GADS Wind Turbine Generation Data Reporting Instructions

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Effective January 2010

Version 1.1.0

Table of Contents

Section 1 – Introduction ...... 7 Who Must Report ...... 7 Terms, Definitions, and Equations...... 7 Data Release Guidelines ...... 8 Talk to Us ...... 8

Section 2 – Data Transmittal and Format ...... 9 Transmittal ...... 9 Format ...... 9 Wind Generation Data Entry Software ...... 10 Questions and Comments ...... 10

Section 3 – Plants, Groups, and Sub-Groups ...... 11 Plants ...... 11 Plant Record Layout (CSV Format) ...... 11 Groups ...... 12 Group Record Layout (CSV Format) ...... 13 Location ...... 14 Wind/Site Characteristics...... 16 SCADA System ...... 16 Sub-Groups ...... 17 Sub-Group Record Layout (CSV Format) ...... 18 Typical Design ...... 19 Turbine Wind Class ...... 20 Plant Boundaries ...... 21

Section 4 – Performance Reporting...... 23 Performance Record Layout (CSV Format) ...... 23 Capacity and Generation ...... 25 Available Turbine Hours (Active) ...... 25 Unavailable Turbine Hours (Active) ...... 25 Outside Management Control - OMC (Active) ...... 26 Other ...... 26 Turbine Hours (Inactive)...... 26 Calculated Turbine Hours (Optional) ...... 27

Section 5 – Component Outage Reporting ...... 29 Component Record Layout (CSV Format) ...... 29 Turbine Hours and Occurrences ...... 30

GADS WTG Data Reporting Instructions – January 2010 3 Table of Contents

Appendix A – GADS Data Release Guidelines...... 31 Introduction ...... 31 Data Release Guidelines ...... 31 Power Generator Representatives ...... 31 Manufacturers and Equipment Suppliers ...... 32 Architect-Engineers and Consultants ...... 32 Industry Organizations (EEI, EPRI, INPO, etc.) ...... 32 Federal Governmental Organizations ...... 32 State and Local Governmental Organizations ...... 32 Non-Industry Organizations...... 33 Foreign Correspondents ...... 33 Subsequent Use of Data ...... 33 Responding to Requests ...... 33

Appendix B – Utility and Unit Identification ...... 35 Utility Identification Codes...... 35 Unit Identification Codes ...... 35 Non-Regional Member Utilities ...... 36 Northeast Power Coordinating Council (NPCC) ...... 38 ReliabilityFirst Corporation (RFC) ...... 42 SERC Reliability Corporation (SERC) ...... 47 Florida Reliability Coordinating Council (FRCC) ...... 49 Midwest Reliability Organization (MRO) ...... 50 Southwest Power Pool (SPP) ...... 52 Texas Regional Entity (TRE)...... 53 Western Electricity Coordinating Council (WECC)...... 54

Appendix C – System-Component Codes ...... 57 Appendix D – Terms and Definitions ...... 61 Capacity and Generation ...... 61 Group or Sub-Group States ...... 62 Turbine States and Hours Collection ...... 63 Priority of Outage Reporting ...... 68

Appendix E – Performance Equations ...... 71 SECTION 1: Resource and Equipment Calculations (for sub-groups) ...... 72 Resource Performance Factors ...... 72 Resource Performance Rates ...... 73 Equipment Performance Factors ...... 74 Equipment Performance Rates ...... 75

4 GADS WTG Data Reporting Instructions – January 2010 Table of Contents

SECTION 2: Pooled Resource and Equipment Calculations ...... 77 Pooled Performance Factors ...... 77 Pooled Performance Rates ...... 79 Pooled Equipment Performance Factors ...... 80 Pooled Equipment Performance Rates...... 81

SECTION 3: Resource and Equipment Calculations without OMC Hours ...... 83 Performance Factors (including resources without OMC hours) ...... 83 Performance Rates (including resources without OMC hours) ...... 84 Equipment Performance Factors (without OMC hours) ...... 85 Equipment Performance Rates (without OMC hours) ...... 85

SECTION 4: Multi-Resource and Multi-Equipment Calculations without OMC Hours ...... 87 Pooled Performance Factors (including resources without OMC hours) ...... 87 Pooled Performance Rates (including resources without OMC hours) ...... 88 Pooled Equipment Performance Factors (without OMC hours) ...... 89 Pooled Equipment Performance Rates (without OMC hours) ...... 90

Appendix F – Manufacturers ...... 93 Appendix G – Outside Management Control ...... 95 Appendix H – Examples ...... 97 Forced Events: ...... 97 Forced OMC Events: ...... 97 Maintenance Events: ...... 98 Planned Events: ...... 98

GADS WTG Data Reporting Instructions – January 2010 5 Table of Contents

6 GADS WTG Data Reporting Instructions – January 2010 Section 1 – Introduction

Section 1 – Introduction

These GADS Wind Turbine Generation (WTG) - Data Reporting Instructions were developed to assist utility personnel in reporting information to the North American Electric Reliability Corporation’s (NERC) WTG database. These instructions detail the procedures, format, and frequency to follow when reporting data to the wind turbine database.

Who Must Report

GADS is a voluntary industry program, open to all participants in the Regional Entities (shown in Figure 1-1) and any other organization (domestic or international) that operate wind turbine generating facilities. Although GADS is a voluntary program, participating organizations must be prepared to commit the necessary effort to provide timely, accurate, and complete data. These reporting instructions detail the data elements collected by GADS and have been identified by the industry as being vital to the understanding and interpretation of wind turbine performance.

Figure 1-1 Regional Entities

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

RFC WECC ReliabilityFirst Corporation Western Electricity Coordinating Council

Terms, Definitions, and Equations

The terms, definitions, and equations used throughout this manual can be found in Appendix D & E.

GADS WTG Data Reporting Instructions – January 2010 7 Section 1 – Introduction

Data Release Guidelines

The GADS Data Release Guidelines can be found in Appendix A of this manual.

Talk to Us

If you have enhancement ideas, feature requests, or specific comments about this manual, we want to hear from you.

Please send your suggestions to Joanne Rura at [email protected].

8 GADS WTG Data Reporting Instructions – January 2010 Section 2 – Data Transmittal and Format

Section 2 – 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, the plant, group, and sub-group data for each plant must be reported to the GADS database. The plant, group, and sub-group data only needs to be provided once when you begin reporting data for each plant and when the characteristics of the plant change. Although, we strongly recommend that all five of the files above be reported with each quarterly submittal. This data provides information regarding installed equipment design and operating characteristics of the plant that are used in special analysis as sorting criteria. In addition, component outage and performance data cannot be verified without this data so it must be submitted before you report any component outage and performance data.

Once the plant, group, and sub-group data have been reported to the GADS database you can begin to report the component outage and performance data. The component outage and performance data should be submitted to GADS within 30 days after the end of every calendar quarter to [email protected]. These data should be reported throughout 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. Be sure all values are not formatted with any punctuation other than a decimal point and slashes used in dates. (Example: numbers with embedded commas can cause problems such as 12,000.25. This 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. The Plant ID should also be included to the file name. Plant ID’s are discussed in Section 3.

GADS WTG Data Reporting Instructions – January 2010 9 Section 2 – Data Transmittal and Format

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/

Questions and Comments

All questions regarding data transmittals and reporting procedures should be directed to:

G. Michael Curley 801-756-0972 Manager of GADS Services 801-756-0973 Fax

Joanne M. Rura 609-524-0613 GADS Services Coordinator 609-452-9550 Fax

10 GADS WTG Data Reporting Instructions – January 2010 Section 3 – Plants, Groups, and Sub-Groups

Section 3 – Plants, Groups, and Sub-Groups

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. The plant data only needs to be provided to NERC once when you begin to report data for each plant.

Plant Record Layout (CSV Format)

Column Field Name Entry Type 1 Plant ID Alpha-Numeric - 10 2 Plant Name Alpha-Numeric - 45

Plant ID (Column 1) Enter a unique 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) Enter a unique name, which may be more descriptive than the Plant ID, given to the plant that you are reporting.

GADS WTG Data Reporting Instructions – January 2010 11 Section 3 – Plants, Groups, and Sub-Groups

Groups

A group is one or more sub-groups that are connected to a common revenue meter. There may be any number of groups per wind plant. 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. This ID is assigned by the reporting utility.

Wind Turbine Group Groups report the following site data:

• Associated Plant Identifier • Turbine Group ID • Turbine Group Name • NERC Utility Code • NERC Unit Code • Installed Capacity in MW • Auxiliary Capacity • Commercial Date • Nearest City, State • Location Longitude and Latitude • Elevation • Wind Regime (topography) • SCADA Type • SCADA Manufacturer • SCADA Model

Revenue Meter The revenue meter is a device use to measure the electricity generated from a group. The revenue meter accounts for the electricity sold to the customer and is normally owned by the customer.

12 GADS WTG Data Reporting Instructions – January 2010 Section 3 – Plants, Groups, and Sub-Groups

Group Record Layout (CSV Format)

Column Field Name Entry Type 1 Plant ID Alpha-Numeric - 10 2 Group ID Alpha-Numeric - 10 3 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 Capacity Numeric - 8 + 2 decimals 8 Auxiliary Capacity Numeric - 8 + 2 decimals 9 Commercial Date (MM/DD/YYYY) Alpha-Numeric -10 10 Country Alpha-Numeric - 2 11 Nearest City Alpha-Numeric - 40 12 State/Province Alpha-Numeric - 2 13 Longitude Numeric - 4 + 4 decimals 14 Latitude Numeric - 3 + 4 decimals 15 Elevation Numeric - 8 + 2 decimals 16 Wind Regime Numeric - 3 17 Annual Average Wind Speed (AAWS) Numeric – 3 + 2 decimals 18 SCADA Type Alpha-Numeric - 10 19 SCADA Manufacturer Alpha-Numeric - 5 20 SCADA Model Alpha-Numeric - 10

Plant ID (Column 1) Enter a unique ID to the plant that you are reporting. This ID is referenced in all groups, sub- groups, performance, and component data existing under the plant.

Group ID (Column 2) Enter a unique ID to the group that you are reporting. This ID is referenced in all sub-groups, performance data, and hours’ 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 complete list of the utilities participating in GADS and their assigned 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.

ISO Resource ID (Column 6) Enter the unique identifier given to the group by the ISO.

GADS WTG Data Reporting Instructions – January 2010 13 Section 3 – Plants, Groups, and Sub-Groups

Capacity (Column 7) Enter the total capacity for the entire group, measured in megawatts (MW).

Auxiliary Capacity (Column 8) Enter the combined capacities for all the auxiliary turbines not normally connected, and not part of GIC, measured in megawatts (MW).

Commercial Date (Column 9) Enter the date (MM/DD/YYYY), that the group came online and entered into active status.

Location

Country (Column 10) From the table below, enter the two-letter country abbreviation where the group is located.

Country Name Abbreviation Canada CA Mexico MX United States US

Nearest City (Column 11) Enter the name of the city closest in proximity to the group.

State /Province (Column 12) From the tables below, enter the two-letter state/province abbreviation where the group is located.

United States Name Abb. Name Abb. Name Abb. Alabama AL Louisiana LA Ohio OH Alaska AK Maine ME Oklahoma OK Arizona AZ Maryland MD Oregon OR Arkansas AR Massachusetts MA Pennsylvania PA California CA Michigan MI Rhode Island RI Colorado CO Minnesota MN South Carolina SC Connecticut CT Mississippi MS South Dakota SD Delaware DE Missouri MO Tennessee TN Florida FL Montana MT Texas TX Georgia GA Nebraska NE Utah UT Hawaii HI Nevada NV Vermont VT Idaho ID New Hampshire NH Virginia VA Illinois IL New Jersey NJ Washington WA Indiana IN New Mexico NM West Virginia WV Iowa IA New York NY Wisconsin WI Kansas KS North Carolina NC Wyoming WY Kentucky KY North Dakota ND

14 GADS WTG Data Reporting Instructions – January 2010 Section 3 – Plants, Groups, and Sub-Groups

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 QC Newfoundland and Labrador NL Saskatchewan SK

Mexico Name Abb. Name Abb. Name Abb. Aguascalientes AG Guerrero GR Quintana Roo QR Baja California BC Hidalgo HG San Luis Potosi SL Baja California Sur BS Jalisco JA Sinaloa SI Campeche CP Mexico EM Sonora SO Chiapas CH Michoacan 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

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.

