FRS Form 1 (in BAL-003 Reliability Std)

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Overview

Instructions
Data Entry
Form 714 Data
Adjustments
Variable Bias Supplemental Info
BA Form 2 Event Data
TimeZone Ref
Event Frequency Graphs
Frequency Response Initiative

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Sheet 1: Instructions

Instructions
Step 1	Enter data in all green cells on the "Data Entry" worksheet. Cell G1 with the BA name. Cells R11 through R13 with contact information. Cell R24 with BA Bias Type, Fixed or Variable.
Step 2	For identified events in column C of the "Data Entry" worksheet, collect data and complete one FRS Form 2 workbook for each event in the list.
	Detailed Instructions for utilizing the "Adjustments" are located on the "Adjustments" worksheet below the table.
Step 3	PasteSpecial/Values data from FRS Form 2 "Form 1 Summary Data" worksheet into "BA Form 2 Event Data" worksheet of this workbook. Do this for each event in the list.
Step 4	Enter FERC Form 714 data from the most recent completed Form 714 in the worksheet "Form 714 Data" in cells C7 through D18. Use Copy/PasteSpecial/Values to enter data.
	Your current year's Frequency Response Obligation will be calculated in cell R20 of the "Data Entry" worksheet.
Step 5	a) If a Fixed Bias was selected, cell R27 will calculate the minimum Bias (least negative) allowed based on your Peak Demand or Peak Generation for Generation only BAs.
	b) If a Fixed Bias was selected, cell R28 will calculate the minimum (in absolute terms) Bias allowed based on 100% of your FRM.
	c) If a Fixed Bias was selected, cell R29 will calculate the maximum Bias (in absolute terms) allowed based on 125% of your FRM.
	d) If R29 was more negative than the value in R27, you may choose a Bias setting that is between R29 and the lesser of R27 or R28 and enter it here. Based on your choice, your Bias Setting will appear in cell R33.
Step 6	a) If a Variable Bias was selected, cell R27 will indicate "not applicable" where there is no maximum or minimum Bias Setting.
	b) If a Variable Bias was selected, enter "Variable" in cell R31.
	c) If a Variable Bias was selected, cell R30 will calculate the minimum Bias (in absolute terms) allowed based on your FRM and Peak Demand/Peak Generation. Calculate your monthly one minute average Variable Bias setting when frequency is lower than 59.964 Hz or higher than 60.036 Hz and enter these monthly values on the "Variable Bias Supplemental Info" worksheet in cells B2 through D13.
	d) If the "average annual Variable Bias Setting" in cell D14 on the "Variable Bias Supplemental Info" worksheet is less negative than cell E14 of this worksheet, R3 of the standard has not been met and cell D14 on the "Variable Bias Supplementa Info" worksheet will turn red. The average minimum Bias Setting will cover two different reporting periods and Cells J3 through K10 require past year's data from those year's Form 1s for this evaluation.
	e) Depending on when the Implementation date is each year for the annual Bias Setting, the ERO may be required to edit the selection of each months' minimum average FBS value. This should be completed by the ERO before each year's FRS Form 1 is published.
	f) The comparison to the FBS minimum will be from two previous year's analysis prior to the current year and the dates in the table starting at J3 will indicate the appropriate year's data to use. For example, if it is Feb 1, 2013 and you are calculating your 2012 FBS time weigted average, the minimum FBS value will be determined from your FRM that you calculated in Feb of 2012 and based on the Peak Demand/Peak Gen reported in June of 2011 for 2010 data. Enter each field in green using the appropriate year's data.
Step 7	Two FRMs are calculated. One for the BA Bias Setting and one for meeting R1 of the standard.
	The FRM for the BA Bias Setting will use all selected events and all SEFRD values will use the delta frequency as measured.
	The FRM for the BA compliance to R1 will limit the delta frequency to no greater than those listed in Table 2 of Attachment A for each Interconnection. (Eastern +/-0.500 Hz, Western +/-0.500 Hz, ERCOT +/-0.700 Hz and HQ +/-1.500 Hz.)
Step 7	Save this workbook using the following file name format:NYISO_yyyy_FRS_Form_1.9.xlsx. (where NYISO is replaced with your Balancing Authority abbreviation). See cell "G74" on the Data Entry worksheet for your exact file name.
Step 8	Send completed Form 1 and each Form 2 to NERC.

