124 FERC ¶ 61,071 

UNITED STATES OF AMERICA 

FEDERAL ENERGY REGULATORY COMMISSION 

18 CFR Part 40 

(Docket No. RM08-7-000; Order No. 713) 

Modification of Interchange and Transmission Loading Relief Reliability Standards; and 

Electric Reliability Organization Interpretation of Specific Requirements of Four 

Reliability Standards 

(Issued July 21, 2008) 

AGENCY: Federal Energy Regulatory Commission. 

ACTION: Final Rule. 

SUMMARY: Pursuant to section 215 of the Federal Power Act, the Federal Energy 

Regulatory Commission (Commission) approves five of six modified Reliability 

Standards submitted to the Commission for approval by the North American Electric 

Reliability Corporation (NERC). The Commission directs NERC to submit a filing that 

provides an explanation regarding one aspect of the sixth modified Reliability Standard 

submitted by NERC. The Commission also approves NERC’s proposed interpretations 

of five specific requirements of Commission-approved Reliability Standards. 

EFFECTIVE DATE: This rule will become effective [30 days after publication in the 

FEDERAL REGISTER]

FOR FURTHER INFORMATION CONTACT: 

Patrick Harwood (Technical Information) 

Office of Electric Reliability 

Federal Energy Regulatory Commission 

888 First Street, NE 

Washington, DC 20426 
Docket No. RM08-7-000 - 2 - 

(202) 502-6125 

patrick.harwood@ferc.gov 

Christopher Daignault (Legal Information) 

Office of the General Counsel 

Federal Energy Regulatory Commission 

888 First Street, NE 

Washington, DC 20426 

(202) 502-8286 

christopher.daignault@ferc.gov 

SUPPLEMENTARY INFORMATION:
124 FERC ¶ 61,071 

UNITED STATES OF AMERICA 

FEDERAL ENERGY REGULATORY COMMISSION 

Modification of Interchange and Transmission Loading 

Relief Reliability Standards; and Electric Reliability 

Organization Interpretation of Specific Requirements of 

Four Reliability Standards 

Docket No. RM08-7-000 

ORDER NO. 713 

FINAL RULE 

TABLE OF CONTENTS

 Paragraph Numbers

I. Background .................................................................................................................... 2.

A. EPAct 2005 and Mandatory Reliability Standards .................................................. 2.

B. NERC Filings ........................................................................................................... 6.

C. Notice of Proposed Rulemaking............................................................................. 11.

II. Discussion................................................................................................................... 13.

A. NERC’s December 19, 2007 Filing: Interpretations of Reliability Standards...... 13.

1. BAL-001-0 – Real Power Balancing Control Performance and BAL-003-0 – 

Frequency Response and Bias ................................................................................. 14.

a. Proposed Interpretation .................................................................................. 16.

b. Comments....................................................................................................... 19.

c. Commission Determination............................................................................ 20.

2. Requirement R17 of BAL-005-0 – Automatic Generation Control................... 23.

a. Proposed Interpretation .................................................................................. 23.

b. Comments....................................................................................................... 26.

i. Whether interpretation could decrease accuracy of frequency and time error 

measurements.................................................................................................. 26.

ii. What conditions would preclude requirement to calibrate devices........... 28.

iii. Whether accuracy of devices is assured by other requirements............... 30.

c. Commission Determination............................................................................ 32.

3. Requirements R1 and R2 of VAR-002-1 Generator Operation for Maintaining 

Network Voltage Schedules .................................................................................... 35.

a. Proposed Interpretations................................................................................. 35.

b. Comments....................................................................................................... 39.

c. Commission Determination............................................................................ 40.

B. NERC’s December 21, 2007 Filing: Modification of TLR Procedure ................. 41.
Docket No. RM08-7-000 ii 

1. Background......................................................................................................... 42.

2. ERO TLR Filing, Reliability Standard IRO-006-4 ........................................... 43.

3. NOPR.................................................................................................................. 44.

4. Comments........................................................................................................... 45.

5. Commission Determination................................................................................ 46.

C. NERC’s December 26, 2007 Filing: Modification to Five “Interchange and 

Scheduling” Reliability Standards ............................................................................... 51.