Note: 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. The purpose of these entries is to get an approximate location of the group to help distinguish it from other groups, and to relate it to other groups as a common latitude or elevation.

GADS WTG Data Reporting Instructions – January 2010 15 Section 3 – Plants, Groups, and Sub-Groups

Wind/Site Characteristics

Wind Regime (Column 16) From the table below, select the average topography of the area in which the group is located.

Wind Regime Entry Seashore 1 Plain 2 Plateau 3 Hills 4 Mountain 5 Ridge 6

Annual Average Wind Speed (Column 17) Enter the annual average wind speed (AAWS) at 80m, measured in meters per second.

SCADA System

SCADA Type (Column 18) From the table below, select the type of SCADA system being used.

SCADA Type Entry Analog 1 Digital 2 IP 3 Ethernet 4 Frame Relay 5 Private Wire 6 56Kbps DDS 7

SCADA Manufacturer (Column 19) From the table below, select the manufacturer of the SCADA system.

SCADA Manufacturer Entry Emerson ES Garrad Hassan GH General Electric Co. GE Horizon Wind Energy HWE Mita-Teknik MTK Scadabase SCB Second Wind SC Vestas VES

SCADA Model (Column 20) Enter the model name of the SCADA system.

16 GADS WTG Data Reporting Instructions – January 2010 Section 3 – Plants, Groups, and Sub-Groups

Sub-Groups

A sub-group is a collection of wind turbine machines with the same manufacturer, designs, model number, and phase of construction. This data collection is a one-time event and it is strongly encouraged to follow the recommended guidelines mentioned. Each sub-group will have a unique identifier and be associated with its parent group. Component outage and performance data will be collected at this level.

For example, suppose that your wind turbine group consisted of 12 Vestas V-27 machines constructed in the year 2000, 20 Vestas V-27 machines constructed in the year 2003, and 24 Vestas V-47 machines constructed in the year 2005. Each of the previous groupings of machines would be considered its own sub-group under the same group.

Wind Turbine Sub-Group Sub-groups report the following design data:

. Turbine Group ID . Turbine Sub-Group ID . Sub-Group Name . Commissioning Year . Typical Turbine Capacity . Total Turbines . Manufacturer . Make . Model . Rotor Height and Diameter . Cut-in and Cut-out Wind Speed . Turbine Wind Class . Turbulence . Wind Speed Range . Wind Shear

GADS WTG Data Reporting Instructions – January 2010 17 Section 3 – Plants, Groups, and Sub-Groups

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 5 NERC Unit Code Alpha-Numeric - 3 6 Sub-Group Number Numeric - 3 7 Sub-Group Name Alpha-Numeric - 45 8 Commissioning Year Numeric - 4 9 Typical Nameplate Capacity Numeric - 3 + 3 decimals 10 Total Number of Turbines Numeric - 7 11 Manufacturer Alpha-Numeric - 5 12 Make Alpha-Numeric - 20 13 Model 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) Numeric - 7 + 2 decimals 17 Low Cut-out Wind Speed (meters/second) Numeric - 7 + 2 decimals 18 High Cut-out Wind Speed (meters/second) Numeric - 7 + 2 decimals 19 Turbulence Numeric - 3 20 Wind Speed Range Numeric - 3 21 Wind Shear Numeric - 3

Plant ID (Column 1) Enter a unique ID to the plant that you are reporting. This ID is referenced in all groups, sub- groups, performance, and component data existing under the plant.

Group ID (Column 2) Enter a unique ID to the group that you are reporting. This ID is referenced in all sub-groups, performance data, and hours data existing under the group.

Sub-Group ID (Column 3) Enter a unique ID to the sub-group that you are reporting. This ID is referenced in all performance and component data existing under the sub-group.

18 GADS WTG Data Reporting Instructions – January 2010 Section 3 – Plants, Groups, and Sub-Groups

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.

Typical 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.

Typical Design

Manufacturer (Column 11) Enter the name of the manufacturer of the turbines in the sub-group. See Appendix F.

Make (Column 12) Enter the name of the make of the turbines in the sub-group.

Model (Column 13) Enter the model 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 (Column 16) Enter the lowest wind speed that the turbine will start to generate power, in meters per second.

Low Cut-out Wind Speed (Column 17) Enter the lowest wind speed that the turbine can continue to generate power before cutting out, in meters per second.

GADS WTG Data Reporting Instructions – January 2010 19 Section 3 – Plants, Groups, and Sub-Groups

High Cut-out Wind Speed (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 (Column 20) From the table below, select the average wind turbulence where the sub-group is located.

Turbulence Entry Low 1 Mild 2 Moderate 3 Strong 4 Severe 5

Wind Speed Range (Column 21) From the table below, select the average range of wind speed where the sub-group is located, measured in meters per second.

Wind Speed Entry 0-3 m/s 1 4-7 m/s 2 8-10 m/s 3 11-13 m/s 4 14-16 m/s 5 17-20 m/s 6 21-24 m/s 7 24-29 m/s 8 30-32 m/s 9 >32 m/s 10

Wind Shear (Column 22) From the table below, select the average strength of the difference between wind speeds from the tip of the rotor at its lowest point and its highest point.

Wind Shear Entry Smooth 1 Moderately Rough 2 Rough 3 Very Rough 4

20 GADS WTG Data Reporting Instructions – January 2010 Section 3 – Plants, Groups, and Sub-Groups

Plant Boundaries

The following is taken from the GADS Data Reporting Instructions as a suggestion of plant boundaries. (See Appendix G, Outside 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.

The standard sets a boundary on the generator side of the power station (see Figure 3-1 below) for the determination of equipment "outside management control."

Figure 3-1: The Physical Boundary of Outside Management Control

GADS WTG Data Reporting Instructions – January 2010 21 Section 3 – Plants, Groups, and Sub-Groups

As shown in Figure 3-1, a generating unit includes all equipment up to (in preferred order) (1) the high-voltage terminals of the generator step-up (GSU) transformer and the station service transformers; (2) the GSU transformer (load) side of the generator-voltage circuit breakers; or (3) at such equipment boundary as may be reasonable considering the design and configuration of the generating unit.

It may be assumed that all problems within the power station boundary are within plant management control. However that is not always the case. Therefore, there is a need for additional clarification as to what is and what is not under plant management control.

Through the discussion of wind power generation there will be references to an off-taker. The off-taker is the entity that accepts the power produced by the wind turbine generating plant. The actions of the off-taker can affect the power produced by the plant. It is important to keep in mind that very often actions of the off-taker that affect the output of the plant are considered to be outside the control of the plant’s management.

22 GADS WTG Data Reporting Instructions – January 2010 Section 4 – Performance Reporting

Section 4 – Performance Reporting

Performance data provide 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 program.

There are two parts the performance record: required and optional. The required fields (columns 1 to 24) must be completed so that GADS can evaluate the performance of the sub-groups, groups and plant. The optional fields (columns 25 to 30) can be calculated by the GADS software but can be completed by the reporter to insure the proper data is recorded in GADS.

Performance 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 Sub-Group Status Alpha-Numeric - 2 9 Gross Actual Generation (GAG) Numeric - 10 + 2 decimals 10 Net Actual Generation (NAG) Numeric - 10 + 2 decimals 11 Net Maximum Capacity (NMC) Numeric - 8 + 2 decimals 12 Period Turbine-Hours (PDTH) Numeric - 10 + 2 decimals 13 Contact Turbine-Hours (CTH) Numeric - 12 + 2 decimals 14 Reserve Shutdown Turbine-Hours (RSTH) Numeric - 10 + 2 decimals 15 Forced Turbine-Hours (FTH) Numeric - 10 + 2 decimals 16 Maintenance Turbine-Hours (MTH) Numeric - 10 + 2 decimals 17 Planned Turbine-Hours (PTH) Numeric - 10 + 2 decimals 18 OMC Forced Turbine-Hours (oFTH) Numeric - 10 + 2 decimals 19 OMC Maintenance Turbine-Hours (oMTH) Numeric - 10 + 2 decimals 20 OMC Planned Turbine-Hours (oPTH) Numeric - 10 + 2 decimals 21 Resource Unavailable Turbine-Hours (RUTH) Numeric - 10 + 2 decimals 22 Inactive Reserve Turbine-Hours (IRTH) Numeric - 10 + 2 decimals 23 Mothballed Turbine-Hours (MBTH) Numeric - 10 + 2 decimals 24 Retired Unit Turbine-Hours (RTH) Numeric - 10 + 2 decimals Optional Fields 25 Site Available Turbine-Hours (SATH) Numeric - 10 + 2 decimals 26 Site Unavailable Turbine-Hours (SUTH) Numeric - 10 + 2 decimals 27 Equipment Available Turbine-Hours (EATH) Numeric - 10 + 2 decimals 28 Equipment Unavailable Turbine-Hours (EUTH) Numeric - 10 + 2 decimals 29 Inactive Turbine Hours (ITH) Numeric - 10 + 2 decimals 30 Calendar Turbine-Hours (CalTH) Numeric - 10 + 2 decimals

GADS WTG Data Reporting Instructions – January 2010 23 Section 4 – Performance Reporting

Plant ID (Column 1) Enter a unique ID to the plant that you are reporting. This ID is referenced in all groups, sub- groups, performance, and component data existing under the plant.

Group ID (Column 2) Enter a unique ID to the group that you are reporting. This ID is referenced in all sub-groups, performance, and component data existing under the group.

Sub-Group ID (Column 3) Enter a unique ID to the sub-group that you are reporting. This ID is referenced in all performance and component data existing under the sub-group.

Report Period (Column 6) Enter the two-digit month (MM) in which the performance data is being entered.

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

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.

Status Entry Active AC Inactive Reserve IR Mothballed MB Retired RU

24 GADS WTG Data Reporting Instructions – January 2010 Section 4 – Performance Reporting

Capacity and Generation

Gross Actual Generation – GAG (Column 9) Enter the total wind turbine energy going out of the wind turbine group (MWh). Gross actual generation is the sum of all individual turbine meters before removing station service or auxiliary loads.

Net Actual Generation – NAG (Column 10) Enter the net generation (MWh) recorded at the revenue meter. 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.

Net Maximum Capacity – NMC (Column 11) Enter the actual generating capability (MW) at the revenue meter. 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 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.

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) Enter the sum of all turbine-hours that the sub-group is available to the system at a reduced capacity for economic reasons. There are no equipment problems and the turbines are ready for service. 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 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 24:00 (just before Sunday becomes Monday).

Maintenance Turbine-Hours – MTH (Column 16) Maintenance Turbine-Hours is the sum of all turbine-hours the sub-group is off-line due to a maintenance event.

GADS WTG Data Reporting Instructions – January 2010 25 Section 4 – Performance Reporting

Planned Turbine-Hours – PTH (Column 17) Planned Turbine-Hours is the sum of all turbine-hours 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.

Outside Management Control - OMC (Active)

OMC hours are clocked hours due to events that are outside management control, such as abnormal weather or off-taker planned or unplanned downtime.

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.

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) Number of turbine hours the sub-group is not producing electricity.

Turbine Hours (Inactive)

Inactive Reserve Turbine-Hours – IRTH (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) Total number of turbine-hours in a period being reported that the sub-group is in the retired state.

26 GADS WTG Data Reporting Instructions – January 2010 Section 4 – Performance Reporting

Calculated Turbine Hours (Optional)

Site Available Turbine-Hours – SATH (Column 25) PDTH minus the RUTH.

Site Unavailable Turbine-Hours – SUTH (Column 26) Sum of the PTH, FTH, MTH, and RUTH.

Equipment Available Turbine-Hours – EATH (Column 27) Sum of the CTH and RUTH.

Equipment Unavailable Turbine-Hours – EUTH (Column 28) Sum of PTH, FTH, and MTH.

Inactive Turbine Hours – ITH (Column 29) Total of the inactive, mothballed, and retired turbine hours.

Calendar Turbine-Hours – CalTH (Column 30) Total number of hours during one period (month).

