Taker OMC comes in several forms Code it as External Off Taker OMC Forced a Equipment failure is a forced OMC outage b Weather outage or brown out usually due to lightning line slaps icing is a forced outage c Line congestion is a limitation of the Off Taker s equipment and is a forced outage d Long outages in very cold weather will require heaters to warm the equipment before the turbine can restart This warm up period is part of the Off Taker outage 2 Economic OMC A Labor strike would go under this category since there is no problem with the equipment Code as External Economic OMC Forced 3 Catastrophic OMC Major events like tornados hurricanes earthquakes wild fires are OMC 4 Weather Ice OMC When icing forces turbines off line it can be classified as OMC in some cases a Icing downtime due to ice on equipment like anemometers windvanes and blades is OMC If the turbines have protective equipment and ices over anyway then the protection failed and the event is not OMC However if the protec
84. n the equipment is returned to service The delay helps NERC understand why it took so long NERC GADS W Data Reporting Instructions November 2014 71 Appendix G Outside Management Control Weather occasionally prevents access to turbines impacting return to service time Delays due to snow flooding or a tornado scattering debris can delay access to the turbine increasing downtime Delays occur when there is inadequate technician support available This could be due to vacations illness or other personnel issues When the stock of replacement parts falls short repairs are delayed Reserve Shutdown RS RS is a decision by plant management to shut down available turbines that are in an active state and not in outage or in danger of failure IEEE 762 defines the condition as an economic shutdown Turbines in this state must remain available If they are disabled in any way like removing the controller they move into an outage state PO MO or FO It can be difficult to discern between OMC and RS at times The following are examples 1 Wind Plant A is actively participating in the energy market During certain times of the day pricing goes negative Negative energy pricing so the revenue from the energy cannot cover the cost of operating the plant The plant shuts down the turbine during these periods which is an RS During an RS due to negative energy pricing a technician needs a controller board to repair anot
85. nt Maintenance Derated Turbine Hrs OMC Equivalent Planned Derated Turbine Hrs NININ S INININ IS SISISISNISN SN INISISNISISN SN INIS S l Component Force Outage Hrs Component Force Outage Occurrences Component Maintenance Outage Hrs Component Maintenance Occurrences Component Planned Outage Hrs NINISISISINSISNISISISISNISNISISISNISNIS SS SN INISNINIS INN INN S Component Planned Occurrences Sub Component Force Outage Hrs Sub Component Force Outage Occurrences Sub Component Maintenance Outage Hrs Sub Component Maintenance Occurrences Sub Component Planned Outage Hrs Sub Component Planned Occurrences NINSISISISINIS S ISISISIS ISIN ISIN NINERS RRS IS S ISNISNISNISN INN IN SRN Notes 1 There are 15 System categories 2 There are 117 Component categories NERC GADS W Data Reporting Instructions November 2014 82 Appendix G Outside Management Control Appendix M Major Changes from the Previous Version e Added a Typical Wind Plant Layout diagram with Group Sub group clarification e Cleaned up the definition of the plant boundary e Moved tables to the Appendix e Group Record Changes Commercial Date was changed to Commissioning Year Deleted SCADA type Added Off Shore to Wind Regime Revised the list of SCADA Supervisory Control and Data Acquisition manufacturers e Sub Group Record Changes Data columns 16 22 we
86. nt is required to shut down When the loss of communication is due to external causes it should be coded as External Communication OMC Maintenance Events MO These are components or systems that are close to failure or in need of modification The turbine should be capable of running until the following week For example if identified on Tuesday it should be capable of running until the following Monday If identified on the weekend it should be capable of running through the following week If the turbine requires maintenance and won t be able to run until the following week then the outage is FO not MO Repairs can take place anytime as long as the turbine is capable of running as stated above 1 Condition Assessment The condition of the turbine is evaluated using historical trends inspection non destructive testing etc When an issue is found the repair is scheduled Inspections Inspections by their nature are MO If the turbine is down prior to the inspection then it is FO Safety Shutdowns Sometimes neighboring turbines or parallel circuits need to be shut down for safety If the safety shutdown is of an immediate nature or less than the MO definition then it is FO Examples a A transformer failed several weeks ago and was bypassed until a replacement could be acquired The original event including parallel circuits was FO The original transformer failure remains FO but when the rest of the circuit is de energize
87. ntime For generation resource planning FTH MTH EFDTH EMDTH 3 PDTH PEEUOF 2 x100 Pooled Equipment Equivalent Scheduled Outage Factor PEESOF of period that the WTG equipment was unavailable due to maintenance and planned downtime I 3 MTH PTH EMDTH EPDTH en 7 3 PDTH Pooled Equipment Generating Factor PEGF of period that the WTG equipment was online and in a generating state CTH PEGF 3 PDTH RUTH i 100 Pooled Equipment Net Capacity Factor PENCF of actual WTG equipment generation 3 NAG PENCF 3 PDTH RUTH x TNMC x 100 2 B Pooled Equipment Performance Rates 2 B 10 2 B 11 Pooled Equipment Equivalent Planned Outage Rate PEEPOR Probability of planned WTG equipment downtime when needed for load 3 PTH EPDTH PEEPOR 3 CTH PTH RUTH 100 Pooled Equipment Equivalent Maintenance Outage Rate PEEMOR Probability of maintenance WTG equipment downtime when needed for load 3 MTH EMDTH 3 CTH MTH RUTH PEEMOR x 100 NERC GADS W Data Reporting Instructions November 2014 44 Appendix E Performance Equations 2 B 12 Pooled Equipment Equivalent Forced Outage Rate PEEFOR Probability of forced WTG equipment downtime when needed for load 3 ETH EFDTH PEEFOR 3 CTH FTH RUTH 100 2 B 13 Pooled Equipment Equivalent Unplanned Outage Rate PEEUOR Probability of forced or maintenance W