1. INT-001-3 – Interchange Information and INT-004-2 – Dynamic Interchange 

Transaction Modifications....................................................................................... 52.

a. Comments....................................................................................................... 56.

b. Commission Determination ........................................................................... 57.

2. INT-005-2 – Interchange Authority Distributes Arranged Interchange, INT-006-

2 – Response to Interchange Authority, and INT-008-2 – Interchange Authority 

Distributes Status..................................................................................................... 58.

a. Comments....................................................................................................... 66.

b. Commission Determination ........................................................................... 67.

III. Information Collection Statement ............................................................................. 68.

IV. Environmental Analysis ............................................................................................ 71.

V. Regulatory Flexibility Act .......................................................................................... 72.

VI. Document Availability .............................................................................................. 73.

VII. Effective Date and Congressional Notification ....................................................... 76.
UNITED STATES OF AMERICA 

FEDERAL ENERGY REGULATORY COMMISSION 

Before Commissioners: Joseph T. Kelliher, Chairman; 

 Suedeen G. Kelly, Marc Spitzer, 

 Philip D. Moeller, and Jon Wellinghoff. 

Modification of Interchange and Transmission Loading 

Relief Reliability Standards; and Electric Reliability 

Organization Interpretation of Specific Requirements of 

Four Reliability Standards 

Docket No. RM08-7-000 

ORDER NO. 713 

FINAL RULE 

(Issued July 21, 2008) 

1. Pursuant to section 215 of the Federal Power Act (FPA),1

 the Commission 

approves five of six modified Reliability Standards submitted to the Commission for 

review by the North American Electric Reliability Corporation (NERC). The five 

Reliability Standards pertain to interchange scheduling and coordination. The 

Commission directs NERC to submit a filing that provides an explanation regarding one 

aspect of the sixth modified Reliability Standard submitted by NERC, which pertains to 

transmission loading relief (TLR) procedures. The Final Rule also approves 

interpretations of five specific requirements of Commission-approved Reliability 

Standards. 

 1

 16 U.S.C. 824o (2006). 
Docket No. RM08-7-000 - 2 - 

I. Background

A. EPAct 2005 and Mandatory Reliability Standards

2. Section 215 of the FPA requires a Commission-certified Electric Reliability 

Organization (ERO) to propose Reliability Standards for the Commission’s review. Once 

approved by the Commission, the Reliability Standards may be enforced by the ERO, 

subject to Commission oversight, or by the Commission independently.2

3. Pursuant to section 215 of the FPA, the Commission established a process to select 

and certify an ERO3

 and, subsequently, certified NERC as the ERO.4 On April 4, 2006, 

as modified on August 28, 2006, NERC submitted to the Commission a petition seeking 

approval of 107 proposed Reliability Standards. On March 16, 2007, the Commission 

issued a Final Rule, Order No. 693, approving 83 of these 107 Reliability Standards and 

directing other action related to these Reliability Standards.5

 In addition, pursuant to 

 2

 See FPA 215(e)(3), 16 U.S.C. 824o(e)(3) (2006). 

3

 Rules Concerning Certification of the Electric Reliability Organization; and 

Procedures for the Establishment, Approval, and Enforcement of Electric Reliability 

Standards, Order No. 672, FERC Stats. & Regs. ¶ 31,204, order on reh’g, Order 

No. 672-A, FERC Stats. & Regs. ¶ 31,212 (2006). 

4

 North American Electric Reliability Corp., 116 FERC ¶ 61,062 (ERO 

Certification Order), order on reh’g & compliance, 117 FERC ¶ 61,126 (ERO Rehearing 

Order) (2006), appeal docketed sub nom. Alcoa, Inc. v. FERC, No. 06-1426 (D.C. Cir. 

Dec. 29, 2006).

5

 Mandatory Reliability Standards for the Bulk-Power System, Order No. 693, 

FERC Stats. & Regs. ¶ 31,242, order on reh’g, Order No. 693-A, 120 FERC ¶ 61,053 

(2007). 
Docket No. RM08-7-000 - 3 - 

section 215(d)(5) of the FPA, the Commission directed NERC to develop modifications 

to 56 of the 83 approved Reliability Standards. 