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Sheet 2: Data Entry

					Balancing Authority	MyBA		NERC FRS FORM 1 20 to 52 second Value B										Enter Addition Data in column W ==>			Information		Select Reason(s) for adjustment																													Columns BA, BB, BC, BD, BE, BF and BG are reserved for calculation of the linear regression.
Event	UTC (t-0)	Date/Time (t-0)	Time	Date/Time (t-0)	BA		BA	BA	Relay Lmt	Value "A" Information		Value "B" Information		SEFRD (FRM)		Exclude for		Enter Data in Green Highlighted Cells			Value "A"	Value "B"																														BA Delta	10 X BA	10 X BA	SEFRDB	SEFRDR	Regression
					Time			Bias	R1					for Bias	for R1																																					NAI	DelFreq	DelFreq	(MW/0.1Hz)	(MW/0.1Hz)	Statistics
Number	Date / Time (MM/DD/YY HH:MM:SS)	(Central Prevailing)	Zone	BA Time	Zone	DelFreq	Time	DelFreq	DelFreq	NAI	Adjustment	NAI	Adjustment	(MW/0.1Hz)	(MW/0.1Hz)	data error *	0.9	Send copy to:	[email protected]		Load	Load	Reason(s)																														For Bias	For R1			For Bias
1	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0	#DIV/0!	0.0	N	0.0				0.0	0.0																		-0.058	23.2			Dynamic schedules for joint-owned units (DS)								0	0	595	#DIV/0!	0	#VALUE!	#VALUE!
2	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0	#DIV/0!	0.0	N	0.0				0.0	0.0																		-0.066	27.7			Nonconforming load (NL)								0	0	595	#DIV/0!	0	#VALUE!	#VALUE!
3	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0	#DIV/0!	0.0	N	0.0				0.0	0.0																		-0.040	10.7			Pumped hydro (PH)								0	0	595	#DIV/0!	0	#VALUE!	#VALUE!
4	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0	#DIV/0!	0.0	N	0.0	1900	Bias Calculation Form 1 for Year		0.0	0.0																		-0.052524929954899	80.6608905519758			Invalid Data (ID)								0	0	595	#DIV/0!	0	#VALUE!	#VALUE!
5	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0	#DIV/0!	0.0	N	0.0	Eastern	Interconnection		0.0	0.0																		-0.070905231294198	-26.8976089613778			Transfered Frequency Response (TFR)								0	0	595	#DIV/0!	0	#VALUE!	#VALUE!
6	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0	#DIV/0!	0.0	N	0.0	MyBA	Balancing Authority		0.0	0.0																		-0.051906767345699	9.95544917881489			Contingent BA adjustment for loss of units (CBA)								0	0	595	#DIV/0!	0
7	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0	#DIV/0!	0.0	N	0.0		Contact Name		0.0	0.0																		-0.058047703334303	3.36702401297433			DS & NL								0	0	595	#DIV/0!	0	For R1
8	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0	#DIV/0!	0.0	N	0.0		Contact Phone #		0.0	0.0																		-0.075572422572499	36.3344268798828			DS & PH								0	0	595	#DIV/0!	0	0	0
9	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0	#DIV/0!	0.0	N	0.0		Contact e-mail		0.0	0.0																		-0.056380498976999	0.488253044359624			DS & ID								0	0	595	#DIV/0!	0	0	#N/A
10	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0	#DIV/0!	0.0	N	0.0		Attachment A page 2. MWh Annual GenBA is the annual "Net Generation (MWh)", FERC Form 714, line 13, column c of Part II - Schedule 3.		0.0	0.0																		-0.057332901727598	2.75803693135579			DS & TFR								0	0	595	#DIV/0!	0	1	0
11	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0	#DIV/0!	0.0	N	0.0		Attachment A Page 2. MWh Annual LoadBA is the annual "Net Energy for Load (MWh)", FERC Form 714, line 13, column e of Part II - Schedule 3.		0.0	0.0																		-0.051760900588299	13.6434168815613			DS & CBA								0	0	595	#DIV/0!	0	#N/A	11
12	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0	#DIV/0!	0.0	N	0.0	FRSDT: NERC will update these values in the 3rd quarter of each year after completed Form 714s are available. This data is used to calculate "next" year's Frequency Response Obligation, FRO. Attachment A, page 3.	MWh Annual GenINT is the Sum of all Annual GenBA values in this interconnection		0.0	0.0																		-0.049999237060547	11.1007459163666			DS & NL & PH								0	0	595	#DIV/0!	0	0	0