88. o wind low wind high wind derated winds less than rated capacity or losses that occur outside the manufacturer s operating specifications temperature electrical amp etc Another way of looking at NDC is the Capacity of the turbine at 100 availability while running within the manufacture s specification with the fuel source available wind For example if the NMC is 100 MW and the losses from all wind problems is 4096 then the NDC can be calculated as 100 MW x 1 0 40 Our NDC would be 60 MW NDC may also be calculated as follows Actual Generation Turbine specific losses reserve shutdown Site outages such as off taker problems balance of plant not wind related PH Net Available Capacity NAC NAC is the actual generating capability at the revenue meter during the time of a planned maintenance forced reserve or spinning event For example if the NMC is 120 MW and a maintenance event feeder outage reduces the capability by 5 MW then the NAC is 115 MW Gross Actual Generation GAG GAG is the total wind turbine energy going out of the Wind Turbine Group MWh GAG is the sum of all individual turbine meters before removing station service or auxiliary loads GAG should be measured as close to the turbine s generator as possible so that generation is measured before any auxiliary use by the turbine Net Actual Generation NAG NAG is the net generation MWh recorded at the revenue meter It is possib
89. od Turbine Hours PDTH PDTH is the number of Turbine Hours being reported that the sub group is in the active state PDTH can vary in output reports month year etc but for GADS reporting purposes data is collected on the number of Turbine Hours in a month NERC GADS W Data Reporting Instructions November 2014 27 Appendix D Terms and Definitions e n two instances the PDTH may be smaller than the normal period hours for the given month When the sub group becomes commercially active or e When one or more turbines go into the Inactive Reserve Mothballed or Retired State The sum of Available Turbine Hours and Unavailable Turbine Hours must equal sub group Period Turbine Hours Inactive Turbine Hours ITH ITH is the number of turbine hours in a period being reported that the sub group is in the inactive state Contact Turbine Hours CTH CTH is the number of turbine hours the sub group is synchronized to the system It is the turbine hours that the contactors are closed and generation is provided to the grid Reserve Shutdown Turbine Hours RSTH RSTH is the sum of all turbine hours that the sub group is available to the system for economic reasons Do not include RSTH with the same equations with CTH this would result in double counting total turbine hours IEEE 762 and the T H NERC DRI define RSTH as a turbine shutdown due to economic reasons To qualify the following must be true 1 Theturbine must be in an activ
90. oled Resource Performance Rates including resources without OMC hours 4 A 8 4 A 9 4 A 10 NERC GADS W Data Reporting Instructions November 2014 Pooled OMC Resource Equivalent Planned Outage Rate PXREPOR Probability of planned plant downtime when needed for load PTH EPDTH oPTH oEPDTH PXREPOR DI X CTH PTH oPTH x 100 Pooled OMC Resource Equivalent Maintenance Outage Rate PXREMOR Probability of maintenance plant downtime when needed for load MTH EMDTH oMTH 0EMDTH PXREMOR 2 3 CTH MTH oMTH x100 Pooled OMC Resource Equivalent Forced Outage Rate PXREFOR Probability of forced plant downtime when needed for load FTH EFDTH oFTH oEFDTH RUTH PXREFOR H 3 rn FTH oFTH RUTH x100 54 Appendix E Performance Equations 4 A 11 Pooled OMC Resource Equivalent Unplanned Outage Rate PXREUOR Probability of forced or maintenance plant downtime including high and low winds when needed for load UOHrs FTH MTH UDerateOHrs EFDTH EMDTH UOMCHrs oFTH oMTH UOMCDerateHrs oEFDTH oEMDTH 3 UOHrs UDerateOHrs RUTH UOMCHrs UOMCDerateHrs PXREUOR 3 CTH UOHrs RUTH UOMCH s x 100 4 A 12 Pooled OMC Resource Equivalent Scheduled Outage Rate PXRESOR Probability of maintenance or planned plant downtime when needed for load SOHrs PTH MTH SODerateHr s EPDTH EMDTH
91. ons do not include OMC hours Multi Resource and Equipment Calculations without OMC Hours These equations pool the resource and equipment performance of sub groups into collections of sub groups groups or plants These equations do not include OMC hours These equations are not weighted and should only be used for pooling data with turbines of the same turbine capacity In most cases resource performance factors and rates take into account all outages and hours These include but are not limited to outages from resource wind unavailability equipment failures off taker events weather and any other non equipment outages Resource equations are primarily used by resource planners integrating wind energy into the bulk power supply Equipment performance factors and rates take into account Calendar Hours Period Hours and all outages pertaining to equipment that fall within and outside of management control for a given study Equipment performance equations are used by plant managers to monitor performance behind the plant boundary SECTION 1 Resource and Equipment Calculations for sub groups 1 A Resource Performance Factors These are performance rates and factors that highlight the effect of the resource and are primarily used by planners or from a system view In order to do that Resource Unavailable Turbine Hours RUTH are treated as forced outage hours This defines the ability of the technology to deliver power to the bul