4. In April 2007, the Commission approved delegation agreements between NERC 

and each of the eight Regional Entities, including the Western Electricity Coordinating 

Council (WECC).6

 Pursuant to such agreements, the ERO delegated responsibility to the 

Regional Entities to carry out compliance monitoring and enforcement of the mandatory, 

Commission-approved Reliability Standards. In addition, the Commission approved as 

part of each delegation agreement a Regional Entity process for developing regional 

Reliability Standards. 

5. NERC’s Rules of Procedure provide that a person that is “directly and materially 

affected” by Bulk-Power System reliability may request an interpretation of a Reliability 

Standard.7

 The ERO’s “standards process manager” will assemble a team with relevant 

expertise to address the clarification and also form a ballot pool. NERC’s Rules provide 

that, within 45 days, the team will draft an interpretation of the Reliability Standard, with 

subsequent balloting. If approved by ballot, the interpretation is appended to the 

 6

 See North American Electric Reliability Corp., 119 FERC ¶ 61,060, order on 

reh’g, 120 FERC ¶ 61,260 (2007). 

7

 NERC Rules of Procedure, Appendix 3A (Reliability Standards Development 

Procedure), at 26-27. 
Docket No. RM08-7-000 - 4 - 

Reliability Standard and filed with the applicable regulatory authority for regulatory 

approval.8

B. NERC Filings

6. As explained in the Notice of Proposed Rulemaking (NOPR),9

 this rulemaking 

proceeding consolidates and addresses three NERC filings. 

7. On December 19, 2007, NERC submitted for Commission approval five 

interpretations of requirements in four Commission-approved Reliability Standards: 

BAL-001-0 (Real Power Balancing Control Performance), Requirement R1; BAL-003-0 

(Frequency Response and Bias), Requirement R3; BAL-005-0 (Automatic Generation 

Control), Requirement R17; and VAR-002-1 (Generator Operation for Maintaining 

Network Voltage Schedules), Requirements R1 and R2.10 On April 15, 2008, NERC 

submitted a petition to withdraw the earlier request for approval of NERC’s interpretation 

 8

 We note that the NERC board of trustees approved the interpretations of 

Reliability Standards submitted by NERC for approval in this proceeding. However, 

Appendix 3A of NERC’s Rules of Procedure is silent on NERC board of trustees 

approval of interpretations before they are filed with the regulatory authority. The 

Commission is concerned that NERC’s Rules of Procedure do not properly reflect this 

approval step. 

9

 Modification of Interchange and Transmission Loading Relief Reliability 

Standards; and Electric Reliability Organization Interpretation of Specific Requirements 

of Four Reliability Standards, Notice of Proposed Rulemaking, 73 FR 22,856 (Apr. 28, 

2008), FERC Stats. & Regs. ¶ 32,632 (2008) (NOPR). 

10 In its filing, NERC identifies the Reliability Standards together with NERC’s 

proposed interpretations as BAL-001-0a, BAL-003-0a, BAL-005-0a, and VAR-002-1a. 
Docket No. RM08-7-000 - 5 - 

of BAL-003-0, Requirement R17, and instead to approve a second interpretation of 

Requirement R17 submitted by NERC in the April 15 filing. 

8. On December 21, 2007, NERC submitted for Commission approval modifications 

to Reliability Standard IRO-006-4 (Reliability Coordination – Transmission Loading 

Relief) that applies to balancing authorities, reliability coordinators, and transmission 

operators. According to NERC, the modifications “extract” from the Reliability Standard 

the business practices and commercial requirements from the current IRO-006-3 

Reliability Standard. The business practices and commercial requirements have been 

transferred to a North American Energy Standards Board (NAESB) business practices 

document. The NAESB business practices and commercial requirements have been 

included in Version 001 of the NAESB Wholesale Electric Quadrant (WEQ) Standards 

which NAESB filed with the Commission on the same day, December 21, 2007.11 

Further, the modified Reliability Standard includes changes directed by the Commission 

in Order No. 693 related to the appropriateness of using the TLR procedure to mitigate 

violations of interconnection reliability operating limits (IROL).12

9. On December 26, 2007, NERC submitted for Commission approval modifications 

to five Reliability Standards from the “Interchange Scheduling” (INT) group of 

 11 NAESB December 21, 2007 Filing, Docket No. RM05-5-005. 

12 An IROL is a system operating limit that, if violated, could lead to instability, 

uncontrolled separation, or cascading outages that adversely impact the reliability of the 