13	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y			MWh Annual LoadINT is the Sum of all Annual LoadBA values in this interconnection		0.0	0.0																		-0.052	-19.9068464835485			DS & NL & ID
14	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y		-964	Interconnection Frequency Response Obligation (FRO) MW/0.1 Hz. Determined by ERO.		0.0	0.0																		-0.055999755859375	12.3254643016391			JOU DS & NL & TFR
15	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y		1899	Current data year (December thru November)		0.0	0.0																		-0.058498382568359	0.750191847483315			DS & NL & CBA
16	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y		#DIV/0!	1900 BA Frequency Response Obligation (FRO) for next year's FRM		0.0	0.0																		-0.048500061035156	2.23005777994791			DS & NL & PH & ID
17	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y			1899 BA Frequency Response Obligation (FRO) for this year's FRM from your last year's Form 1.		0.0	0.0																		-0.045000076293945	9.47785933017731			DS & NL & PH & TFR
18	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y					0.0	0.0																		-0.037502288818359	0.355309009552002			DS & NL & PH & CBA
19	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y			BA Bias Type and Bias Setting		0.0	0.0																		-0.047500610351563	2.17070185343425			DS & NL & PH & ID & TFR
20	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y		Fixed	Bias Type utilized.		0.0	0.0																		-0.055500030517578	29.3820742766062			DS & NL & PH & ID & CBA
21	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y		0.90%	Interconnection Minimum Fixed Frequency Bias Setting % of Peak Demand or Peak Generation (Set by ERO)		0.0	0.0																		-0.047	4.60138130187988			DS & NL & PH & ID & TFR & CBA
22	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y		621018	The Sum of the Non-Coincident peak demands for all Bas on the interconnection from FERC Form No. 714, provided by ERO.		0.0	0.0																		-0.060000000000002	1.59351487954458			NL & PH
23	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y		#DIV/0!	Your BA's lowest absolute Fixed Frequency Bias Setting based on interconnection non-coincident peak demand.		0.0	0.0																		-0.059999999999995	52.3709077835083			NL & ID
24	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y		#DIV/0!	Your BA's lowest absolute Fixed Frequency Bias Setting based on 100% of FRM.		0.0	0.0																		-0.051000000000002	33.9478736718496			NL & TFR
25	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y		#DIV/0!	Your BA's highest absolute Fixed Bias Setting: 125% of FRM.		0.0	0.0																		-0.1	100			NL & CBA
26	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y		n/a	Balancing Authority lowest absolute Variable Bias Setting (least negative one minute average Bias while frequency is less than 59.964 or greater than 60.036 Hz).		0.0	0.0																						NL & PH & ID
27	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y		-20.87	Balancing Authority desired Bias Setting: May be set to a value between 100% to 125% of its FRM if this value is more negative than the minimum Bias based on Peak Demand. If not more negative, then the Bias must be the minimum Bias based on Peak Demand. If variable Bias is used, enter "Variable".		0.0	0.0																						NL & PH & TFR
28	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y					0.0	0.0																						NL & PH & BAA