92. orking condition to improve their availability when turbines in the main generating group are in an unavailable state due to an outage Net Maximum Capacity NMC NMC is the actual maximum generating capability at the revenue meter and is equal to the installed capacity less any electrical losses These losses may include but are not limited to transformation losses line losses and other auxiliary losses between the turbine and revenue meter NERC GADS W Data Reporting Instructions November 2014 24 Appendix D Terms and Definitions For example if the GIC is 100 MW and the loss is 296 then the NMC can be calculated as 100 MW x 1 0 02 Our NMC is 98 MW IA NMC may also be calculated as follows NMC GIC x E where GAG gt 0 and NAG gt 0 Turbine Net Maximum Capacity TNMC TNMC is the average Net Maximum Capacity of each turbine in the sub group It is calculated by dividing the NMC of the sub group by the number of turbines in the sub group This value is used in equations so that turbine hours and turbine capacity may be used to arrive at a theoretical net max generation When multiple sub groups are being pooled together this value for the pooled set of turbines is equal to the sum of the capacities divided by the sum number of turbines Net Dependable Capacity NDC NDC is the actual generating capability at the revenue meter less capacity losses These losses may include but are not limited to losses from n
93. pment Equivalent Forced Outage Rate EEFOR EEFOR FTH EFDTH 100 X CTH FTH RUTH Notice that the numerator is the same for the factor and rate calculations The denominator is different containing contactor hours low high winds and the hours for the rate we are calculating in this case forced hours See figure K2 NERC GADS W Data Reporting Instructions November 2014 78 Appendix G Outside Management Control Figure K2 Equivalent Forced Outage Rate EFOR Percent of On Line Available m On Line CTH m Lo Hi Wind RUTH m Forced FO m Planned PO m Maintenance MO m OMC E Reserve Shutdown RS EFOR The Whole On Line Available When the value in the denominator is similar between the two equations the results will be similar When large numbers aren t included in the denominator the result can be surprising An example of this is Plant A has 100 turbines and there are 744 hours in the month Therefore PDTH 74 400 hrs The plant will be down the entire month for a planned substation outage Going into the outage there is one turbine on FO Gearbox The gearbox is not repaired during the outage What are equivalent hours At times turbines or systems are not out of service but their capacity is reduced During this time the turbine or system is still accumulating contactor hours The reduced capacity is calculated as equivalent hours and added to the hours in the numerator
94. ps esses 34 SECTION 2 Pooled Resource and Equipment Calculations cccesscccccessssscseceeececessessseeececssesseaeaeeeeeeeseseaees 40 SECTION 3 Resource and Equipment Calculations without OMC Hours essen 45 SECTION 4 Pooled Resource and Equipment Calculations without OMC Hours eese 51 Appendix F Reference Tables nnsennssenssseeresnssesrrenrrsnssenrrsnnsssseennrennsssrnnasssssrrernnanssesreennesssrerreeanssrsreneneassreeennan 59 Appendix G Outside Management Control 64 Appendix H Outage Classification Guidelines esses eene ener sten terrens senes 66 cr r1c pesnc rci 66 Forced Outages FO RR 67 Forced OME EVENTS sz X S 68 Maintenance Events MO ERN 69 Maintenance OMC Events 7 ertet terne inna e p tained ee aie aes 70 ERmuTlqrldudo m EE 70 end UTC 71 Reserve Sh tdOWrr RS cei et repre RE VEER EE e En bee v Ee Cede Ea PRENDE FEE ERR Eege 72 Appendix l Overlapping EVENS icici eiie en e reat NEEN GENANNT eege pun 73 Appendix J Data Quality Control 76 Appendix K Frequently Asked Questions s sssssssessressssesrreenrssssrorresnrsesreesnsenssrsereenssssreeensanssesreeenssnsseeeneanssesreeen 78 What is the difference between a rate EFOR and a factor IFOEIN 78 What are eguivalent hours i noce roe ia ett cde eire e SAA ere ve rere eT Feo e ew a clases Fede nut Feu eva Cede vd EES
95. ration GAG Column 9 Enter the total wind turbine energy generated at the wind turbine for the sub group MWh The Gross Actual Generation is the sum of all individual turbine meters before subtracting station service or auxiliary loads Net Actual Generation NAG Column 10 Enter the net generation MWh recorded at the sub group boundary It is possible to have a negative net actual generation value if the group s station service or auxiliary loads are greater than total generation NERC GADS W Data Reporting Instructions November 2014 11 Chapter 3 Performance Reporting Net Maximum Capacity NMC Column 11 Enter the actual generating capability MW at the sub group boundary This is equal to the installed capacity less any electrical losses such as transformation losses line losses and other losses due to transmission between the turbine and the revenue meter Available Turbine Hours Active Period Turbine Hours PDTH Column 12 Enter the number of turbine hours that the sub group is in the active state PDTH can vary in output reports month year etc but for GADS W reporting purposes data is collected on the number of turbine hours in a month Contact Turbine Hours CTH Column 13 Enter the number of turbine hours the sub group is synchronized to the system It is the turbine hours that the contactors are closed and generation is provided to the grid Reserve Shutdown Turbine Hours RSTH Column 14