Bulk-Power System. 
Docket No. RM08-7-000 - 6 - 

Reliability Standards: INT-001-3 (Interchange Information); INT-004-2 (Dynamic 

Interchange Transaction Modifications); INT-005-2 (Interchange Authority Distributes 

Arranged Interchange); INT-006-2 (Response to Interchange Authority); and INT-008-2 

(Interchange Authority Distributes Status). NERC stated that the modifications to 

INT-001-3 and INT-004-2 eliminate waivers requested in 2002 under the voluntary 

Reliability Standards regime for entities in the WECC region. According to NERC, 

modifications to INT-005-2, INT-006-2, and INT-008-2 adjust reliability assessment time 

frames for proposed transactions within WECC.13

10. Each Reliability Standard that the ERO proposed to interpret or modify in this 

proceeding was approved by the Commission in Order No. 693. 

C. Notice of Proposed Rulemaking

11. On April 21, 2008, the Commission issued a NOPR that proposed to approve the 

six modified Reliability Standards submitted to the Commission for approval by NERC 

and to approve NERC’s proposed interpretations of five specific requirements of 

Commission-approved Reliability Standards. On May 16, 2008, the Commission 

supplemented the NOPR,14 proposing to approve NERC’s modified interpretation of 

Reliability Standard BAL-005-0, Requirement R17. 

 13 The Reliability Standards and interpretations addressed in this Final Rule 

are available on the Commission’s eLibrary document retrieval system in Docket 

No. RM08-7-000 and also on NERC’s website, http://www.nerc.com. 

14 Modification of Interchange and Transmission Loading Relief Reliability 

Standards; and Electric Reliability Organization Interpretation of Specific Requirements 

(continued) 
Docket No. RM08-7-000 - 7 - 

12. In response to the NOPR, comments were filed by the following eight interested 

persons: Alcoa Inc. (Alcoa); Independent Electricity System Operator of Ontario (IESO); 

ISO/RTO Council; International Transmission Company, Michigan Electric 

Transmission Company, LLC and Midwest LLC (collectively, ITC); Lafayette Utilities 

and the Louisiana Energy and Power Authority (Lafayette and LEPA); NERC; NRG 

Companies;15 and Southern Company Services, Inc. (Southern). 

II. Discussion

A. NERC’s December 19, 2007 Filing: Interpretations of Reliability 

Standards

13. As mentioned above, NERC submitted for Commission approval interpretations of 

five specific requirements in four Commission-approved Reliability Standards. 

1. BAL-001-0 – Real Power Balancing Control Performance and BAL003-0 – Frequency Response and Bias

14. The purpose of Reliability Standard BAL-001-0 is to maintain interconnection 

steady-state frequency within defined limits by balancing real power demand and supply 

in real-time.16 It uses two averages, covering the one-minute and ten-minute area control 

 

of Four Reliability Standards, Supplemental Notice of Proposed Rulemaking, 73 FR 

30,326 (May 27, 2008), FERC Stats. & Regs. ¶ 32,635 (2008) (Supplemental NOPR). 

15 NRG Companies includes Louisiana Generating LLC, Bayou Cove Peaking 

Power LLC, Big Cajun I Peaking Power LLC, NRG Sterlington Power LLC, and NRG 

Power Marketing, LLC. 

16 See Reliability Standard BAL-001-0. Each Reliability Standard developed by 

the ERO includes a “Purpose” statement. 
Docket No. RM08-7-000 - 8 - 

error (ACE) performance (CPS1 and CPS2, respectively), as measures for determining 

compliance with its four Requirements. Requirement R1 of BAL-001-0 obligates each 

balancing authority, on a rolling twelve-month basis, to maintain its clock-minute 

averages of ACE, modified by its frequency bias and the interconnection frequency, 

within a specific limit based on historic performance.17

15. The purpose of Reliability Standard BAL-003-0 is to ensure that a balancing 

authority’s frequency bias setting is accurately calculated to match its actual frequency 

response. Frequency bias may be calculated in a number of ways provided that the 

frequency bias is as close as practical to the frequency response. Requirement R3 of 

BAL-003-0 requires each balancing authority to operate its automatic generation control 

on “tie line frequency bias,” unless such operation is adverse to system interconnection 

reliability.18

 17 Frequency bias is an approximation, expressed in megawatts per 0.1 Hertz, of 

the frequency response of a balancing authority area which estimates the net change in 

power from the generators that is expected to occur with a change in interconnection 

frequency from the scheduled frequency (which is normally 60 Hertz). 