29	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y		#DIV/0!	1900 Frequency Bias Setting - (minimum of 100% to 125% of FRM, or 0.9% of Historical Peak Demand if not Variable)		0.0	0.0																						NL & PH & ID & TFR
30	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y					0.0	0.0																			N			NL & PH & ID & CBA
31	12/30/1899 6:00:00		CST	12/30/1899 0:00:00	CST		0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y		#DIV/0!	1899 FRM - Average Estimated Frequency Response MW/0.1 Hz using SEFRD for Bias		0.0	0.0																			Y			NL & PH & ID & TFR & CBA
32							0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y		#VALUE!	1899 FRM - Regression Estimated Frequency Response MW/0.1Hz using SEFRD for Bias		0.0	0.0																						PH & ID
33							0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y		#DIV/0!	1899 FRM - Median Estimated Frequency Response MW/0.1Hz using SEFRD for Bias		0.0	0.0																						PH & TFR
34							0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y		0.00	1899 FRM - Average Estimated Frequency Response MW/0.1 Hz using SEFRD for R1		0.0	0.0																						PH & CBA
35							0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y		0.00	1899 FRM - Regression Estimated Frequency Response MW/0.1Hz using SEFRD for R1		0.0	0.0																						PH & ID & TFR
36							0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y		0.00	1899 FRM - Median Estimated Frequency Response MW/0.1Hz for BA Compliance to R1, minimum Frequency Response		0.0	0.0																						PH & ID & CBA
37							0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y		N	Do you RECEIVE Overlap regulation?		0.0	0.0																						PH & TFR
38							0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y			If Yes, list the BA name and the associated Bias of that BA in the table below.		0.0	0.0																						PH & CBA
39							0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y					0.0	0.0																						PH & ID & TFR
40							0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y		Bias -MW/0.1 Hz	Balancing Authority		0.0	0.0																						PH & ID & CBA
41							0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y					0.0	0.0																						PH & TFR
42							0:00:00	0.000	0.000	0.0	0.0	0.0	0.0			Y					0.0	0.0																						PH & CBA
																																												PH & ID & TFR & CBA
																																												RU & TFR
																																												RU & CBA
																																												RU & TFR & CBA
																																												TFR & CBA
																		N	Do you PROVIDE Overlap regulation?
																			If Yes, list the BA name and the associated Bias of that BA																						N
																																									Y
																		Bias -MW/0.1 Hz	Balancing Authority
																																									Fixed
																																									Variable
		Instructions																																								Relay Limits
																																									Eastern	59.5	60.5
		Step 1				Enter data in all green cells on this "Data Entry" worksheet.																																			Western	59.5	60.5
																																									ERCOT	59.3	60.7
		Step 2				For identified events in column B, collect data and complete FRS Form 2.9 for each event in the list.																																			HQ	58.5	61.5
		Step 3				PasteSpecial/Values data from FRS Form 2.9 "Form 1 Summary Data" into "BA Form 2 Data" worksheet of this workbook. Do this for each event in the list.
		Step 4				Save this workbook using the following file name format:NYISO_yyyy_FRS_Form_1.9.xlsm and send a copy of this workbook and all FRS_Form 2 workbooks to NERC. (where NYISO is replaced with your BA name)
						MyBA_1900_FRS_Form_1.9.xlsm