GADS WTG Data Reporting Instructions – January 2010 27 Section 4 – Performance Reporting

28 GADS WTG Data Reporting Instructions – January 2010 Section 5 – Component Outage Reporting

Section 5 – Component Outage Reporting

The component outage reporting section is used to identify the general area or reason for WTG loss production as reported in performance reporting. 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)

Plant ID (Column 1) Enter a unique ID to the plant that you are reporting. This ID is referenced in all groups, sub- groups, performance, and component data existing under the plant.

Group ID (Column 2) Enter a unique ID to the group that you are reporting. This ID is referenced in all sub-groups, performance, and component data existing under the group.

Sub-Group ID (Column 3) Enter a unique ID to the sub-group that you are reporting. This ID is referenced in all performance and component data existing under the sub-group.

GADS WTG Data Reporting Instructions – January 2010 29 Section 5 – Component Outage Reporting

Report Period (Column 6) Enter the two-digit month (MM) in which the event occurred.

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

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.

Turbine Hours and Occurrences

Forced Turbine Hours (Column 9) Enter the total number of forced turbine hours (for the reporting sub-group) that attributed to the system/component specified above during the period being reported.

Number of Forced Outage Occurrences (Column 10) Enter the total number of forced outage events that 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 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 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 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 attributed to the system/component specified above during the period being reported.

30 GADS WTG Data Reporting Instructions – January 2010 Appendix A – GADS Data Release Guidelines

Appendix A – GADS Data Release Guidelines

Introduction

NERC Generating Availability Data System (GADS) contains information which can be broadly classified into two categories: design data, which is descriptive of equipment physical and operational characteristics, and performance and component outage data, which constitutes a record of equipment availability over a period of time.

The design data is unrestricted, and available to power generators, manufacturers and equipment suppliers, architect-engineers and consultants, industry organizations (EEI, EPRI, INPO, etc.), federal governmental organizations, and state and local governmental organizations.

To avoid the potential misuse of individual equipment data, the performance and event 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 project (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.

The "standard publication" mentioned in the following paragraphs is that approved and recognized as such by the NERC Planning Committee. The current publication is the Generating Availability Report and the GADS Brochure. The latest versions can be downloaded from the NERC web site: http://www.nerc.com/page.php?cid=4|43|47

Power Generator Representatives

Power generator owners/operators who report GADS data for all units outlined in the GADS Data Reporting Instructions, Figure III-1 (shown as “required” for the different unit types) may receive any special data analyses, data analysis-type software products like pc-GAR or standard publication without restriction, except that large amounts of power generator, pool, region, or specific unit data will be provided only with the permission of the appropriate power generator, pool, or region. Power generator representatives are understood to refer to employees of the member power generators, power pools, or regional entities.

GADS WTG Data Reporting Instructions – January 2010 31 Appendix A – GADS Data Release Guidelines

Power generator owners/operators who do not report any GADS data or only part of the full sets of unit data as outlined in the GADS Data Reporting Instructions, Figure III-1 (shown as “required” for the different unit types) may only receive standard publications but will not receive any special data analyses or data analysis-type software products like pc-GAR.

Manufacturers and Equipment Suppliers

Manufacturers and equipment suppliers may receive the standard publication. They may also receive individual analyses and outage records concerning the equipment they supplied, as well as total unit performance statistics. National, regional, or local summary analyses of the manufacturer's or equipment supplier's equipment compared to all others as a group can be provided. These analyses may collectively review all competitors, but will not identify an individual competitor; nor will they rank competitors, power generators, pools, or regions without their specific authorization.

Architect-Engineers and Consultants

Architect-engineers and consultants may receive the standard publication. They may also receive individual analyses and outage records concerning the equipment they designed or installed, as well as total unit performance statistics for those same units. National, regional, or local grouped units summary analyses on the performance of the architect-engineer's or consultant's units compared to all others as a group can be provided. These analyses may collectively review all competitors but will not identify an individual competitor; nor will they rank competitors, power generators, pools, or regions without their specific authorization. If an architect-engineer or consultant is under contract to a power generator client, that architect-engineer or consultant may receive any information the power generator may receive, as long as the client power generator is identified and approves.

Industry Organizations (EEI, EPRI, INPO, etc.)

Industry organizations such as EEI, EPRI, and INPO may receive the standard publication. They may also receive any analyses that do not identify individual units, power generators, pools, or regions.

Federal Governmental Organizations

Federal governmental organizations may receive the standard publication. They may also receive any analyses that do not identify individual units, power generators, pools, or regions.

State and Local Governmental Organizations

State and local governmental organizations may receive the standard publication. They may also receive any analyses that do not identify individual units, power generators, pools, or regions. Responses to requests for unit, power generator, pool, or regional specific data will be coordinated through the appropriate power generator(s), pool(s), or NERC region(s).

32 GADS WTG Data Reporting Instructions – January 2010 Appendix A – GADS Data Release Guidelines

Non-Industry Organizations

Non-industry organizations may receive the standard publication. They may also receive any analyses that do not identify individual units, power generators, pools, or regions. Responses to requests for unit, power generator, pool, or regional specific data will be coordinated through the appropriate power generator(s), pool(s), or region(s).

Foreign Correspondents

Foreign correspondents may receive the standard publication. They may also receive grouped analyses at the discretion of the NERC staff.

Subsequent Use of Data

Publication or re-transmittal by those who have received GADS data, reports, or analyses specific to individual or identifiable units, power generators, pools, or regions is considered a matter separate and distinct from requesting such data for the internal use of the requester. As such, authorization for publication must be expressly obtained by the requester from the appropriate power generator(s), pool(s), or NERC region(s), and NERC.

Responding to Requests

All requests must be submitted in writing and will be answered on a timely basis with special attention given to requests identified as urgent.

GADS WTG Data Reporting Instructions – January 2010 33 Appendix A – GADS Data Release Guidelines

34 GADS WTG Data Reporting Instructions – January 2010 Appendix B – Utility and Unit Identificiation

Appendix B – Utility and Unit Identification

Utility Identification Codes

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. This Appendix contains a list of the codes for each utility system presently participating or assigned a NERC GADS utility code.

Unit Identification Codes

Each utility participating in the wind turbine generation database assigns their own unique identification codes to its units. This unique three character alpha-numeric code allows each unit’s data to be catalogued and filed in the database.

GADS WTG Data Reporting Instructions – January 2010 35 Appendix B – Utility and Unit Identificiation

Non-Regional Member Utilities

Utility Code Utility Name

008 Emera Energy 010 Hawaiian Electric Co., Inc. 011 AES – Hawaii 012 Kaua`i Island Utility Co-op 013 Hydro-Quebec Production A 014 Hydro-Quebec Production B 015 Constellation Energy Commodities Group (Canada) 021 Calpine - Europe 022 ECOELECTRICA L.P. 023 Federal de Electricidad 024 EDF S.A. (Electricitie de France) 025 Israel Electric Company 026 Itabo Power - Dominican Republic 030 AES – South America/Mexico 031 AES – Europe 032 AES – Asia 033 AES – Africa 034 AES – Australia 049 PLN – LITBANG (Indonesian State Electricity Enterprise) (Indonesia) 050 Tenaga Nasional Power 051 Saudi Electric Company - Central Operating Area 052 Saudi Electric Company - Western Operating Area 053 Saudi Electric Company - Eastern Operating Area 054 Saudi Electric Company - Southern Operating Area 061 Endesa (Italy) 062 AEM S.p.A. Milano (Italy) 063 Tirreno Power (Italy) 064 Acea Electrabel Produzione S.p.A.(Italy) 065 ISAB energy S.r.I. (Italy) 066 NU.CE.S.p.A.(Italy) 067 Raffineria di Gela S.p.A.(Italy) 068 AEM Torino S.p.A. (Italy) 069 Raffineria di Milazzo (Italy) 097 American National Power – NPCC 099 Pawtucket Power 0AA RWE Power AG (Germany) 0AB Scottish and Southern Energy (UK) 0AC Essent Energy (Netherlands) 0AD Electric Supply Board of Ireland 0AE Scottish Power (UK) 0AF Stadtwerk Bremen (Germany) OAG Conoco Phillips (UK) 0AH NUON (Netherlands)

36 GADS WTG Data Reporting Instructions – January 2010 Appendix B – Utility and Unit Identificiation

Non-Regional Member Utilities (continued)

Utility Code Utility Name

0AI Intergen - Europe 0AJ EDP Producão (Portugal) 0AK Drax Power Limited, Selby, North Yorkshire, UK 0AL International Power Plc, London, UK 0AM Energie Baden-Württemberg AG 0AN ATCO Power 0HA NTPC Limited (India) 0H1 Gujarat Paguthan Energy Corp. (GPEC) (Bharuch, Gujarat, India) 0IA Guohua Power Co. Ltd (Beijing, China) 0IB InterGen – Asia 0IC Petronas (Malaysia) 0NA Eskom (South Africa) 0NB InterGen – Africa 0NC Sasol Limited – Africa 0ND Jorf Lasfar Energy Company 0RA InterGen – Australia 0VA Brookfield Power (Brazil) 0VB Pantanal Energia (Brazil) 0VC Braskem Utilities Division (Brazil) 0VD InterGen – South America/Mexico 0WA Grand Bahamas Power

GADS WTG Data Reporting Instructions – January 2010 37 Appendix B – Utility and Unit Identificiation

Northeast Power Coordinating Council (NPCC)

Northeast Power Coordinating Council 1040 Avenue of the Americas (6th Avenue) 10th Floor New York, New York 10018-3703

212-840-1070 212-302-2782 Fax

Utility Code Utility Name

003 Ontario Power Generation, Inc. 004 New Brunswick Electric Power Commission 043 Nova Scotia Power Inc. 1A0 Brookfield Power 1A1 Brookfield Power 1B1 Dominion Energy (NPCC) 1B2 Exelon New England Holding 1C1 James A. Goodman, as Receiver 1D1 Waterside Power 1E1 BG North America LLC (NPCC) 1F1 Matep LLC 1G1 Androscoggin Energy Center 1H1 UPC Wind 1I1 Hingham Municipal Lighting Plant 1J1 Westfield Gas & Electric Light Department 1K1 Hampshire Paper Co 1L1 Noble Environmental Power 1M1 First Wind Energy, LLC 1N1 Saranac Energy 1P1 Princeton Municipal Light Department 1R1 Black Bear Hydro Partners LLC 1T1 LS Power (Bridgeport) 100 Brookfield Power 101 Boston Edison Company 102 Constellation Energy (NPCC) 103 Bangor Hydro (USA) 104 Dynegy-Northeast 105 Central Maine Power Company 106 Holyoke Gas & Electric Department 107 Connecticut Light and Power Co. (NE) 108 Consolidated Edison Co. of New York, Inc. 109 Glenwood Energy Center (Keyspan Energy - Parent) 110 Fort Jefferson Energy Center (Keyspan Energy - Parent)

38 GADS WTG Data Reporting Instructions – January 2010 Appendix B – Utility and Unit Identificiation

Northeast Power Coordinating Council (continued)

Utility Code Utility Name

111 Connecticut Light and Power Co. (NE) 112 Holyoke Water Power Co. (NE) 113 National Grid (Keyspan Energy) 114 Chicopee Municipal Lighting 115 TransCanada 116 Commonwealth Energy System 117 N.Y. State Electric & Gas Corp. 118 NRG Energy 119 Mirant – New York 120 New York Power Authority 121 Public Service of New Hampshire (NE) 122 Rochester Gas & Electric Corp. 123 Wisvest-Connecticut, LLC 124 W. Massachusetts Electric Co. (NE) 125 Yankee Atomic Electric Co. 126 Massachusetts Municipal Wholesale Electric Co. 127 Dominion Energy (NPCC) 128 Connecticut Yankee Atomic Power Co. 129 Montaup Electric Co. 130 ARC-SEMASS 131 Exelon Generation (New England) 132 Global Common Greenport LLC 133 FPL Energy (NPCC) 134 Nantucket Electric 135 Kimberly-Clark 136 Mirant – New England 137 Ocean State Power 138 American National Power 139 Penobscot Hydro LLC 140 TransCanada – Ravenswood 141 NRG Energy – New England 142 Ipswich Municipal Light Department 143 VAE Lowell Power 144 Entergy Nuclear Northeast 145 Berkshire Power Company, LLC 146 Massachusetts Bay Transportation Authority 147 Brainstree Electric Light Department 148 Indeck Pepperell Power 149 Milford Power Co. 150 Connecticut Municipal Electric Energy Coop. 151 US Power Generating Co. (USPowerGen) 152 NRG Energy – New York