18 Automatic generation control refers to an automatic process whereby a 

balancing authority’s mix and output of its generation and demand-side management is 

varied to offset the extent of supply and demand imbalances reflected in its ACE. North 

American Electric Reliability Corporation, 121 FERC ¶ 61,179, at P 19 n.14 (2007). 

“Tie line frequency bias” is defined in the NERC Glossary of Terms Used in Reliability 

Standards as “[a] mode of Automatic Generation Control that allows the Balancing 

Authority to 1.) maintain its Interchange Schedule and 2.) respond to Interconnection 

frequency error.” 
Docket No. RM08-7-000 - 9 - 

a. Proposed Interpretation

16. In its December 19, 2007 filing, NERC explained that WECC requested the ERO 

to provide a formal interpretation whether the use of WECC’s existing automatic time 

error correction factor that is applied to the net interchange portion of the ACE equation 

violates Requirement R1 of BAL-001-0 or Requirement R3 of BAL-003-0. 

17. In response, the ERO interpreted of BAL-001-0 Requirement R1 as follows: 

 The [WECC automatic time error correction or WATEC] procedural 

documents ask Balancing Authorities to maintain raw ACE for 

[control performance standard or CPS] reporting and to control via 

WATEC-adjusted ACE. 

 As long as Balancing Authorities use raw (unadjusted for WATEC) 

ACE for CPS reporting purposes, the use of WATEC for control is 

not in violation of BAL-001 Requirement 1. 

The ERO interpreted BAL-003-0 Requirement R3 as follows: 

 Tie-Line Frequency Bias is one of the three foundational control 

modes available in a Balancing Authority’s energy management 

system. (The other two are flat-tie and flat-frequency.) Many 

Balancing Authorities layer other control objectives on top of their 

basic control mode, such as automatic inadvertent payback, [control 

performance standard] optimization, [and] time control (in single 

[balancing authority] interconnections).[19] 

 As long as Tie-Line Frequency Bias is the underlying control mode 

and CPS1 is measured and reported on the associated ACE 

 19 The “flat frequency” control mode would increase or decrease generation solely 

based on the interconnection frequency. The “flat tie” mode would increase or decrease 

generation within a balancing authority area depending solely on that balancing 

authority’s total interchange. The “tie-line frequency bias” mode combines the flat 

frequency and flat tie modes and adjusts generation based on the balancing authority’s 

net interchange and the interconnection frequency. 
Docket No. RM08-7-000 - 10 - 

equation,[20] there is no violation of BAL-003-0 Requirement 3: 

ACE = (NIA− NIS) – 10B (FA − FS) − IME 

(NERC December 19, 2007 Filing, Ex. A-3.) 

18. In the NOPR, the Commission proposed to approve the ERO’s formal 

interpretations of Requirement R1 of BAL-001-0 and Requirement R3 of BAL-003-0. 

b. Comments

19. NERC and IESO support the Commission’s proposal to approve these 

interpretations. 

c. Commission Determination

20. The Commission approves the ERO’s formal interpretations of Requirement 

R1 of BAL-001-0 and Requirement R3 of BAL-003-0. The ERO’s interpretation of 

BAL-001-0, Requirement R1, is reasonable in that it requires all balancing authorities in 

WECC to calculate CPS1 and CPS2 as defined in the Requirements. Thus, the 

interpretation upholds the reliability goal to minimize the frequency deviation of the 

interconnection by constantly balancing supply and demand. 