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Sheet 3: Form 714 Data

Report 714 Data (in MW)
Part II Schedule 3
Column (b)	Column (j)
Month	Peak Demand
January
February					Peak Demand: (Your BA from Form 714, column j of Part II - Schedule 3)
March
April
May
June
July
August
September
October
November
December
Average	#DIV/0!
Maximum	0

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Sheet 4: Adjustments

	Balancing Authority	MyBA	JOU Dynamic Schedules			Non conforming Load			Pumped Hydro			Not Used			Transferred Frequency Response			Contingent BA Adjustment			Net Total Adjustments
Event	Date/Time (t-0)		Value A	Value B		Value A	Value B		Value A	Value B		Value A	Value B		Value A	Value B		Value A	Value B		Value B 20 to 52 seconds
Number	(Central Prevailing)	DelFreq	Adjustment	Adjustment		Adjustment	Adjustment		Adjustment	Adjustment		Adjustment	Adjustment		Adjustment	Adjustment		Adjustment	Adjustment
1			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
2			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
3			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
4			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
5			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
6			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
7			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
8			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
9			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
10			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
11			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
12			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
13			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
14			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
15			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
16			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
17			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
18			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
19			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
20			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
21			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
22			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
23			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
24			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
25			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
26			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
27			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
28			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
29			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
30			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
31			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
32			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
33			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
34			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
35			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
36			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
37			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
38			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
39			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
40			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
41			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
42			0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0	0.0		0.0
	Sign Convention for scan data collected in Form 2		Imports: MWs are - Exports: MWs are +			Loads in MW as -			Load MW as - Generation MW as +			Enter Gen MW as +			The transactional amount in MW Receiver enters - Deliverer enters + on Form 2 Data sheet			Generation MW as + (If demand occurs due to gen loss, enter MW as - at value B)
	Instructions for utilizing Adjustments:
	1)	Balancing Authorities making adjustments must retain evidence to verify: - Adjustment values are determined from scan-cycle data using Value A and Value B averaging periods. Scan-cycle data must be available if adjustments are made. - Adjustments are necessary to improve accuracy of calculations compared to using Net Actual Interchange solely. Said differently, unless an adjustment compensates for significant known error, it should not be made. However, as noted in the next item, once a decision to include an adjustment for one or more of the five types is made for one event, the entity must calculate adjustments for that (those) type(s) for all events except for the Contengent BA Adjustment which is only utilized for the events that you are contengent during that event. - Adjustments are included consistently for all events (e.g. if adjustments for nonconforming load are made for one event, the load must be included for all events, etc.).
	2)	Dynamic Schedules: - Values use schedule sign convention. - Adjustments should include only dynamic schedules accounting for joint-owned units. Other dynamic schedules should be ignored.
	3)	Nonconforming Loads: - Values must be negative numbers.
	4)	Pumped Hydro: - Values for pumping must be negative values. - Values for generating must be positive values.
	5)	Rampling Units: - Values are positive values.
	6)	Transferred Frequency Response: - This value is the amount agreed upon between the entities expressed in MW/0.1 Hz. Form 2 will adjust this amount for the frequency deviation experienced. (e.g. if an entity agrees to provide 20 MW/0.1 Hz to another entity and a frequency event with a deviation of 50 mHz occurs, the delivering entity should enter +20 in the data column of Form 2 and the receiving entity should enter - 20. The spreadsheet will adjust the SEFRD for each entity by the 10 for this event.) - Values for the entity receiving the response must be entered as a negative number. - Values for the entity delivering the response must be entered as a positive number. - Values between entities must sum to zero.
	7)	Contingent Balancing Authority Adjustment: - Data for Value A is the pre-contingency scan rate generation (+MW values) from the contingent unit(s). - Data for Value B is usually 0 MW, but may be the demand (-MW values) that remains on the system that was "netted" out by the now offline generation.

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Sheet 5: Variable Bias Supplemental Info

Month

Minimum FBS* for month

Maximum FBS* for month

Time weighted ** average FBS* for month

Time weighted ** minimum average FBS* for month

January

Balancing Authority:

MyBA

Feburary

1898

Reporting period FRS Form 1 data

March

0.00

1898 Reporting period: Balancinig Authority FRM MW/0.1 Hz, enter from FRS Form 1 for that year's FRM. If not know enter zero.

April

1.00%

1898 Reporting period: Interconnection Minimum Fixed Frequency Bias Setting % of Peak Demand or Peak Generation (Set by ERO)

May

1898 Reporting period: Your BA's Annual Peak Demand or Peak Gen for Gen only BAs from your BA Form 714.

June

0.00

Your BA's lowest absolute Fixed Frequency Bias Setting based on BA Peak Demand (Peak Generation for Generation only BA) MW/0.1 Hz.