96. rature cooling capacity The site dependable capacity varies depending upon the current environment therefore there can be a large difference between the installed capacity and dependable capacity Some of the methods for roll up data into a portfolio metric are NERC GADS W Data Reporting Instructions November 2014 79 Appendix G Outside Management Control Averaging Averaging percentages only works in special situations Even averaging monthly data for the same site can have issues such as different number of days per month and large variations in monthly NCF For monthly single site roll up one of the pooling equations would be better Averaging should not be used Pooling The pooling equations only work when rolling up plants with similar turbine capacities When selecting the pool plants with similar resource characteristics should be selected Generation Generation weighting will work when EFOR is low When EFOR gets above 10 significant errors occur At 100 EFOR there is no generation therefore no weight See Figure K3 This method should be avoided Installed Capacity Installed capacity weighting works but does not take into account the differences in turbine efficiency and plant capability based on resources Net Dependable Energy Net dependable energy is the maximum amount of energy that could be produced based on the resource available This could also be called the entitlement for the project for the speci
97. rbine Hour oPTH OPTH is a sub set of PTH that equals any planned Turbine Hours that were due to causes deemed to be outside of management control For more information on OMC refer to Appendix G Site Available Turbine Hours SATH SAH is the Period Turbine Hours PDTH minus the Resource Unavailable Turbine Hours RUTH Equipment Available Turbine Hours EATH EATH is the sum of the Contact Turbine Hours CTH and Resource Unavailable Turbine Hours RUTH Site Unavailable Turbine Hours GUTH SUTH is the sum of Planned Turbine Hours PTH Forced Turbine Hours FTH Maintenance Turbine Hours MTH and Resource Unavailable Turbine Hours RUTH Equipment Unavailable Turbine Hours EUTH EUTH is the sum of Planned Turbine Hours PTH Forced Turbine Hours FTH and Maintenance Turbine Hours MTH Equivalent Hours Equivalent hours occur when turbine power is reduced from the installed capacity The equivalent hours can be calculated several ways 1 Anindividual turbine s power is reduced Example a 1 5MW turbine is limited to 1 0MW of 10 hrs This is a 33 396 reduction in power so the equivalent outage hours are 10 3 3 33hrs 2 A group of turbines maybe limited in their output Example a 100MW plant is limited to 5SOMW This is a 50 restriction so 50 of the hours during the period are equivalent outage hours 10 turbines for 8 hrs equal 80 hrs total times 5096 equals 40 equivalent outage hours NERC GADS W
98. rbox 1064 System Component Entry General 665 Aerodynamic Brake Tip Brakes amp Spoilers 602 Blade Pitch Bearing 603 Blades 600 Deicing Systems 604 Rotor Hub 601 Lightning Protection 605 Nose Cone 606 Blade Coatings 1065 Blade Attachments System Component Entry General 664 FAA Lighting 598 Foundations 595 MASS Harmonic Damp 599 Nacelle 593 Structures Nacelle Heating amp Cooling 597 Paint amp Coatings 596 Towers 594 Ladders 1066 Climb Assist Elevator 1067 Tower Filtration 1068 NERC GADS W Data Reporting Instructions November 2014 22 Appendix C System Component Codes Lighting 1069 Hoist 1070 System Component Entry General 663 Slew Ring 620 Yaw Dampening 622 Yaw Gear 621 Yaw System Yaw Lubrication Systems 623 Yaw Motors Hydraulics 619 System Component Entry General 1032 Wind Turbine Preventative Maintenance 1031 Overall 1033 System Component Entry General 1071 Operator 1072 Maintenance 1073 P aed Contractor 1074 errormance Procedure Error 1075 NERC GADS W Data Reporting Instructions November 2014 23 Appendix D Terms and Definitions General Revenue Meter The revenue meter is a device used to measure the electricity generated from a plant group or sub group depending on the plant configuration The revenue meter accounts for the electricity sold to the customer and is normal
99. re changed to optional Defined Turbulence Intensity Change column 12 changed Make to Model Change column 13 changed from Model to Version Defined Wind Shear Added reference Anemometer Height e Performance Reporting Record Changes Deleted data columns 25 30 Added derate terms columns 31 35 Added delay terms columns 36 38 Optional e Component Outage Reporting Added derate terms columns 15 17 Added delay terms columns 18 20 e Appendix A GADS W Data Release Guidelines Revised to focus on GADS W Added a section outlining the data request process e Appendix B Utility Identification Codes Codes moved to NERC Web site Added the procedure for getting a new NERC Utility Code e Appendix C System Component Codes Balance of Plant o Change 650 Feeder Collection changed to Underground o Added 1037 Breaker NERC GADS W Data Reporting Instructions November 2014 83 Appendix G Outside Management Control o Added 1038 Main Substation Transformer o Added 1039 Switches o Added 1040 Wave Trap o Added 1041 CT PT Current Transformer Potential Transformer o Added 1042 Battery Systems o Added 1043 Site Communication o Added 1044 Fuses o Added 1075 Transmission Gen Tie Brake o Added 1045 Brake Hydraulic System Control System o Moved 641 Rotor Current Control RCC moved to Generator o Added 1046 Hardware o Added 1047 Power Supply o Added
100. riod being reported Equivalent Planned Derated Turbine Hours Column 17 Enter the total number of equivalent planned outage hours that are attributed to the system component specified above during the period being reported NERC GADS W Data Reporting Instructions November 2014 16 Chapter 4 Component Outage Reporting Forced Delay Turbine Hours Column 18 Optional Enter the total number of equivalent forced delay outage hours that are attributed to the system component specified above during the period being reported Maintenance Delay Turbine Hours Column 19 Optional Enter the total number of equivalent maintenance delay hours that are attributed to the system component specified above during the period being reported Planned Delay Turbine Hours Column 20 Optional Enter the total number of equivalent planned delay hours that are attributed to the system component specified above during the period being reported NERC GADS W Data Reporting Instructions November 2014 17 Appendix A GADS W Data Release Guidelines I ntroduction NERC Wind Generating Availability Data System GADS W contains information which can be broadly classified into five categories plant group sub group component outage and performance data The plant group and sub group data is unrestricted and available to power generators manufacturers and equipment suppliers architect engineers and consultants industry organizations EEI EPR