21. The ERO’s interpretation of BAL-003-0, Requirement R3 is appropriate because it 

maintains the goal of Requirement R3 by obligating a balancing authority to operate 

automatic generation control on tie-line frequency bias as its underlying control mode, 

unless to do so is adverse to system or interconnection reliability. Further, the 

 20 “CPS1” refers to Requirement R1 of BAL-001-0. 
Docket No. RM08-7-000 - 11 - 

interpretation fosters the purpose of Requirement R3 as it allows that a balancing 

authority may go beyond Requirement R3 and “layer other control objectives on top of 

their basic control modes, such as automatic inadvertent payback, [control performance 

standard] optimization, [and] time control (in single [balancing authority] 

interconnections),”21 although such layering is not required by the Reliability Standard. 

22. For the reasons stated above, the Commission finds that the ERO’s interpretations 

of Requirement R1 of BAL-001-0 and Requirement R3 of BAL-003-0 are just, 

reasonable, not unduly discriminatory or preferential, and in the public interest. 

Accordingly, the Commission approves the ERO’s interpretations. 

2. Requirement R17 of BAL-005-0 – Automatic Generation Control

a. Proposed Interpretation

23. Requirement R17 of Reliability Standard BAL-005-0 is intended to annually 

check and calibrate the time error and frequency devices under the control of the 

balancing authority that feed data into automatic generation control necessary to calculate 

ACE. Requirement R17 mandates that the balancing authority must adhere to an annual 

calibration program for time error and frequency devices. The requirement states that a 

balancing authority must adhere to minimum accuracies in terms of ranges specified in 

Hertz, volts, amps, etc., for various listed devices, such as digital frequency transducers, 

 21 NERC interpretation of BAL-003-0, Requirement R3. 
Docket No. RM08-7-000 - 12 - 

voltage transducers, remote terminal unit, potential transformers, and current 

transformers. 

24. On April 15, 2008, NERC submitted an interpretation of Requirement R17 

regarding the type and location of the equipment to which Requirement R17 applies.22 

The interpretation provides that BAL-005-0, Requirement R17 

applies only to the time error and frequency devices that provide, or in the 

case of back-up equipment may provide, input into the reporting or 

compliance ACE equation or provide real-time time error or frequency 

information to the system operator. Frequency inputs from other sources 

that are for reference only are excluded. The time error and frequency 

measurement devices may not necessarily be located in the system 

operations control room or owned by the Balancing Authority; however the 

Balancing Authority has the responsibility for the accuracy of the frequency 

and time error devices.... 

New or replacement equipment that provides the same functions noted 

above requires the same calibrations. Some devices used for time error and 

frequency measurement cannot be calibrated as such. In this case, these 

devices should be cross-checked against other properly calibrated 

equipment and replaced if the devices do not meet the required level of 

accuracy. 

25. In a supplemental NOPR issued May 16, 2008, the Commission proposed to 

approve NERC’s interpretation of BAL-005-0, Requirement R17. In addition, the 

Commission noted that tie-line megawatt metering data is an important aspect of ensuring 

the accurate calculation of ACE, and the interpretation limits the specific accuracy 

requirements of Requirement R17 to frequency and time error measurement devices. The 

 22 As mentioned earlier, in April 2008, NERC submitted a petition seeking to 

withdraw an earlier interpretation of Requirement R17 and substituting a new 

interpretation for Commission approval. 
Docket No. RM08-7-000 - 13 - 

Commission asked for comment on (1) whether the interpretation could decrease the 

accuracy of frequency and time error measurements by not requiring calibration of tieline megawatt metering devices; (2) what conditions would preclude the requirement to 

calibrate these devices; and (3) whether the accuracy of these devices is assured by other 

requirements within BAL-005-0 in the absence of calibration. 

b. Comments

i. Whether interpretation could decrease accuracy of frequency 

and time error measurements

26. Southern, ITC, ISO/RTO Council, and NERC claim that the interpretation could 

not decrease the accuracy of frequency and time error measurements by not requiring 

calibration of tie-line megawatt metering devices because tie-line metering data is not an 

input to either time error or frequency measurements and has no impact on the accuracy 

of these devices. NERC further suggests that the Commission may have intended to ask 

whether the interpretation adversely affects the accuracy of the balancing authority ACE 

calculation. NERC provides that it does not, because calibration of tie-line metering 

historically was included in the guide section of NERC Operating Policy 1 and was not 

intended to be translated into a requirement. NERC asserts that calibration of tie-line 

metering remains a sound practice and there are safeguards, checks, and balances to 

ensure inadvertent flows in the interconnection equal zero, thus ensuring that errors in 

ACE are bounded to protect the interconnections. 