July

0.00

Your BA's lowest absolute Fixed Frequency Bias Setting based on 100% of FRM.

August

0.00

1899 Minimum, lowest absolute, conditional average Frequency Bias Setting MW/0.1 Hz.

September

1898 Minimum, lowest absolute, conditional average Frequency Bias Setting MW/0.1 Hz.

October

November

December

0.0

0.0

1899 Average Annual Bias MW/0.1 Hz

* Frequency Bias Setting (FBS)

** Based on the one minute values used in BAL 001 when frequency is greater than 60.036 Hz or less than 59.964 Hz.

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Sheet 6: BA Form 2 Event Data

Average P.U. Performance

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PasteSpecial/Values the data copied from FRS Form 2 for each event.

Value A Data

BA Performance

Value B

20 to 52 second Average Period Evaluation

Frequency Response Initiative - Additional Primary Frequency Response Evaluation Points

JOU

Non-

Transferred

Contingent

JOU

Non-

Transferred

Contingent

Average

Unadjusted

Unadjusted

Unadjusted

Unadjusted

Unadjusted

Adjusted

Adjusted

Adjusted

Adjusted

Adjusted

Date

A Point

FPointA

A Value

t(0) Time

C Value

Net

Dynamic

Conforming

Pumped

Ramping

Frequency

BA

BA

BA

Bias

Net

Dynamic

Conforming

Pumped

Ramping

Frequency

BA

Initial

Initial

Sustained

BA

BA

Bias

Bias While

PFR

PFR

PFR

PFR

PFR

PFR

PFR

PFR

PFR

PFR

Time

Hz

Hz

Hz

Actual

Schedules

Load

Hydro

Units

Response

Lost Generation

Bias

Load

Setting

Actual

Schedules

Load

Hydro

Units

Response

Lost Generation

Performance

Performance

Performance

Bias

Load

Setting

Hz > +/-0.036

Performance

Performance

Performance

Performance

Performance

Performance

Performance

Performance

Performance

Performance

Maximum

Minimum

Event

Date/Time

Frequency

Interchange

Imp(-) Exp (+)

Load (-)

Load (-) Gen (+)

Gen (+)

Rec (-) Del (+)

Load (-) Gen (+)

Setting

EPFR

Frequency

Interchange

Imp(-) Exp (+)

Load (-)

Load (-) Gen (+)

Gen (+)

Rec (-) Del (+)

Load (-) Gen (+)

Adjusted

Unadjusted

Setting

EPFR

Hz

@ T(+46)

@ T(+76)

@ T(+106)

@ T(+136)

@ T(+166)

@ T(+46)

@ T(+76)

@ T(+106)

@ T(+136)

@ T(+166)

Bias Setting

Bias Setting

Number

(Central Prevailing)

DelFreq

Hz

MW

MW

MW

MW

MW

MW

MW

MW/0.1 Hz

MW

MW

Hz

MW

MW

MW

MW

MW

MW

MW

P.U.

P.U.

P.U.

MW/0.1 Hz

MW

MW

MW/0.1 Hz

P.U.

P.U.

P.U.

P.U.

P.U.

P.U.

P.U.

P.U.

P.U.

P.U.