101. rting Hours or Performance files This happens when the entered year is earlier than 1980 or greater than the current year or if the entered period month is not within the range of 1 12 Invalid System This happens when the System Identifier does not match any found within the program No Name or Description This error may occur when importing sub group Group or Plant files This happens when the name description field is blank in the incoming CSV file NERC GADS W Data Reporting Instructions November 2014 77 Appendix K Frequently Asked Questions What is the difference between a rate EFOR and a factor FOF The difference between rates and factors is often confusing Under normal operating conditions the results of the two types of calculations will give similar results but may vary widely during various outage conditions A factor is defined as a percent of the whole Equation 1 B 5 Equipment Equivalent Forced Outage Factor EEFOF FTH EFDTH 100 gt X PDTH Notice the denominator in the equation is all the hours the whole pie See figure K1 Figure K1 Forced Outage Factor FOF Percent of the Whole B On Line CTH m Lo Hi Wind RUTH m Forced FO m Planned PO m Maintenance MO E OMC E Reserve Shutdown RS The Whole FOF Note OMC Out of Management Control A rate is defined as a percent of the available hours Equation 1 B 12 Equi
102. s oF TH oMTH oPTH DeratedOMCHrs oEFDTH oEMDTH 0EPDTH OutageHrs DeratedHrs OMCHrs DeratedOM CHrs XEEUF x100 PDTH 100 XEEAF 3 B 3 OMC Equipment Equivalent Planned Outage Factor XEEPOF 26 of period that the WTG equipment was in planned downtime ER PTH EPDTH oPTH 0EPDTH den PDTH 3 B 4 OMC Equipment Equivalent Maintenance Outage Factor XEEMOF of period that the WTG equipment was in maintenance downtime MTH EMDTH oMTH 0EMDTH XEEMOF x 100 PDTH NERC GADS W Data Reporting Instructions November 2014 49 Appendix E Performance Equations 3 B 5 OMC Equipment Equivalent Forced Outage Factor XEEFOF of period that the WTG equipment was forced off line Including low and high winds DE FTH EFDTH oFTH 0EFDTH T PDTH 3 B 6 OMC Equipment Equivalent Unplanned Outage Factor XEEUOF 26 of period that the WTG equipment was unavailable due to forced and maintenance downtime For generation resource planning UOHrs FTH MTH UDerateOHrs EFDTH EMDTH UOMCHrs oFTH oMTH UOMCDerateHrs oEFDTH o0EMDTH Wu OHrs UDerateOHrs UOMCHrs UOM CDerateHrs PDTH XEEOUF x 100 3 B 7 OMC Equipment Equivalent Scheduled Outage Factor XEESOF of period that the WTG equipment was unavailable due to maintenance and planned downtime SOHrs PTH MTH SODerateHrs EPDTH EMDTH SOMCHrs oPTH oM
103. s November 2014 63 Appendix G Outside Management Control Outside Management Control OMC events occur beyond the wind plant boundaries Interconnect or are caused by abnormal weather These types of events are currently categorized into Weather Off Taker Planned and Off Taker Unplanned downtime categories Equations with and without OMC are included for both resource and equipment equations OMC events can be Planned Maintenance Forced Outage or Derating Events The following excerpt is from the GADS Data Reporting Instructions Appendix K The electric industry in Europe and other parts of the world has made a change to examine losses of generation caused by problems with and outside plant management control After reviewing the work used by others the following is provided as guidelines for determining what is and is not outside plant management control There are a number of outage causes that may prevent the energy coming from a power generating plant from reaching the customer Some causes are due to the plant operation and equipment while others are outside plant management control It may be assumed that all problems within the power station boundary are within plant management control however this is not always the case Therefore there is a need for some additional clarification as to what is and what is not under plant management control It is easier to identify actions outside plant management control than to iden
104. s and Definitions Relationships Between Types of Hours amp Capacity N Reserve Shutdown Outages and Derations Time Figure D 3 NERC GADS W Data Reporting Instructions November 2014 32 Appendix D Terms and Definitions j I ECTS61400 26 1 OR IEEE 762 Time Based Availability NERC Cross Reference Non Operative IANO Unavailable li git zy ofc pee FE Figure D 4 Cross Reference NERC GADS W Data Reporting Instructions November 2014 33 Appendix E Performance Equations Four different sets of performance equations will be listed in the following sections A short description of these sections is listed below 1 Resource and Equipment Calculations These equations calculate the individual resource and equipment performance by turbine sub group s that have similar turbine capacities These equations also include OMC hours Pooled Resource and Equipment Calculations These equations pool the resource and equipment performance of sub groups into collections of sub groups groups or plants These equations also include OMC hours These equations are not weighted and should only be used for pooling data with turbines of the same turbine capacity Resource and Equipment Calculations without OMC Hours These equations calculate the individual resource and equipment performance by turbine sub group s that have the same or very similar turbine capacities These equati