GADS WTG Data Reporting Instructions – January 2010 39 Appendix B – Utility and Unit Identificiation

Northeast Power Coordinating Council (continued)

Utility Code Utility Name

153 Ogden Martin Babylon 154 YESCo Power 155 Calpine (NPCC) 156 Columbia/ZAPCO 157 Montenay Power 158 Covanta Energy Corp. 159 Nissequogue Cogen 160 Marblehead Municipal Light Department 161 PPL Generation Co. (New England) 162 Equus Power One, LP (number was Aquila - NPCC) 163 Wyeth-Ayerst Pharmaceuticals 164 NAEA 165 Energy Systems Northeast (ESNE) 166 AES Energy (NPCC) 167 Taunton Municipal Light 168 Shrewsbury Electric Light Plant 169 Granite Ridge Energy 170 Masspower 171 Unitil Power Corp. 172 Fitchburg Gas and Electric Light Co. 173 NextEra Energy Resources – Seabrook Station 174 Covanta Haverhill, Inc. 175 Wheelabrator Millbury, Inc. 176 Wheelabrator Technologies, Inc. 177 Barre Energy Partners, L.P./Zahren Alternative Power Company 178 Ridgewood Providence Power Partners, L.P. 179 Waste Management of New Hampshire, Inc. 180 Suncook Energy LLC 181 Massachusetts Water Resources Authority 182 Vermont Electric Power Co. 183 CHI Energy 184 Hafslund U.S.A., Inc. 185 American Paper Mills of VT 186 Hudson Light & Power 187 Sterling Municipal Electric Light Department 188 Chicopee Hydro Electric Limited Partnership 189 Swift River Co. 190 Northeast Generation Co. 191 PS&H IPPS 192 Boralex Operation Inc. 193 Pioneer Electric Hydro Co., Inc. 194 Connecticut Resources Recovery Authority

40 GADS WTG Data Reporting Instructions – January 2010 Appendix B – Utility and Unit Identificiation

Northeast Power Coordinating Council (continued)

Utility Code Utility Name

195 Springfield Water and Sewer Commission 196 Dynegy 197 Peabody Municipal Light 198 New Hampshire Electric Cooperative, Inc. 199 Indeck Pepperill Power Associates

GADS WTG Data Reporting Instructions – January 2010 41 Appendix B – Utility and Unit Identificiation

ReliabilityFirst Corporation (RFC)

ReliabilityFirst Corporation 320 Springside Drive, Suite 300 Akron, Ohio 44333

330-456-2488

Utility Code Utility Name

201 Atlantic Electric Co. 202 Constellation Energy (Baltimore Gas and Electric) 203 Delaware Municipal Utilities 204 Delmarva Power & Light Co. 205 Jersey Central Power & Light Co. 206 Easton Utilities Commission 208 First Energy (Metropolitan Edison Co.) 209 Vineland Municipal Electric Utilities 211 Pennsylvania Electric Company (FirstEnergy) 212 PPL Corp. 213 Exelon (PECO) 214 Potomac Electric Power Co. 215 Public Service Electric and Gas Co. 216 UGI Corporation 220 EME Homer City Generation L.P. 221 Cinergy Capital & Trading, Inc. 222 PEI Power Corporation 223 FPL Energy 224 Willamette Industries, Inc. 225 Crown Vantage 226 Williams Energy 227 Statoil Energy 228 American Ref-fuel 229 First Energy 230 Integrys Energy Services 231 Pedricktown Cogen 232 Amergen 233 Lebanon Methane Recovery 234 Commonwealth Chesapeake 235 Mirant Mid Atlantic 236 RRI Energy, Inc. - East 237 RRI Energy, Inc. - Central 238 RRI Energy, Inc. - West 239 Bethlehem Steel 240 El Paso Merchant Energy (RFC)

42 GADS WTG Data Reporting Instructions – January 2010 Appendix B – Utility and Unit Identificiation

ReliabilityFirst Corporation (continued)

Utility Code Utility Name

241 Sempra 242 NRG Energy-Mid Atlantic 243 Algonquin Power 244 Convanta Energy 245 Delaware Municipal Electric Cooperative 246 Mt. Carmel NUG 247 NAEA 248 Old Dominion Electric Cooperative 249 AES Energy (RFC) 250 Calpine Corporation (RFC) 251 Premcor Refinery Group 252 JARON & CO 253 Dominion Energy (RFC) 254 East Coast Power 255 SUNOCO 256 Newmarket Power Company, LLC 257 Liberty Electric Power, LLC 258 Brascan Power 259 Marina Energy 260 Ontelaunee Power Operating Co. 261 Allegheny Energy Supply (AETS) 262 Brookfield Power (RFC) 263 Corona Power 264 Constellation New Energy 265 Cape May Holdings 266 Ingenco (RFC) 267 RPL Holdings Inc. 268 Pa Renewable Resources Assoc. 269 Hazelton Generation, LLC 270 EFS Parlin 271 Wheelabrator Frackville 272 Viking Energy 273 Horsehead Corp. 274 Ameresco 275 Monmouth Energy 276 NEPCO Harwood 277 Kimberly Clark Corp. 278 Pioneer Crossing Energy, LLC

350 Emporia Hydro

GADS WTG Data Reporting Instructions – January 2010 43 Appendix B – Utility and Unit Identificiation

ReliabilityFirst Corporation (continued)

Utility Code Utility Name

401 Appalachian Power Co. (AEP) 402 Central Operating Company (AEP) 403 Cinergy 404 First Energy (formerly Cleveland Electric Illuminating Co.) 405 Columbus Southern Power Co. (AEP) 406 Consumers Energy 407 Dayton Power and Light Co. 408 DTE Energy Co. 409 Duquesne Light 410 East Kentucky Power 411 Indiana Michigan Power Co. (AEP) 412 Indiana-Kentucky Electric Corp. (OVEC) 413 Indianapolis Power & Light Co. (The AES Corp.) 414 Kentucky Power Co. (AEP) 418 Northern Indiana Public Service Co. 419 First Energy (formerly Ohio Edison) 420 Ohio Power Co. (AEP) 421 Ohio Valley Electric Corp. (OVEC) 422 Pennsylvania Power Co. (FirstEnergy) 424 Cinergy (formerly Public Service Co. of Indiana, Inc.) 425 Vectren Power (formerly So Indiana Gas and Electric Co.) 426 First Energy (formerly Toledo Edison Co.) 427 Allegheny Energy Supply (formerly West Penn Power Co.) 430 Cinergy 431 RRI Energy, Inc. (RFC) 432 DTE Georgetown, LLC 433 Calpine Corporation 434 El Paso Merchant Energy 435 Constellation Energy 436 AEP - Lawrence 437 Duke Energy Trading 438 Mirant - ECAR 439 AES - ECAR 440 DPL Energy LLC 441 AMP - Ohio 442 Indiana Municipal Power Agency (IMPA) 443 NRG Energy 444 International Power 445 Dynegy Generation 446 PSE&G 447 Hoosier Energy 448 Department of Municipal Services (DMS) (WYand)

44 GADS WTG Data Reporting Instructions – January 2010 Appendix B – Utility and Unit Identificiation

ReliabilityFirst Corporation (continued)

Utility Code Utility Name

449 Tenaska (RFC) 450 Buckeye Power 451 Sugar Creek Power Co LLC 452 Entergy Nuclear Northeast (RFC) 453 Tenaska (New Covert) 454 Midland Cogeneration Venture, L.P. 455 Bear Energy LP 456 Michigan South Central Power Agency 457 DTE Energy Trading 458 CMS Enterprise 459 BP Energy 460 White Pine Electric Power LLC 461 Southwestern Electric Cooperative Inc 464 Michigan Public Power Agency 465 City of Escanaba, Michigan 466 Bluegrass Generation Co., LLC 467 Big River Electric Coop. 468 City of Painsville, Ohio 469 Norway, Michigan Power & Light

502 Constellation Energy 503 Ameren (CILCO) 504 Ameren (CIPS) 506 Exelon (Com Ed) 507 Electric Energy, Inc. 508 Dynegy Midwest Generation (formerly Illinois Power Co.) 509 Elwood Energy LLC 510 Midwest Generation EME 511 Tenaska (University Park) 514 Southern Illinois Power Coop. 516 City Water, Light and Power (Springfield) 517 Ameren - UE 518 PPL Generation Co. 520 Madison Electric and Gas Co. 521 Wisconsin Electric Power Co. 522 Alliant Energy (Wisconsin P&L) 523 Wisconsin Public Service Corp. 524 Calpine Corporation (RFC) 525 El Paso Merchant Energy 526 RRI Energy, Inc. 527 Duke Energy Trading 528 Dominion Energy

GADS WTG Data Reporting Instructions – January 2010 45 Appendix B – Utility and Unit Identificiation

ReliabilityFirst Corporation (continued)

Utility Code Utility Name

529 Tenaska (Lincoln) 530 City of Rochelle, Illinois 531 Tenaska (Crete) 532 Exelon Generation, LLC 533 Wisconsin Public Power Inc. 534 Dynegy 535 NRG Energy 537 Diamond Generating Corp. 538 City of Geneva, IL 539 Calpine Corporation (RFC) 540 Upper Peninsula Power Company (UPPCO) 541 Wisconsin River Power Company (WRPCO) 542 Kaukauna Utilities 543 River Falls Municipal Utilities 544 Independence Light & Power 545 Prairie Power 546 Gen-Sys Energy 547 International Power 548 Columbia Missouri Water and Light 550 City of Sikeston 555 Capital Co-generation LLC 556 LS Power 557 Marshfield Utilities 558 Prairieland Energy Inc.

607 Alliant Energy (formerly Interstate Power) 608 Alliant Energy (formerly IES Utilities) 612 Alliant Energy (formerly IES Utilities)

46 GADS WTG Data Reporting Instructions – January 2010 Appendix B – Utility and Unit Identificiation

SERC Reliability Corporation (SERC)

SERC Reliability Corporation 2815 Coliseum Centre Drive, Suite 500 Charlotte, NC 28217

704-357-7372

Utility Code Utility Name

301 PowerSouth Energy Coop. (formerly Alabama Electric Coop., Inc.) 302 Alabama Power Co. (Southern Company) 303 Progress Energy - Carolinas 304 Southern Power (SOCO) 307 Duke Energy (Duke Power Company) 311 Old Dominion Electric Cooperative 312 Georgia Power Co. (SOCO) 313 Gulf Power Co. 315 Mississippi Power Co. (SOCO) 316 Municipal Electric Authority of Georgia 318 Savannah Electric and Power Co. (SOCO) 319 South Carolina Electric & Gas Co. 320 So. Carolina Public Service Authority 321 So. Mississippi Electric Power Association 323 Southern Electric Gen. Co. (SOCO) 325 Alcoa Power Generating (Tapoco, Inc.) 326 Tennessee Valley Authority 327 Allegheny Energy Supply (SERC) 328 Virginia Power-Dominion 329 Constellation Energy 330 Seminole Electric Coop., Inc. 331 Oglethorpe Power Coop. 332 Calpine Corporation (SERC) 333 El Paso Merchant Energy (SERC/FRCC) 334 Aquila-SERC 335 Duke Energy Trading (SERC) 336 West Georgia Generating Co. 339 Intergen (SERC) 340 Tenaska (SERC) 341 Southeastern Power Administration 342 Coral Power (SERC) 344 North Carolina Electric Membership Corp. 345 Ingenco Wholesale Power, LLC 346 Dynegy Generation (SERC)

GADS WTG Data Reporting Instructions – January 2010 47 Appendix B – Utility and Unit Identificiation

SERC Reliability Corporation (continued)

Utility Code Utility Name

348 Progress Ventures, Inc. 349 Batesville Generating Facility (LSP Energy LP) 351 DeSoto County Generating Co., LLC 352 Magnolia Energy, LP

415 Kentucky Utilities Co. (E.ON-US) 416 Louisville Gas and Electric Co. (E.ON-US)

703 Arkansas Power and Light Co. (Entergy) 717 Gulf States Utilities Co. (Entergy) 722 Louisiana Power and Light Co. (Entergy) 723 Mississippi Power and Light Co. (Entergy) 728 New Orleans Public Service, Inc. (Entergy) 739 System Energy Resources, Inc. (Entergy)