MW/0.1 Hz

MW/0.1 Hz

1

12/30/1899 0:00

0.000

2

12/30/1899 0:00

0.000

3

12/30/1899 0:00

0.000

4

12/30/1899 0:00

0.000

5

12/30/1899 0:00

0.000

6

12/30/1899 0:00

0.000

7

12/30/1899 0:00

0.000

8

12/30/1899 0:00

0.000

9

12/30/1899 0:00

0.000

10

12/30/1899 0:00

0.000

11

12/30/1899 0:00

0.000

12

12/30/1899 0:00

0.000

13

12/30/1899 0:00

0.000

14

12/30/1899 0:00

0.000

15

12/30/1899 0:00

0.000

16

12/30/1899 0:00

0.000

17

12/30/1899 0:00

0.000

18

12/30/1899 0:00

0.000

19

12/30/1899 0:00

0.000

20

12/30/1899 0:00

0.000

21

12/30/1899 0:00

0.000

22

12/30/1899 0:00

0.000

23

12/30/1899 0:00

0.000

24

12/30/1899 0:00

0.000

25

12/30/1899 0:00

0.000

26

12/30/1899 0:00

0.000

27

12/30/1899 0:00

0.000

28

12/30/1899 0:00

0.000

29

12/30/1899 0:00

0.000

30

12/30/1899 0:00

0.000

31

12/30/1899 0:00

0.000

32

12/30/1899 0:00

0.000

33

12/30/1899 0:00

0.000

34

12/30/1899 0:00

0.000

35

12/30/1899 0:00

0.000

36

12/30/1899 0:00

0.000

37

12/30/1899 0:00

0.000

38

12/30/1899 0:00

0.000

39

12/30/1899 0:00

0.000

40

12/30/1899 0:00

0.000

41

12/30/1899 0:00

0.000

42

12/30/1899 0:00

0.000

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Sheet 7: TimeZone Ref

Full name	Abbreviation	Offset	Time zone
Atlantic Daylight Time	ADT	3:00	UTC - 3 hours
Atlantic Standard Time	AST	4:00	UTC - 4 hours
Central Daylight Time	CDT	5:00	UTC - 5 hours
Central Standard Time	CST	6:00	UTC - 6 hours
Eastern Daylight Time	EDT	4:00	UTC - 4 hours
Eastern Standard Time	EST	5:00	UTC - 5 hours
Mountain Daylight Time	MDT	6:00	UTC - 6 hours
Mountain Standard Time	MST	7:00	UTC - 7 hours
Pacific Daylight Time	PDT	7:00	UTC - 7 hours
Pacific Standard Time	PST	8:00	UTC - 8 hours

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Sheet 8: Event Frequency Graphs

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Sheet 9: Frequency Response Initiative

FRI - NERC Frequency Response Initiative

The FRI Report made recommendations to evaluate Primary Frequency Response at additional time intervals during the event recovery period.

Additional evaluations have been added to both Form 1 and Form 2 to evaluate PFR delivery for these suggested time periods.

These evaluations utilize Interconnection frequency at specific times during the recovery period and calculates the BA's delivery of PFR for each selection.

These evaluations are not part of BAL-003 and will not impact compliance to R1 of the draft standard.

The following time selections are evaluated: T+46, T+76, T+106, T+136 and T+166.

Each evaluation is a P.U. measure based on the BA's Bias setting at each of these times.

Performance is the "best" performance at the specific time through 10 seconds past each time.

This is intended to account for any delay in data in the measurement. This measurement may be changed as experience in this effort increases.

Also included is the measure of PFR delivery during the T+20 to T+52 second period, the same as R1 of the standard.

The measure (P.U.) here is based on the BA Bias setting and not the FRO. This was done to provide comparison to the additional measurement times.

Some basic observations from this data:

1) If the P.U. value is close to 1.0, the BA delivered the full amount of PFR equal to its Bias setting.

2) The average performance of the Eastern Interconnection in PFR is about 40% of the total Interconnection Bias setting. If the BA's average score is greater

than 0.40 P.U. then they are providing more PFR than the average BA. If the P.U. is less than 40% then they are providing less than average PFR.

3) If the P.U. value at T+46 is consistently less than the P.U. value at T+20 to T+52, then the PFR of the BA is not being sustained.

4) If the P.U. value at later time interval measures is consistently less, then withdrawal of PFR is occurring at a slower rate, but still being withdrawn.

5) If the P.U. value at T+20 to T+52, T+46, or T+76 is consistently greater than 1.0, this indicates that the BA Bias setting is too low.