105. t boundaries There are a number of outage causes that may prevent the energy coming from a power generating plant from reaching the customer Some causes are due to the plant operation and equipment while others are outside plant management control The following describes what equipment a generating unit includes in preferred order 1 The preferred plant boundary at the revenue meter is usually at the high voltage terminals of the generator step up GSU transformer and the station service transformers NERC GADS W Data Reporting Instructions November 2014 2 Chapter 2 Plants Groups and sub groups 2 In cases of multiple sub groups the plant boundary would be at the metering of the low side of the substation transformer load side of the generator voltage circuit breakers 3 Any equipment boundary that is reasonable considering the design and configuration of the generating unit Plants A plant is defined as a collection of wind turbine groups at a single physical location There may be any number of wind turbine groups at a wind plant You only need to provide the plant data to NERC initially when you begin to report data for each plant or anytime any changes to the plant are made Plant Record Layout CSV Format Table 1 Plant Record Layout Column Field Name Entry Type 1 Plant ID Alpha Numeric 10 2 Plant Name Alpha Numeric 45 Plant ID Column 1 With help from NERC staff enter a uniqu
106. t is not maintained by the plant such as opacity out of limits or NOx out of control etc then plant management should be penalized These are equipment problems and are within plant management control Lack of fuels water from rivers or lakes coal mines gas lines etc where the operator is not in control of contracts supply lines or delivery of fuels However if the operator elected to contract for fuels where the fuel for example natural gas can be interrupted so that the fuel suppliers can sell the fuels to others part of the plant fuel cost saving measure then the lack of fuel is under management control and is not applicable to this case Labor strikes Outages or load reductions caused by labor strikes are not normally under the direct control of plant management The strikes are within manufacturer companies and transportation companies However direct plant management grievances that result in a walkout or strike are under plant management control and are included as penalties against the plant If a labor strike is caused by plant management worker problems during an outage any outage extensions are included as energy losses as long as the unit is incapable of being restarted because of equipment failures maintenance overhauls or other activities Other weather related problems such as seasonal variations in gross dependable capacity due to cooling water temperature variations are not under plant management control
107. that is not operable or is not capable of operation at a moment s notice must be on a forced maintenance or planned outage and remain on that outage for at least 60 days before it can be moved to the MB state If repairs are being made on the group in order to restore the group to operating status before the 60 day period expires then the outage must remain a forced maintenance or planned outage and not MB If group repairs for restoring the group to operation are made after the 60 day period then the first 60 days must be a forced maintenance or planned outage and the time after the 60 days including the repair time on the group up to operation shall be the MB event Turbine States and Hours Collection Given the nature of wind generation it would be a very rare occurrence for every turbine in a group or even a sub group to be found in the same state Therefore due to the hours that turbines spend in various conditions NERC GADS collects hours as turbine hours to enable NERC to calculate meaningful statistics Using turbine hours allows the operator to report hours simply by adding up the hours reported by each turbine NERC GADS W Data Reporting Instructions November 2014 26 Appendix D Terms and Definitions Calendar Hours CalTH Inactive Hours ITH Mothballed MBTH Unavailable SUTH or EUTH Available SATH or EATH Reserve Unplanned Planned Outages Shut
108. this case An example of this would be a failed gearbox FO Several days later the Off Taker takes a 2 week maintenance outage OMC MO The gearbox remains FO until the repair is completed and then becomes part of the OMC MO NERC GADS W Data Reporting Instructions November 2014 66 Appendix G Outside Management Control Forced Outage FO An unplanned outage that usually results from a mechanical electrical hydraulic control system trip or an operator initiated trip in response to a unit alarm The turbine is not capable of running under the MO rules 1 10 Component failures Most FOs will be component failures that require replacement and or repair Examples are towers generators controllers loose wire amp etc Trips or faults These remove the turbine from availability until corrected Examples are overproduction vibration etc Events that are part of normal operation like cable untwisting and battery testing are considered as available hours RUTH Condition Assessment Sometimes failing components are identified through condition assessment If the component fails before the repair or replacement occurs it is FO For example a high speed gearbox bearing is overheating and is scheduled for replacement If the bearing fails before the scheduled replacement time the outage is FO Balance of Plant BOP components like underground cabling failure can cause FO BOP failures often have parallel and undam