48 GADS WTG Data Reporting Instructions – January 2010 Appendix B – Utility and Unit Identificiation

Florida Reliability Coordinating Council (FRCC)

Florida Reliability Coordinating Council Austin Towers West 1408 N. Westshore Boulevard, Suite 1002 Tampa, Florida 33607-4512

813-289-5644 813-289-5646 Fax

Utility Code Utility Name

305 Tallahassee Electric Department 306 Constellation Energy (FRCC) 308 Florida Power & Light Co. 309 Progress Energy - Florida 310 Mirant – FRCC 314 Jacksonville Electric Authority 317 Orlando Utilities Commission 324 Tampa Electric Company 343 Florida Municipal Power Agency 347 Lakeland Electric (FRCC)

GADS WTG Data Reporting Instructions – January 2010 49 Appendix B – Utility and Unit Identificiation

Midwest Reliability Organization (MRO)

Midwest Reliability Organization 2774 Cleveland Avenue North Roseville, Minnesota 55113

651-855-1760

Utility Code Utility Name

005 Manitoba Hydro-Electric Board 601 Basin Electric Power Coop., Inc. 603 Great River Energy (Coop. Power) 605 Dairyland Power Coop. 606 Central Iowa Power Coop. 609 MidAmerican Energy Co. (formerly Iowa-Illinois Gas and Electric Co.) 610 MidAmerican Energy Co. (formerly Midwest Power and Iowa Power Inc.) 611 MidAmerican Energy Co. (formerly Midwest Power and Iowa Public Service Co.) 614 Lincoln Electric System 615 Otter Tail Power Co. 616 Minnesota Power 617 Minnkota Power Coop., Inc. 618 Montana-Dakota Utilities Co. 619 Muscatine Power & Water 620 Nebraska Public Power District 621 Xcel Energy (Northern States Power Co.) 622 NorthWestern Energy 623 Omaha Public Power District 624 Great River Energy (formerly United Power Association) 625 Western Area Power Administration 626 Missouri Basin 627 Minnkota Power Coop., Inc. (formerly Square Butte Electric Coop.) 628 Calpine Corporation (MRO) 629 El Paso Merchant Energy (MRO) 630 Minnesota Municipal Power Agency 631 Wolverine Power Supply Cooperative Inc. 632 Manitowoc Public Utilities 633 Southern Minnesota Municipal Power Agency 634 Resale Power Group 635 Hutchinson Utilities 636 Nextra Energy Resources 638 Silver Bay Power 640 Maquoketa Municipal Electric Utility 641 Preston Iowa Municipal Electric Utility

50 GADS WTG Data Reporting Instructions – January 2010 Appendix B – Utility and Unit Identificiation

Midwest Reliability Organization (continued)

Utility Code Utility Name

643 Trigen-St. Louis Energy Corp. 644 Willmar Municipal Utilities 645 Ames Municipal Energy Resources 646 Delano Municipal Utilities 647 Detroit Lakes Public Utilities 648 Cargill Power Markets, LLC 649 City of Pella, IA 650 Larentian Energy Authority 651 Indianola Municipal Utilities 652 Marshall Municipal Utilities

GADS WTG Data Reporting Instructions – January 2010 51 Appendix B – Utility and Unit Identificiation

Southwest Power Pool (SPP)

Southwest Power Pool 415 North McKinley, Suite 140 Little Rock, Arkansas 72205-3020

501-664-0146

Utility Code Utility Name

704 Associated Electric Coop., Inc. 708 Central Louisiana Electric Co. 709 Denver City Energy Associates 715 Empire District Electric Co. 716 Grand River Dam Authority 718 Kansas City Power & Light Co. 719 Westar Energy (KGE) 720 Westar Energy (KPL) 729 Oklahoma Gas and Electric Co. 730 American Electric Power West (Public Service Co. of Oklahoma) 732 American Electric Power West (Southwestern Electric Power Co.) 733 Southwestern Power Administration 734 Xcel Energy (Southwestern Public Service Co.) 735 Sunflower Electric Power Corporation 737 Western Farmers Electric Cooperative 740 NRG Energy – Louisiana Generating, LLC 750 Borger Energy Associates (BEA) 751 Calpine Corporation (SPP) 752 El Paso Merchant Energy-SPP 753 AES - SPP 754 Intergen Corp (SPP) 755 Tenaska (SPP) 756 Brookfield Power (SPP) 757 Dogwood Energy LLC

52 GADS WTG Data Reporting Instructions – January 2010 Appendix B – Utility and Unit Identificiation

Texas Regional Entity (TRE)

Texas Regional Entity 2700 Via Fortuna, Suite 225 Austin, Texas 78746

512-225-7000

Utility Code Utility Name

801 Austin Energy (formerly Austin Electric Department) 802 Exelon Generation (Texas) 803 Constellation Energy (TRE) 804 AES (TRE) 805 Intergen Corp (TRE) 806 Tenaska (TRE) 807 International Power 808 Brazos Electric Power Coop., Inc. 810 Calpine Corporation (TRE) 811 El Paso Merchant Energy (TRE) 812 Topaz Power Group, LLC 815 GIM Channelview Cogeneration 819 Luminant Power 828 Garland Power & Light Co. 838 American National Power 839 Mirant - ERCOT 840 NRG Texas (formerly Texas Genco LLC) 841 Reliant Energy (TRE) 842 Optim Energy, LLC 854 Lower Colorado River Authority 868 CPS Energy (San Antonio City Public Service) 879 Luminant Power 880 Luminant Power 884 American Electric Power West (West Texas Utilities Co.) 887 Luminant Power 888 Texas Municipal Power Agency 889 San Miguel Electric Coop., Inc. 894 Luminant Power

GADS WTG Data Reporting Instructions – January 2010 53 Appendix B – Utility and Unit Identificiation

Western Electricity Coordinating Council (WECC)

Western Electricity Coordinating Council 615 Arapeen Drive, Suite 210 Salt Lake City, Utah 84108-1262

801-582-0353 801-582-3918 Fax

Utility Code Utility Name

001 B.C. Hydro 002 Calgary Power Ltd. 007 TransAlta Utilities 006 West Kootenay Power & Light Co. 009 Trans-Canada 901 Brookfield Power (SPP) 902 Arizona Electric Power Coop., Inc. 903 Sycamore Cogeneration Company 904 Arizona Public Service Co. 905 Calpine Corporation (WECC) 906 El Paso Merchant Energy-WECC 907 Constellation Energy (WECC) 908 Elk Hills Power, LLC 909 Tri-State G&T Association, Inc. 910 Magnolia Power Project 911 Burbank Water & Power 912 Black Hills Power, Inc. 913 El Paso Electric Co. 914 Eugene Water & Electric Board 915 Black Hill Wyoming 916 Kern River Cogeneration Company 917 Idaho Power Company 918 Harbor Cogeneration Company 919 GWF Power Systems 920 Los Angeles Department of Water and Power 921 La Paloma Generating 922 PPL-Montana 923 Coalinga Cogeneration Company 924 NV Energy 925 Pacific Gas and Electric Co. 926 Pacificorp (Pacific Power & Light Co.) 927 PG&E National Energy Group - WECC 928 Mirant - WECC 929 Pinnacle West Energy Co.

54 GADS WTG Data Reporting Instructions – January 2010 Appendix B – Utility and Unit Identificiation

Western Electricity Coordinating Council (continued)

Utility Code Utility Name

930 Platte River Power Authority 931 Portland General Electric Co. 932 Xcel Energy (Public Service Co. of Colorado) 933 Public Service Co. of New Mexico 934 Mid-Set Cogeneration Company 935 Salinas River Cogeneration Company 936 PUD No. 1 of Chelan County 937 Sargent Canyon Cogeneration Company 938 PUD No. 1 of Douglas County 939 San Diego County Water Authority 940 RRI Energy, Inc. (WECC) 941 El Dorado, LLC 942 Sacramento Municipal Utility District 944 Salt River Project 945 San Diego Gas & Electric Co. 947 Seattle City Light 948 NV Energy (Sierra Pacific Power Co.) 949 Southern California Edison Co. 953 Tucson Electric Power Company 954 Pacificorp (Utah Power & Light Co.) 956 Energy Northwest 958 Tucson Electric Power Co. 959 U.S. Army Corp of Engineers – Portland District 960 U.S. Army Corp of Engineers – Walla Walla District 961 U.S. Army Corp of Engineers – Seattle District 962 Inland Empire Energy Center 965 Deseret Generation & Transmission Coop. 966 Imperial Irrigation District 967 AES Redondo Beach 968 U.S. Bureau of Reclamation 969 NRG Energy-Western 970 Tenaska (WECC) 971 AES-Alamitos LLC 972 NRG Energy - Western 973 Duke Energy Trading (WECC) 974 Intergen Corp. (WECC) 975 Williams Energy 976 Wildflower Energy LLP 977 Wellhead Electric Co. INC. 979 Sunrise Power Company 980 Colton Power LLC 981 CalPeak Power - Border LLC

GADS WTG Data Reporting Instructions – January 2010 55 Appendix B – Utility and Unit Identificiation

Western Electricity Coordinating Council (continued)

Utility Code Utility Name

982 CalPeak Power - El Cajon LLC 983 CalPeak Power - Enterprise LLC 984 CalPeak Power - Panoche LLC 985 CalPeak Power - Vaca Dixon LLC 986 FPL Energy (WECC) 987 Dynegy 988 MMC Energy 989 California Power Holdings LLC 990 Starwood Power – Midway LLC 991 LS Power

56 GADS WTG Data Reporting Instructions – January 2010 Appendix C – System-Component Codes

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 Feeder/Collection 650 Metering and Relays 655 Overhead Lines 652 Pad Mount-Multiple WTG 651 Balance of Plant Preventative Maintenance 682 SCADA 656 Site Reactive Power Comp 654 Substation 653 Wind Park Control System 657

System Component Entry General 673 Brake High Speed Shaft Brake 617 Mechanical Lock 618

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 Control System Processor Cooling 646 Reactive Power Control 640 Sensors 642 Software 643 Voltage Regulation 639 VRCC 641 Wind Vane and Anemometer 649

System Component Entry General 671 High Speed Coupling 615 Drive Train Main Bearings 613 Main Shaft 614 Transmission Shaft 616

GADS WTG Data Reporting Instructions – January 2010 57 Appendix C – System-Component Codes

System Component Entry General 670 Circuit Breakers and Switches 661 Individual Pad Mounted Xformers 662 Electrical Power Compensation-WTG 660 Power Converters 658 Transmission Cables 659

System Component Entry General 681 Catastrophe 680 Catastrophe (OMC) 1034 Economic 679 Economic (OMC) 1035 External Off-Taker Transmission & Distribution 675 Weather – Ice 677 Weather – Ice (OMC) 1036 Weather – Lightning 678 Weather - Temperature 676

System Component Entry General 669 Gear Box 608 Gear Box Heating/Cooling 609 Gear Box Gear Box Oil System 610 Gearbox Filtration 611 Torque Arm System 612

System Component Entry General 668 Exciter 634 Generator 631 Generator Bearings 632 Generator/Exciter Generator Cooling Systems 636 Generator Lube Oil Systems 633 Generator Shaft 635 Wiring to Gen Terminals 637

System Component Entry General 667 Common Pump and Motor 627 Hydraulic System Filtering System 629 Hoses, Reservoirs, Valves 630 Hydraulic Accumulator 628

System Component Entry General 666 Electrical 626 Pitch System Mechanical/Electrical 624 Pitch Hydraulics 625

58 GADS WTG Data Reporting Instructions – January 2010 Appendix C – System-Component Codes

System Component Entry General 665 Aerodynamic Brake 602 Blade Pitch Bearing 603 Blades 600 Rotor Deicing Systems 604 Hub 601 Lightning Protection 605 Nose Cone 606

System Component Entry General 664 FAA Lighting 598 Foundations 595 MASS/Harmonic Damp 599 Structures Nacelle 593 Nacelle Heating & Cooling 597 Paint & Coatings 596 Towers 594

System Component Entry General 663 Slew Ring 620 Yaw Dampening 622 Yaw System Yaw Gear 621 Yaw Lubrication Systems 623 Yaw Motors/Hydraulics 619

System Component Entry General 1032 Wind Turbine Overall 1033

GADS WTG Data Reporting Instructions – January 2010 59 Appendix C – System-Component Codes

60 GADS WTG Data Reporting Instructions – January 2010 Appendix D – Terms and Definitions

Appendix D – Terms and Definitions

Capacity and Generation

Group Installed Capacity (GIC) GIC is the sum of all 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 Vestas V-27 machines rated at 0.225 MW each. The GIC would be (20 x 0.66 MW) + (10 x 0.225 MW), which would be 13.20 MW + 2.25 MW. This would give you a GIC of 15.45 MW.