27. As a general comment on the proposed interpretation of Requirement R17, 

Southern suggests that the metering specifications table in Requirement R17 may be 
Docket No. RM08-7-000 - 14 - 

creating some confusion because the NERC committee that developed this Reliability 

Standard intended to include the frequency metering specifications from this table but 

inadvertently included other metering specifications that are not required to fulfill 

Requirement R17. Southern claims that Requirement R17 is intended to only address 

time error and frequency devices, and this table was added in error and should have been 

limited to specifications for those devices. 

ii. What conditions would preclude requirement to calibrate 

devices

28. NERC, ISO/RTO Council, and Southern claim that there are no conditions which 

would preclude the requirement to calibrate tie-line megawatt metering devices. NERC 

suggests that, if the question relates to a possible new requirement to calibrate all tie-line 

metering equipment on a given schedule, a new standards authorization request should be 

submitted through the Reliability Standards Development Process. NERC believes that 

the industry may not want to divert resources away from other important tasks unless a 

case can be made that calibration of these devices presents a risk to reliability. Similarly, 

ITC comments that, if the Commission believes it is necessary to annually calibrate the 

tie-line megawatt metering devices, such a requirement belongs in BAL-005-0 and not in 

Requirement R17. ISO/RTO Council claims such a requirement is unnecessary because 

it is redundant, not needed for reliability, and poses the possibility of financial sanctions 

for no good reason. 

29. ITC states that tie-line meters would be precluded from calibration requirements if 

they are digital devices that the equipment vendor has indicated do not require 
Docket No. RM08-7-000 - 15 - 

calibration. They claim that there are no field calibration procedures which can be 

performed by end-users for such devices. According to ITC, Requirement R17 of 

BAL-005-0 should recognize that there are modern digital devices that do not require 

calibration as analog devices do. 

iii. Whether accuracy of devices is assured by other requirements

30. NERC, ITC, ISO/RTO Council, and Southern state that tie-line metering accuracy 

is addressed by Requirement R13 of BAL-005-0, which requires each balancing authority 

to perform hourly error checks using tie-line megawatt-hour meters with common time 

synchronization to determine the accuracy of its control equipment and make adjustments 

accordingly. ITC claims that Requirement R13 of BAL-005-0 provides a more timely 

identification of errors than a requirement for annual calibration. 

31. NERC comments that tie-line metering accuracy is not assured by any other 

requirement. According to NERC, requirements relating to Reliability Standards BAL005-0 and BAL-006-1, along with the associated NERC processes, provide several layers 

of overlapping protection to address tie-line accuracy. NERC further claims that BAL005-0 requires balancing authorities to operate in conformance with common metering 

equipment in comparison to that of their neighbors, so there is no net balancing authority 

error in the interconnection as a whole. In addition, NERC claims that many balancing 

authorities have secondary or backup metering on critical tie lines and have access to the 

NERC Resource Adequacy application, which can provide alerts to the balancing 

authority of tie-line metering errors. 
Docket No. RM08-7-000 - 16 - 

c. Commission Determination

32. The Commission approves the ERO’s formal interpretation of Requirement R17 of 

BAL-005-0 as set forth in the ERO’s April 2008 filing. Based on the comments, we find 

that this interpretation will not decrease the accuracy of frequency and time error 

measurements by not requiring calibration of tie-line megawatt metering devices. In 

addition, we are persuaded by the commenters that the need to calibrate tie-line megawatt 

metering devices is addressed by other requirements such as Requirement R13 that 

require hourly checks to ensure continuous accuracy. The Commission notes that the 

applicable requirement for the accuracy of calibration of tie-line megawatt metering 

devices is identified in Requirement R17. While Southern has stated that the metering 

specifications table in Requirement R17 was added in error, an interpretation cannot 

change the substance of a Reliability Standard. Notwithstanding the question of 

relevancy of particular components of the metering specifications table, the accuracy 

requirements of this table remain part of Reliability Standard BAL-005-0 as reference for 

mandatory reliability practices. The Commission encourages further clarification of tieline metering device calibration requirements through the ERO standards development 

process. 