109. tify the responsibilities of plant management Therefore the following are considered to be outside external of plant management control All other items are considered within their jurisdiction and are the responsibility of the plant management for calculating power plant performance and statistics Energy losses due to the following causes should not be considered when computing the unit controllable performance because these losses are not considered to be under the control of plant management e Grid connection or substation failure is not under management control This relates to problems with transmission lines and switchyard equipment outside the boundaries of the plant as specified by the boundary of plant responsibility shown in Figure 3 1 e Acts of nature such as ice storms tornados winds lightning etc are not under plant management control whether inside or outside the plant boundary e Terrorist attacks on the generating transmission facilities or transmission operating repair errors are not under plant management control e Special environmental limitations such as low cooling pond level or water intake restrictions that could not be prevented by operator action These are acts of nature such as high ambient temperatures where the equipment is working within design specifications However if the NERC GADS W Data Reporting Instructions November 2014 64 Appendix G Outside Management Control equipmen
110. tions Maintenance Turbine Hour MTH MTH is the sum of all turbine hours that the sub group is off line due to a Maintenance Event A maintenance event is an event that can be deferred beyond the end of the next weekend Sunday at 2400 but requires that a wind turbine be removed from service another outage state or Reserve Shutdown state before the next Planned event Characteristically a maintenance event can occur at any time during the year has a flexible start date may or may not have a predetermined duration and is usually much shorter than a Planned Event If an event occurs before Friday at 2400 the above definition applies If the event occurs after Friday at 2400 and before Sunday at 2400 the Maintenance event will only apply if the event can be delayed past the next weekend not the current one If the event cannot be deferred it is a Forced Event Examples can be found in Appendix H OMC Maintenance Turbine Hour oMTH OMTH is a sub set of MTH that equals any maintenance Turbine Hours that were due to causes deemed to be outside of management control OMC For more information on OMC refer to Appendix G Examples can be found in Appendix H Planned Turbine Hour PTH PTH is the sum of all Turbine Hours that the sub group is off line due to a planned event A Planned Event is scheduled well in advance and is of predetermined duration and can occur several times a year Examples can be found in Appendix H OMC Planned Tu
111. tive equipment s operating specifications are exceeded then the event is OMC b Ice on HV equipment causing tracking line slaps or equipment failures c Safety shut downs for turbines shedding ice on highways 5 Weather Lightning OMC If the turbines had lightning protection but the protection failed the event is FO If the turbines lacked protection then it is OMC Code this as External Weather Lightning OMC Lightning can strike anywhere on the turbine but the blades and nacelle usually have lightning protection When considering lightning strikes evaluate whether the protection work as claimed or if it was overwhelmed There are devices and services that can help determine the magnitude of a lightning strike and if the equipment worked properly The electrical distribution system is more often struck by lightning then the blades and nacelle and just as with the blades and nacelle only label an outage as OMC if the equipment lacked protection 6 Weather Temperature OMC Wind turbines have high and low ambient temperature limitations When these limits are exceeded the turbine will shut down Code this as External Temperature OMC NERC GADS W Data Reporting Instructions November 2014 68 Appendix G Outside Management Control Communication OMC Many Off Taker s ISO s and other groups require full time communication with the wind plant s SCADA systems When communication is lost with the site the pla
112. uivalent Planned Derated Hours Numeric 8 2 decimals 18 Forced Delay Hours Optional Numeric 8 2 decimals 19 Maintenance Delay Hours Optional Numeric 8 2 decimals 20 Planned Delay Hours Optional Numeric 8 2 decimals Plant I D Column 1 Enter the Plant ID as previously defined Group I D Column 2 Enter the Group ID as previously defined Sub Group I D Column 3 Enter the sub group ID as previously defined NERC Utility Code Column 4 Enter the three character alpha numeric code NERC assigned to your utility See Appendix B NERC Unit Code Column 5 Enter the three character alpha numeric code your utility assigned for the plant that you are reporting This code distinguishes one plant from another in your utility See Appendix B Report Period Column 6 Enter the two digit month MM in which the event occurred See Appendix F Table 8 NERC GADS W Data Reporting Instructions November 2014 15 Chapter 4 Component Outage Reporting Report Year Column 7 Enter the four digit year YYYY in which the event occurred System Component Code Column 8 Enter the system that was responsible for the outage See Appendix C for a complete list of the system component codes Component Turbine Hours and Occurrences Forced Turbine Hours Column 9 Enter the total number of forced turbine hours for the reporting sub group that are attributed to the system component specified above during t
113. umber of delay hours during one period month See definitions for a clear definition Planned Delay Turbine Hour PXDTH Column 40 Optional Total number of delay hours during one period month See definitions for a clear definition NERC GADS W Data Reporting Instructions November 2014 14 Chapter 4 Component Outage Reporting The component outage reporting section is used to identify the general area or reason for WTG loss production as reported in the performance records at the sub group level To be accurate the sum of the component turbine hours must equal the turbine hours shown in the performance records Component Record Layout CSV Format Column Field Name Entry Type 1 Plant ID Alpha Numeric 10 2 Group ID Alpha Numeric 10 3 Sub Group ID Alpha Numeric 10 4 NERC Utility Code Alpha Numeric 3 5 NERC Unit Code Alpha Numeric 3 6 Report Period month Numeric 2 7 Report Year Numeric 4 8 System Component Code Numeric 14 9 Forced Turbine Hours Numeric 8 2 decimals 10 Number of Forced Occurrences Numeric 14 11 Maintenance Turbine Hours Numeric 8 2 decimals 12 Number of Maintenance Occurrences Numeric 14 13 Planned Turbine Hours Numeric 8 2 decimals 14 Number of Planned Occurrences Numeric 14 15 Equivalent Forced Derated Hours Numeric 8 2 decimals 16 Equivalent Maintenance Derated Hours Numeric 8 2 decimals 17 Eq