Auxiliary Group Installed Capacity (AGIC) 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 working 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 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.

For example, if the GIC is 100 MW and the loss is 2% then the NMC can be calculated as 100 MW x (1 - 0.02). Our NMC is 98 MW.  NAG  NMC may also be calculated as follows: NMC = GIC ×   where GAG > 0, and NAG > 0.  GAG 

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 no wind, wind speed that is too low, wind speed that is too high, derated winds, or losses that occur outside the manufacturer’s operating specifications.

For example, if the NMC is 100 MW and the losses from all wind problems is 40% then the NDC can be calculated as 100 MW x (1 - 0.40). Our NDC would be 60 MW.

GADS WTG Data Reporting Instructions – January 2010 61 Appendix D – Terms and Definitions

NDC may also be calculated as follows: [(Actual Generation) + (Turbine specific losses) + (reserve derates) + (Site outages such as off-taker problems, 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 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. See Figure 3-1.

Net Actual Generation (NAG) NAG is the net generation (MWh) recorded at the revenue meter. It is possible to have a negative NAG value if the group’s station service or auxiliary loads are greater than total generation.

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:

. The group is capable of reaching 50% of its generator nameplate MW Capacity (wind conditions not part of requirement) and . Dispatch is notified that the group is capable of providing power (wind conditions not part of requirement).

Inactive State (IA) 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.

. 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” 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 have deteriorated or need replacing before the group can be operated.

62 GADS WTG Data Reporting Instructions – January 2010 Appendix D – Terms and Definitions

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. A 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.

. 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 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 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. • Retired (RU) – RU is defined by IEEE and GADS as “The State in which a group or individual WTG is unavailable for service and not expected to return to service in the future.” RU should be the last event for the remainder of the year (up through December 31st at 2400). The group must not be reported to GADS in any future submittals.

Turbine States and Hours Collection

Given the nature of wind generation, it would be a very rare occurrence when every turbine in a group or even a sub-group would be found in the same state. To acknowledge this, to collect hours that are spent in various conditions, and to be able to calculate meaningful statistics, hours are collected as turbine-hours. Using turbine-hours allows the operator to report hours simply by adding up the hours reported by each turbine.

GADS WTG Data Reporting Instructions – January 2010 63 Appendix D – Terms and Definitions

Calendar Hours (CalTH)

Inactive Period Hours Hours (PDTH) (ITH)

Inactive Mothballed Retired Available Unavailable Reserve (MBTH) (RTH) (SATH or (SUTH or (IRTH) EATH) EUTH)

Contact Reserve Planned Unplanned (CTH) Shutdown Outage Outage (RSTH) (PTH)

Resource Forced Maintenance Unavailable Outage Outage (RUTH) (FTH) (MTH)

Figure D-1 - Time Spent in Various 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.

64 GADS WTG Data Reporting Instructions – January 2010 Appendix D – Terms and Definitions

Period 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.

In two instances, the PDTH may be smaller than the normal period hours for the given month:

. When the sub-group becomes commercially active . 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 at a reduced capacity for economic reasons. There are no equipment problems and the turbines are ready for service. Do not include RSTH with the same equations with CTH (this would result in double counting total turbine-hours).

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 and D-3 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 2400 (just before Sunday becomes Monday).

A few examples of forced events:

. LS Generator identified as bad, but fails before it can be replaced . Underground Cable Failure . A turbine fails a hydraulic motor. There is no wind anywhere in the area. In fact, no power has been made on any turbine for over a week.

*More examples can be found in Appendix H.

GADS WTG Data Reporting Instructions – January 2010 65 Appendix D – Terms and Definitions

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.

A few examples of forced OMC events:

. The Off-Taker calls and indicates that a truck has damaged a pole on the line carrying power from the site. The repair cannot wait and power will be down for a few hours. . Safety shutdown due to an approaching storm. . WTGs shedding ice on the local highway. The turbines were shutdown due to safety concerns.

*More examples can be found in Appendix H.

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, not current, weekend. If the event cannot be deferred, the event shall be a Forced Event.

A few examples of maintenance events:

. Brand X manufacturer has developed a new operating program for their WTG and all turbines are scheduled for installation of the update. . Gases are slightly high in transformer. The transformer is monitored and replaced when convenient.

*More 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.

66 GADS WTG Data Reporting Instructions – January 2010 Appendix D – Terms and Definitions

A few examples of maintenance OMC events:

. A contractor off-site damages a high voltage (HV) cable. Repairs are made 2 weeks later. . Transmission line maintenance activities.

*More 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.

A few examples of planned events:

. Substation maintenance . WTG preventative maintenance

*More examples can be found in Appendix H

OMC Planned Turbine-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.

A few examples of planned OMC events:

. Planned Off-Taker outages . The Off-Taker is upgrading their system and power reduction is required

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 (SUTH) 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).

GADS WTG Data Reporting Instructions – January 2010 67 Appendix D – Terms and Definitions

Priority of Outage Reporting

In some instances, there may be more than one event occurring at the same time. In such cases, the group remains on the highest order of outage until it is cleared and then moves to the next level of outage reporting. As per the WTWG meeting, September 2008, the order of outages is as follows:

1. Contact Turbine-Hours 2. Forced Turbine-Hours 3. Maintenance Turbine-Hours 4. Planned Turbine-Hours 5. Reserve Shutdown Turbine-Hours 6. Resource Unavailable Turbine-Hours

Figure D-2

68 GADS WTG Data Reporting Instructions – January 2010 Appendix D – Terms and Definitions

Figure D-3

GADS WTG Data Reporting Instructions – January 2010 69 Appendix D – Terms and Definitions

70 GADS WTG Data Reporting Instructions – January 2010 Appendix E – Performance Equations

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 the same, or very similar, capacities. These equations also include OMC hours. 2. Pooled Resource and Equipment Calculations – These equations pool the resource and equipment performance of sub-groups into collections of sub-groups, groups, or farms. These equations also include OMC hours. 3. 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, capacities. These equations do not include OMC hours. 4. Multi-Resource and Multi-Equipment Calculations without OMC Hours – These equations pool the resource and equipment performance of sub-groups into collections of sub-groups, groups, or farms. These equations do not include OMC hours. 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.

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.

GADS WTG Data Reporting Instructions – January 2010 71 Appendix E – Performance Equations

SECTION 1: Resource and Equipment Calculations (for sub-groups)

A. Resource Performance Factors

1.A.1. Resource Equivalent Availability Factor (REAF) % of period that the plant was available. [PDTH − (FTH + MTH + PTH + RUTH )] REAF = ×100 ≈ (100 − REUF ) PDTH

1.A.2. Resource Equivalent Unavailability Factor (REUF) % of period that the plant was unavailable. (FTH + MTH + PTH + RUTH ) REUF = ×100 ≈ (100 − REAF ) PDTH

1.A.3. Resource Equivalent Planned Outage Factor (REPOF) % of period that the plant was in planned downtime. PTH REPOF = ×100 PDTH

1.A.4. Resource Equivalent Maintenance Outage Factor (REMOF) % of period that the plant was in maintenance downtime. MTH REMOF = ×100 PDTH

1.A.5. Resource Equivalent Forced Outage Factor (REFOF) % of period that the plant was forced off line. Including low and high winds. (FTH + RUTH ) REFOF = ×100 PDTH

1.A.6. 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 + RUTH ) REUOF = ×100 PDTH

72 GADS WTG Data Reporting Instructions – January 2010 Appendix E – Performance Equations

1.A.7. Resource Equivalent Scheduled Outage Factor (RESOF) % of period that the plant was unavailable due to maintenance and planned downtime. (MTH + PTH ) RESOF = ×100 PDTH

1.A.8. Resource Generating Factor (RGF) % of period that the plant was online and in a generating state. CTH RGF = ×100 PDTH

1.A.9. Resource Net Capacity Factor (RNCF) % of actual plant generation. NAG RNCF = ×100 (PDTH × NMC)

1.A.10. Net Output Factor (NOF) % of actual plant loading when on-line. NAG NOF = ×100 (CTH × NMC)

Resource Performance Rates

1.A.11. Resource Equivalent Planned Outage Rate (REPOR) Probability of planned plant downtime when needed for load. PTH REPOR = ×100 (CTH + PTH )

1.A.12. Resource Equivalent Maintenance Outage Rate (REMOR) Probability of maintenance plant downtime when needed for load. MTH REMOR = ×100 (CTH + MTH )

1.A.13. Resource Equivalent Forced Outage Rate (REFOR) Probability of forced plant downtime when needed for load. (FTH + RUTH ) REFOR = ×100 (CTH + FTH + RUTH )

GADS WTG Data Reporting Instructions – January 2010 73 Appendix E – Performance Equations

1.A.14. Resource Equivalent Unplanned Outage Rate (REUOR) Probability of forced or maintenance plant downtime (including high and low winds) when needed for load. (FTH + MTH + RUTH ) REUOR = ×100 (CTH + FTH + MTH + RUTH )

1.A.15. Resource Equivalent Scheduled Outage Rate (RESOR) Probability of maintenance or planned plant downtime when needed for load. (MTH + PTH ) RESOR = ×100 (CTH + MTH + PTH )

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. 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. Equipment Equivalent Availability Factor (EEAF) % of period that the WTG equipment was available. (CTH + RSTH + RUTH ) EEAF = ×100 PDTH

1.B.2. Equipment Equivalent Unavailability Factor (EEUF) % of period that the WTG equipment was unavailable. (FTH + MTH + PTH ) EEUF = ×100 PDTH

1.B.3. Equipment Equivalent Planned Outage Factor (EEPOF) % of period that the WTG equipment was in planned downtime. PTH EEPOF = ×100 PDTH

1.B.4. Equipment Equivalent Maintenance Outage Factor (EEMOF) % of period that the WTG equipment was in maintenance downtime. MTH EEMOF = ×100 PDTH

74 GADS WTG Data Reporting Instructions – January 2010 Appendix E – Performance Equations

1.B.5. Equipment Equivalent Forced Outage Factor (EEFOF) % of period that the WTG equipment was forced off line. Including low and high winds. FTH EEFOF = ×100 PDTH

1.B.6. 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 ) EEOUF = ×100 PDTH

1.B.7. Equipment Equivalent Scheduled Outage Factor (EESOF) % of period that the WTG equipment was unavailable due to maintenance and planned downtime. (MTH + PTH ) EESOF = ×100 PDTH

1.B.8. Equipment Generating Factor (EGF) % of period that the WTG equipment was online and in a generating state. CTH EGF = ×100 (PDTH − RUTH )

1.B.9. Equipment Net Capacity Factor (ENCF) % of actual WTG equipment generation. NAG ENCF = ×100 ((PDTH − RUTH )× NMC)

Equipment Performance Rates

1.B.10. Equipment Equivalent Planned Outage Rate (EEPOR) Probability of planned WTG equipment downtime when needed for load. PTH EEPOR = ×100 (CTH + PTH + RUTH )

1.B.11. Equipment Equivalent Maintenance Outage Rate (EEMOR) Probability of maintenance WTG equipment downtime when needed for load. MTH EEMOR = ×100 (CTH + MTH + RUTH )

GADS WTG Data Reporting Instructions – January 2010 75 Appendix E – Performance Equations

1.B.12. Equipment Equivalent Forced Outage Rate (EEFOR) Probability of forced WTG equipment downtime when needed for load. FTH EEFOR = ×100 (CTH + FTH + RUTH )

1.B.13. 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 ) EEUOR = ×100 (CTH + FTH + MTH + RUTH )

1.B.14. Equipment Equivalent Scheduled Outage Rate (EESOR) Probability of maintenance or planned WTG equipment downtime when needed for load. (MTH + PTH ) EESOR = ×100 (CTH + MTH + PTH + RUTH )

76 GADS WTG Data Reporting Instructions – January 2010 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 unweighted pooling of turbine-hours which gives the same weight to each unit in the group regardless of size. Sums, ∑(), in this section refer to the summation for each sub-group.

A. Pooled Performance Factors

2.A.1. Resource Equivalent Availability Factor (REAF) % of period that the plant was available. ∑[PDTH − (FTH + MTH + PTH + RUTH )] REAF = ×100 ≈ (100 − REUF ) ∑ PDTH

2.A.2. Resource Equivalent Unavailability Factor (REUF) % of period that the plant was unavailable. ∑(FTH + MTH + PTH + RUTH ) REUF = ×100 ≈ (100 − REAF ) ∑ PDTH

2.A.3. Resource Equivalent Planned Outage Factor (REPOF) % of period that the plant was in planned downtime. ∑ PTH REPOF = ×100 ∑ PDTH

2.A.4. Resource Equivalent Maintenance Outage Factor (REMOF) % of period that the plant was in maintenance downtime. ∑ MTH REMOF = ×100 ∑ PDTH

2.A.5. Resource Equivalent Forced Outage Factor (REFOF) % of period that the plant was forced off line. Including low and high winds. ∑(FTH + RUTH ) REFOF = ×100 ∑ PDTH GADS WTG Data Reporting Instructions – January 2010 77 Appendix E – Performance Equations

2.A.6. 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 + RUTH ) REOUF = ×100 ∑ PDTH

2.A.7. Resource Equivalent Scheduled Outage Factor (RESOF) % of period that the plant was unavailable due to maintenance and planned downtime. ∑(MTH + PTH ) RESOF = ×100 ∑ PDTH

2.A.8. Resource Generating Factor (RGF) % of period that the plant was online and in a generating state. ∑CTH RGF = ×100 ∑ PDTH

2.A.9. Resource Net Capacity Factor (RNCF) % of actual plant generation. ∑ NAG RNCF = ×100 ∑(PDTH × NMC)

2.A.10. Net Output Factor (NOF) % of actual plant loading when on-line. ∑ NAG NOF = ×100 ∑(CTH × NMC)

78 GADS WTG Data Reporting Instructions – January 2010 Appendix E – Performance Equations

Pooled Performance Rates

2.A.11. Resource Equivalent Planned Outage Rate (REPOR) Probability of planned plant downtime when needed for load. ∑ PTH REPOR = ×100 ∑(CTH + PTH )

2.A.12. Resource Equivalent Maintenance Outage Rate (REMOR) Probability of maintenance plant downtime when needed for load. ∑ MTH REMOR = ×100 ∑(CTH + MTH )

2.A.13. Resource Equivalent Forced Outage Rate (REFOR) Probability of forced plant downtime when needed for load. ∑(FTH + RUTH ) REFOR = ×100 ∑(CTH + FTH + RUTH )

2.A.14. Resource Equivalent Unplanned Outage Rate (REUOR) Probability of forced or maintenance plant downtime (including high and low winds) when needed for load. ∑(FTH + MTH + RUTH ) REUOR = ×100 ∑(CTH + FTH + MTH + RUTH )

2.A.15. Resource Equivalent Scheduled Outage Rate (RESOR) Probability of maintenance or planned plant downtime when needed for load. ∑(MTH + PTH ) RESOR = ×100 ∑(CTH + MTH + PTH )

GADS WTG Data Reporting Instructions – January 2010 79 Appendix E – Performance Equations

B. Pooled Equipment Performance Factors

2.B.1. Equipment Equivalent Availability Factor (EEAF) % of period that the WTG equipment was available. ∑(CTH + RSTH + RUTH ) EEAF = ×100 ∑ PDTH

2.B.2. Equipment Equivalent Unavailability Factor (EEUF) % of period that the WTG equipment was unavailable. ∑(FTH + MTH + PTH ) EEUF = ×100 ∑ PDTH

2.B.3. Equipment Equivalent Planned Outage Factor (EEPOF) % of period that the WTG equipment was in planned downtime. ∑ PTH EEPOF = ×100 ∑ PDTH

2.B.4. Equipment Equivalent Maintenance Outage Factor (EEMOF) % of period that the WTG equipment was in maintenance downtime. ∑ MTH EEMOF = ×100 ∑ PDTH

2.B.5. Equipment Equivalent Forced Outage Factor (EEFOF) % of period that the WTG equipment was forced off line. Including low and high winds. FTH EEFOF = ∑ ×100 ∑ PDTH

2.B.6. 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 ) EEOUF = ×100 ∑ PDTH

80 GADS WTG Data Reporting Instructions – January 2010 Appendix E – Performance Equations

2.B.7. Equipment Equivalent Scheduled Outage Factor (EESOF) % of period that the WTG equipment was unavailable due to maintenance and planned downtime. ∑(MTH + PTH ) EESOF = ×100 ∑ PDTH

2.B.8. Equipment Generating Factor (EGF) % of period that the WTG equipment was online and in a generating state. ∑CTH EGF = ×100 ∑(PDTH − RUTH )

2.B.9. Equipment Net Capacity Factor (ENCF) % of actual WTG equipment generation. ∑ NAG ENCF = ×100 ∑((PDTH − RUTH )× NMC)

Pooled Equipment Performance Rates

2.B.10. Equipment Equivalent Planned Outage Rate (EEPOR) Probability of planned WTG equipment downtime when needed for load. ∑ PTH EEPOR = ×100 ∑(CTH + PTH + RUTH )

2.B.11. Equipment Equivalent Maintenance Outage Rate (EEMOR) Probability of maintenance WTG equipment downtime when needed for load. ∑ MTH EEMOR = ×100 ∑(CTH + MTH + RUTH )

2.B.12. Equipment Equivalent Forced Outage Rate (EEFOR) Probability of forced WTG equipment downtime when needed for load. ∑ FTH EEFOR = ×100 ∑(CTH + FTH + RUTH )

GADS WTG Data Reporting Instructions – January 2010 81 Appendix E – Performance Equations

2.B.13. 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 ) EEUOR = ×100 ∑(CTH + FTH + MTH + RUTH )

2.B.14. Equipment Equivalent Scheduled Outage Rate (EESOR) Probability of maintenance or planned WTG equipment downtime when needed for load. ∑(MTH + PTH ) EESOR = ×100 ∑(CTH + MTH + PTH + RUTH )

82 GADS WTG Data Reporting Instructions – January 2010 Appendix E – Performance Equations

SECTION 3: Resource and Equipment Calculations without OMC Hours

A. Performance Factors (including resources without OMC hours)

3.A.1. OMC Resource Equivalent Availability Factor (XREAF) % of period that the plant was available. [PDTH − (FTH + MTH + PTH + RUTH )− (oFTH + oMTH + oPTH )] XREAF = ×100 ≈ (100 − XREUF) PDTH

3.A.2. OMC Resource Equivalent Unavailability Factor (XREUF) % of period that the plant was unavailable. (FTH + MTH + PTH + RUTH )− (oFTH + oMTH + oPTH ) XREUF = ×100 ≈ (100 − XREAF) PDTH

3.A.3. OMC Resource Equivalent Planned Outage Factor (XREPOF) % of period that the plant was in planned downtime. (PTH − oPTH ) XREPOF = ×100 PDTH

3.A.4. OMC Resource Equivalent Maintenance Outage Factor (XREMOF) % of period that the plant was in maintenance downtime. (MTH − oMTH ) XREMOF = ×100 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 − oFTH )+ RUTH ] XREFOF = ×100 PDTH

3.A.6. OMC Resource Equivalent Unplanned Outage Factor (XREUOF) % of period that the plant was unavailable due to forced and maintenance downtime. For generation resource planning. [(FTH + MTH + RUTH ) − (oFTH + oMTH )] XREOUF = ×100 PDTH

GADS WTG Data Reporting Instructions – January 2010 83 Appendix E – Performance Equations

3.A.7. OMC Resource Equivalent Scheduled Outage Factor (XRESOF) % of period that the plant was unavailable due to maintenance and planned downtime. [(MTH + PTH + RUTH )− (oMTH + oPTH )] XRESOF = ×100 PDTH

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. (PTH − oPTH ) XREPOR = ×100 [CTH + (PTH − oPTH )]

3.A.9. OMC Resource Equivalent Maintenance Outage Rate (XREMOR) Probability of maintenance plant downtime when needed for load. (MTH − oMTH ) XREMOR = ×100 [CTH + (MTH − oMTH )]

3.A.10. OMC Resource Equivalent Forced Outage Rate (XREFOR) Probability of forced plant downtime when needed for load. [(FTH − oFTH )+ RUTH ] XREFOR = ×100 [CTH + (FTH − oFTH )+ RUTH ]

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. [(FTH + MTH + RUTH )− (oFTH + oMTH )] XREUOR = ×100 CTH + [(FTH + MTH + RUTH )− (oFTH + oMTH )]

3.A.12. OMC Resource Equivalent Scheduled Outage Rate (XRESOR) Probability of maintenance or planned plant downtime when needed for load. [(MTH + PTH )− (oMTH + oPTH )] XRESOR = ×100 [(CTH + MTH + PTH )− (oMTH + oPTH )]

84 GADS WTG Data Reporting Instructions – January 2010 Appendix E – Performance Equations

B. Equipment Performance Factors (without OMC hours)

3.B.1. OMC Equipment Equivalent Availability Factor (XEEAF) % of period that the WTG equipment was available. [(CTH + RSTH + RUTH )− (oFTH + oMTH + oPTH )] XEEAF = ×100 PDTH

3.B.2. OMC Equipment Equivalent Unavailability Factor (XEEUF) % of period that the WTG equipment was unavailable. [(FTH + MTH + PTH )− (oFTH + oMTH + oPTH )] XEEUF = ×100 PDTH

3.B.3. OMC Equipment Equivalent Planned Outage Factor (XEEPOF) % of period that the WTG equipment was in planned downtime. (PTH − oPTH ) XEEPOF = ×100 PDTH

3.B.4. OMC Equipment Equivalent Maintenance Outage Factor (XEEMOF) % of period that the WTG equipment was in maintenance downtime. (MTH − oMTH ) XEEMOF = ×100 PDTH

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. (FTH − oFTH ) XEEFOF = ×100 PDTH

3.B.6. OMC Equipment Equivalent Unplanned Outage Factor (XEEUOF) % of period that the WTG equipment was unavailable due to forced and maintenance downtime. For generation resource planning. [(FTH + MTH )− (oFTH + oMTH )] XEEOUF = ×100 PDTH

3.B.7. OMC Equipment Equivalent Scheduled Outage Factor (XEESOF) % of period that the WTG equipment was unavailable due to maintenance and planned downtime. [(MTH + PTH )− (oMTH + oPTH )] XEESOF = ×100 PDTH

GADS WTG Data Reporting Instructions – January 2010 85 Appendix E – Performance Equations

Equipment Performance Rates (without OMC hours)

3.B.8. OMC Equipment Equivalent Planned Outage Rate (XEEPOR) Probability of planned WTG equipment downtime when needed for load. (PTH − oPTH ) XEEPOR = ×100 [CTH + (PTH − oPTH )]

3.B.9. OMC Equipment Equivalent Maintenance Outage Rate (XEEMOR) Probability of maintenance WTG equipment downtime when needed for load. (MTH − oMTH ) XEEMOR = ×100 [CTH + (MTH − oMTH )]

3.B.10. OMC Equipment Equivalent Forced Outage Rate (XEEFOR) Probability of forced WTG equipment downtime when needed for load. (FTH − oFTH ) XEEFOR = ×100 [CTH + (FTH − oFTH )]

3.B.11. 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 )− (oFTH + oMTH )] XEEUOR = ×100 CTH + [(FTH + MTH )− (oFTH + oMTH )]

3.B.12. OMC Equipment Equivalent Scheduled Outage Rate (XEESOR) Probability of maintenance or planned WTG equipment downtime when needed for [(MTH + PTH )− (oMTH + oPTH )] load. XEESOR = ×100 CTH + [(MTH + PTH )− (oMTH + oPTH )]