114. urisdiction that will be required to provide the data or information reporting entities iv the schedule or due date for the data or information v a description of any restrictions on disseminating the data or information e g confidential critical energy infrastructure information aggregating or identity masking and vi an estimate of the relative burden imposed on the reporting entities to accommodate the data or information request A proposed modification to a previously authorized request for data or information shall explain i the nature of the modifications ii an estimate of the burden imposed on the reporting entities to accommodate the modified data or information request and iii any other items from paragraph 1 1 that require updating as a result of the modifications After the close of the comment period NERC shall make such revisions to the proposed request for data or information as are appropriate in light of the comments NERC shall submit the proposed request for data or information as revised along with the comments received NERC s evaluation of the comments and recommendations to the Board of Trustees In acting on the proposed request for data or information the Board of Trustees may authorize NERC to issue it modify it or remand it for further consideration NERC may make minor changes to an authorized request for data or information without board approval How
115. ust be reported to other agencies such as the EIA EPA Nearest City Column 11 Enter the name of the nearest major city closest in proximity to the group State Province Column 12 Using Tables 1 amp 2 in Appendix F enter the two letter State Province abbreviation where the group is located Longitude Column 13 Enter the degrees of longitude of the physical location of the group Latitude Column 14 Enter the degrees of latitude of the physical location of the group Elevation Column 15 Enter the elevation of the physical location of the group given in meters Wind Site Characteristics Wind Regime Column 16 Using Table 3 in Appendix F enter the average topography of the area in which the group is located Annual Average Wind Speed Column 17 Enter the annual average wind speed AAWS at 80 m measured in meters per second SCADA System Column 18 Column 18 is left intentionally blank The degrees of longitude latitude and elevation may be taken anywhere on the site that is meaningful to the reporting entity This could be the revenue meter main structure or geographic center of the group NERC GADS W Data Reporting Instructions November 2014 6 Chapter 2 Plants Groups and sub groups SCADA Manufacturer Column 19 Using Table 4 in Appendix F enter the manufacturer of the SCADA system We recommend that all values reported to NERC match any values that also must be reported to other
116. vided in a timely fashion to assess projected bulk power system reliability and analyze its ongoing performance for individual regional and interconnection wide planning In the coming years the evolution in resource mix will require the industry to gain experience with technology behavior operating characteristics and optimal planning approaches in order to properly assess the reliability and improve performance analysis As new technologies are integrated on the bulk power system a complete set of plant group sub group component outage and performance power plant data including wind generation will be critical to ensure bulk power system reliability The need for GADS W data is required for the following NERC and Regional Entity activities e Reliability Assessment reports and modeling e Loss of load Expectation studies and modeling t NERC s Rules of Procedure are available at http www nerc com files NERC Rules of Procedure EFFECTIVE 20111117 pdf 3353 Peachtree Road NE Suite 600 North Tower Atlanta GA 30326 404 446 2560 www nerc com RELIABILITY ACCOUNTABILITY e As renewable generation becomes a greater percentage of the resource mix in North America NERC and its stakeholders need to understand how resource availability and performance impacts Planning Reserve Margin calculations e Actual wind generator performance data is needed to continue to refine the severity risk index to establish the effect that w
117. y captured in the denominator Also note that the hours are based on the reduction in capacity and do not depend upon the wind resource If individual turbines are turned off to meet the capacity reduction then they are treated as regular outages PO MO amp FO Below are a few examples 1 Equipment Deterioration A turbine has a deteriorating main bearing Engineering has determined that they can extend the life of the bearing by running at reduced load Turbine output is reduced from 1 0MW to 0 8MW until repairs can take place This is a 20 reduction in maximum capacity so 20 of the hours would be coded as Drive Train Main Bearing EFDTH 2 Partial Equipment Failure 1 of 4 parallel underwater feeder cables to an island fail limiting output from the plant There are 2 ways that the Equivalent hours are calculated a 75 of the capacity of the lines is available Therefore 25 of the hours would be coded as Balance of Plant Underground EFDTH b Alternatively an engineer could calculate the remaining capacity based on the cable specifications If the remaining 3 cables can handle 85 of the capacity 15 of the hours would be coded as Balance of Plant Underground EFDTH 3 Off Taker Constraints An Off Taker limits plant output due to line congestion This is coded as External Off Taker OMC EFDTH The following are examples a The Off Taker limits plant output 50 Therefore 50 of the hours are OMC EFDTH b The Off T

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