86 GADS WTG Data Reporting Instructions – January 2010 Appendix E – Performance Equations

SECTION 4: Multi-Resource and Multi-Equipment Calculations without OMC Hours

A. Pooled Performance Factors (including resources without OMC hours)

4.A.1. OMC Resource Equivalent Availability Factor (XREAF) % of period that the plant was available. ∑[PDTH − (FTH + MTH + PTH + RUTH )− (oFTH + oMTH + oPTH )] XREAF = ×100 ≈ (100 − XREUF) ∑ PDTH

4.A.2. OMC Resource Equivalent Unavailability Factor (XREUF) % of period that the plant was unavailable. ∑(FTH + MTH + PTH + RUTH )− (oFTH + oMTH + oPTH ) XRUF = ×100 ≈ (100 − XREAF) ∑ PDTH

4.A.3. OMC Resource Equivalent Planned Outage Factor (XREPOF) % of period that the plant was in planned downtime. ∑(PTH − oPTH ) XREPOF = ×100 ∑ PDTH

4.A.4. OMC Resource Equivalent Maintenance Outage Factor (XREMOF) % of period that the plant was in maintenance downtime. ∑(MTH − oMTH ) XREMOF = ×100 ∑ PDTH

4.A.5. OMC Resource Equivalent Forced Outage Factor (XREFOF) % of period that the plant was forced off line. Including low and high winds. ∑[(FTH − oFTH )+ RUTH ] XREFOF = ×100 ∑ PDTH

GADS WTG Data Reporting Instructions – January 2010 87 Appendix E – Performance Equations

4.A.6. OMC Resource Equivalent Unplanned Outage Factor (XREUOF) % of period that the plant was unavailable due to forced and maintenance downtime. For generation resource planning. ∑[(FTH + MTH + RUTH ) − (oFTH + oMTH )] XREUOF = ×100 ∑ PDTH

4.A.7. OMC Resource Equivalent Scheduled Outage Factor (XRESOF) % of period that the plant was unavailable due to maintenance and planned downtime. ∑[(MTH + PTH + RUTH )− (oMTH + oPTH )] XRESOF = ×100 PDTH ∑

Pooled Performance Rates (including resources without OMC hours)

4.A.8. OMC Resource Equivalent Planned Outage Rate (XREPOR) Probability of planned plant downtime when needed for load. ∑(PTH − oPTH ) XREPOR = ×100 ∑[CTH + (PTH − oPTH )]

4.A.9. OMC Resource Equivalent Maintenance Outage Rate (XREMOR) Probability of maintenance plant downtime when needed for load. ∑(MTH − oMTH ) XREMOR = ×100 ∑[CTH + (MTH − oMTH )]

4.A.10. OMC Resource Equivalent Forced Outage Rate (XREFOR) Probability of forced plant downtime when needed for load. ∑[(FTH − oFTH )+ RUTH ] XREFOR = ×100 ∑[CTH + (FTH − oFTH )+ RUTH ]

4.A.11. OMC Resource Equivalent Unplanned Outage Rate (XREUOR) Probability of forced or maintenance plant downttime (including high and low winds) when needed for load. ∑[(FTH + MTH + RUTH )− (oFTH + oMTH )] XREUOR = ×100 ∑CTH + [(FTH + MTH + RUTH )− (oFTH + oMTH )]

88 GADS WTG Data Reporting Instructions – January 2010 Appendix E – Performance Equations

4.A.12. OMC Resource Equivalent Scheduled Outage Rate (XRESOR) Probability of maintenance or planned plant downtime when needed for load. ∑[(MTH + PTH )− (oMTH + oPTH )] XRESOR = ×100 ∑[(CTH + MTH + PTH )− (oMTH + oPTH )]

B. Pooled Equipment Performance Factors (without OMC hours)

4.B.1. OMC Equipment Equivalent Availability Factor (XEEAF) % of period that the WTG equipment was available. ∑(CTH + RSTH + RUTH )− (oFTH + oMTH + oPTH ) XEEAF = ×100 ∑ PDTH

4.B.2. OMC Equipment Equivalent Unavailability Factor (XEEUF) % of period that the WTG equipment was unavailable. ∑(FTH + MTH + PTH − (oFTH + oMTH + oPTH )) XEEUF = ×100 ∑ PDTH

4.B.3. OMC Equipment Equivalent Planned Outage Factor (XEEPOF) % of period that the WTG equipment was in planned downtime. ∑(PTH − oPTH ) XEEPOF = ×100 ∑ PDTH

4.B.4. OMC Equipment Equivalent Maintenance Outage Factor (XEEMOF) % of period that the WTG equipment was in maintenance downtime. ∑(MTH − oMTH ) XEEMOF = ×100 ∑ PDTH

4.B.5. OMC Equipment Equivalent Forced Outage Factor (XEEFOF) % of period that the WTG equipment was forced off line. Including low and high winds. ∑(FTH − oFTH ) XEEFOF = ×100 ∑ PDTH

GADS WTG Data Reporting Instructions – January 2010 89 Appendix E – Performance Equations

4.B.6. OMC Equipment Equivalent Unplanned Outage Factor (XEEUOF) % of period that the WTG equipment was unavailable due to forced and maintenance downtime. For generation resource planning. ∑[(FTH + MTH ) − (oFTH + oMTH )] XEEUOF = ×100 ∑ PDTH

4.B.7. OMC Equipment Equivalent Scheduled Outage Factor (XEESOF) % of period that the WTG equipment was unavailable due to maintenance and planned downtime. ∑[(MTH + PTH )− (oMTH + oPTH )] XEESOF = ×100 ∑ PDTH

Pooled Equipment Performance Rates (without OMC hours)

4.B.8. OMC Equipment Equivalent Planned Outage Rate (XEEPOR) Probability of planned WTG equipment downtime when needed for load. ∑(PTH − oPTH ) XEEPOR = ×100 ∑[CTH + (PTH − oPTH )]

4.B.9. OMC Equipment Equivalent Maintenance Outage Rate (XEEMOR) Probability of maintenance WTG equipment downtime when needed for load. ∑(MTH − oMTH ) XEEMOR = ∑[CTH + (MTH − oMTH )]

4.B.10. OMC Equipment Equivalent Forced Outage Rate (XEEFOR) Probability of forced WTG equipment downtime when needed for load. ∑(FTH − oFTH ) XEEFOR = ×100 ∑(CTH + FTH − oFTH )

4.B.11. OMC Equipment Equivalent Unplanned Outage Rate (XEEUOR) Probability of forced or maintenance WTG equipment downtime (including high and low winds) when needed for load. ∑[(FTH + MTH ) − (oFTH + oMTH )] XEEUOR = ×100 ∑CTH + [(FTH + MTH ) − (oFTH + oMTH )]

90 GADS WTG Data Reporting Instructions – January 2010 Appendix E – Performance Equations

4.B.12. OMC Equipment Equivalent Scheduled Outage Rate (XEESOR) Probability of maintenance or planned WTG equipment downtime when needed for load. ∑[(MTH + PTH ) − (oMTH + oPTH )] XEESOR = ×100 ∑CTH + [(MTH + PTH ) − (oMTH + oPTH )]

GADS WTG Data Reporting Instructions – January 2010 91 Appendix E – Performance Equations

92 GADS WTG Data Reporting Instructions – January 2010 Appendix F – Manufacturers

Appendix F – Manufacturers

The table below contains a list of the turbine manufacturers collected in the sub-group data (page 19, column 11) of these data reporting instructions. If you would like to add a manufacturer to this list please e-mail your request to Mike Curley at [email protected].

Turbine Manufacturer Entry Clipper CL DanWind DW Denertec S.A.C. DT Earth Wind and Power LLC EWP Enercon Gmbh EC General Electric GE Green Energy Technologies GET Kenetech KE MHI MHI Micon MI Nordex NX Prime Wind Power International PW R.E. Power Systems Ag REP Stock Equipment Co. SE Urban Green Energy UGE Vestas VES Wind Energy Solutions WES Winwind WW Zond ZD Other OTHER

GADS WTG Data Reporting Instructions – January 2010 93 Appendix F – Manufacturers

94 GADS WTG Data Reporting Instructions – January 2010 Appendix G – Outside Management Control

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.

OMC events are included as a curtailment for Resource equations but not for equipment equations.

OMC events can be Planned, Maintenance, or Forced Outage or Derating Events.

The following 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 that 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 those actions outside plant management control than to identify 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:

. Grid connection or substation failure. This reason 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 (of this WTG documents).

. Acts of nature such as ice storms, tornados, winds, lightning, etc are not under plant management control, whether inside or outside the plant boundary.

GADS WTG Data Reporting Instructions – January 2010 95 Appendix G – Outside Management Control

. Terrorist attacks on the generating/transmission facilities or transmission operating/repair errors are not under plant management control.

. 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 equipment 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. These strikes may be company-wide problems or strikes outside the company’s jurisdiction such as manufacturers (delaying repairs) or transportation (fuel supply) problems.

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 within plant management control.

96 GADS WTG Data Reporting Instructions – January 2010 Appendix H – Examples

Appendix H – Examples

Forced Events:

. The off-taker calls and indicates that a truck has damaged a pole on the line carrying power from the site. The repair cannot wait and power will be down for a few hours. Totaled as FTH and oFTH. . Component failures – towers, generators, controllers & etc. Total as FTH. . Trips – overproduction, vibration, icing & etc. . LS generator identified as bad, but fails before we can replace it. . Underground cable failure. . A turbine fails a hydraulic motor. There is no wind anywhere in the area. In fact no power has been made on any turbine for over a week. . Safety shutdown due to an approaching storm. . WTGs shedding ice on local highway. The turbines were shutdown due to safety concerns. . A turbine has been repeatedly faulting on pitch asymmetry. Last night alone it faulted 6 times. The turbine is shut down to determine root cause and repair. History indicates that the turbine is not capable of running until the following week without faulting. . Turbines are shutting down for high ambient temperature. . Severe icing on the sites overhead lines cause the overhead line to fail. . Contractor hits an underground HV cable. The site trips off and the cable requires repair. . Five turbines were found down in the morning due to stolen generator cables. . Oily rags left in a nacelle spontaneously catch fire and burn up the nacelle. . Lightning strikes and welds one of the pitch bearings in the pitched-up position. . Ice freezes the anemometer on a turbine. It may or may not have heaters. Heater or no heater determines which bucket not the event type. If it has a heater then it is controller FO. If it does not have a heater than it is weather FO. . A gearbox endplay is identified as beyond tolerance and is scheduled for replacement but the gearbox fails before replacement.

Forced OMC Events:

. The off-taker calls and indicates that a truck has damaged a pole on the line carrying power from the site. The repair cannot wait and power will be down for a few hours. . Safety shutdown due to an approaching storm. . WTGs are shedding ice on local highway. The turbines were shutdown due to safety concerns. . Turbines are shutting down for high ambient temperature. . Severe icing on the sites overhead lines cause the overhead line to fail. . Contractor hits an underground HV cable. The site trips off and the cable requires repair. . Five turbines were found down in the morning due to stolen generator cables. . Lightning strikes and welds one of the pitch bearings in the pitched-up position.

GADS WTG Data Reporting Instructions – January 2010 97 Appendix H – Examples

. Ice freezes the anemometer on a turbine. It may or may not have heaters. Heater or no heater determines which bucket not the event type. If it has a heater then it is controller FO. If it does not have a heater than it is weather oFTH.

Maintenance Events:

• Brand X manufacturer has developed a new operating program for their WTG and all turbines are scheduled for installation of the update. . Brand Y gearbox endplay is identified as beyond tolerance and is scheduled for replacement. The WTG ran until replacement 1 month later. . Gases are slightly high in transformer. The transformer is monitored and replaced when convenient. . A hydraulic pump was identified as off spec and put into continuous mode and run until repairs can be made. . A slip ring needs repair but will last till next week before repairing. . Transformer IR inspections reveal a hot elbow connection. Repairs are scheduled and take place a month later. . The Brand Z fleet is experiencing high failure rates on their generators. The engineer wants to perform condition assessment using Video Probe. . Brand X turbines are experiencing nacelle frame cracks. The fleet team wants to know what the extent of the cracking and a condition assessment plan is developed. . A contractor damages an HV cable. Repairs are made 2 weeks later.

Planned Events:

. Substation maintenance. . WTG preventative maintenance. . Retrofit. . Planned Off-Taker outages. . Gearbox oil changes. . The Off-Taker is upgrading their system and power reduction is required.

98 GADS WTG Data Reporting Instructions – January 2010