33. ITC comments that digital devices are precluded from the calibration requirement. 

We note that the interpretation provides that “[s]ome devices used for time error and 

frequency measurement cannot be calibrated as such. In this case, these devices should 

be cross-checked against other properly calibrated equipment and replaced if the devices 
Docket No. RM08-7-000 - 17 - 

do not meet the required level of accuracy.” Thus, while ITC’s comment is accurate, the 

ERO’s interpretation acknowledges the concern and provides a response, i.e., modern 

digital devices that cannot be calibrated must be cross-checked against other equipment 

and replaced if they do not meet the required level of accuracy. 

34. The ERO’s interpretation of BAL-005-0, Requirement R17 provides that 

“frequency inputs from other sources that are for reference only are excluded.” The 

Commission notes that this Reliability Standard establishes requirements concerning the 

inputs to the ACE equation to correctly operate automatic generation control. Frequency 

inputs used for other purposes are not covered by this Reliability Standard. Therefore, 

we understand the ERO’s interpretation to exclude frequency devices that do not provide 

input into the reporting or compliance with the ACE equation or provide real-time time 

error or frequency information to the system operator. Any devices that provide 

reference input from which a balancing authority calibrates other time error and 

frequency devices, however, do provide real-time time error and frequency information 

to the system operator and therefore must be calibrated under this requirement. 

3. Requirements R1 and R2 of VAR-002-1 Generator Operation for 

Maintaining Network Voltage Schedules

a. Proposed Interpretations

35. The stated purpose of Reliability Standard VAR-002-1 is to ensure that generators 

provide reactive and voltage control necessary to ensure that voltage levels, reactive 

flows, and reactive resources are maintained within applicable facility ratings to protect 
Docket No. RM08-7-000 - 18 - 

equipment and the reliable operation of the interconnection. Requirement R1 ofVAR002-1 provides: 

The Generator Operator shall operate each generator connected to 

the interconnected transmission system in the automatic voltage 

control mode (automatic voltage regulator in service and controlling 

voltage) unless the Generator Operator has notified the Transmission 

Operator. 

Requirement R2 provides: 

 

Unless exempted by the Transmission Operator, each Generator 

Operator shall maintain the generator voltage or Reactive Power 

output (within applicable Facility Ratings) as directed by the 

Transmission Operator. 

36. The ERO received a request to provide a formal interpretation of Requirements 

R1 and R2. The request first asked whether automatic voltage regulator operation in the 

constant power factor or constant Mvar modes complies with Requirement R1. Second, 

the request asked the ERO whether Requirement R2 gives the transmission operator the 

option of directing the generation owner to operate the automatic voltage regulator in the 

constant power factor or constant Mvar modes rather than the constant voltage mode. 

37. NERC’s formal interpretation provides that a generator operator that is operating 

its automatic voltage regulator in the constant power factor or constant Mvar modes does 

not comply with Requirement R1.23 The interpretation rests on the assumptions that the 

generator has the physical equipment that will allow such operation and that the 

 23 NERC’s interpretation of VAR-002-1, Requirement R1 is quoted in full in the 

NOPR, FERC Stats. & Regs. ¶ 32,632 at P 32, n.27. 
Docket No. RM08-7-000 - 19 - 

transmission operator has not directed the generator to run in a mode other than constant 

voltage. The interpretation also provides that Requirement R2 gives the transmission 

operator the option of directing the generation operator to operate the automatic voltage 

regulator in the constant power factor or constant Mvar modes rather than the constant 

voltage mode. 

38. In the NOPR, the Commission proposed to approve the ERO’s interpretation of 

Requirement R1 and Requirement R2 of VAR-002-1. 

b. Comments

39. NERC and IESO support the Commission’s proposal to approve the interpretation. 

c. Commission Determination

40. The Commission concludes that the interpretation is just, reasonable, not unduly 

discriminatory or preferential, and in the public interest. Therefore, the Commission 

approves the ERO’s interpretation of Requirements R1 and R2 of VAR-002-1.

B. NERC’s December 21, 2007 Filing: Modification of TLR Procedure

41. NERC submitted for Commission approval proposed Reliability Standard 

IRO-006-4, which modifies the Commission-approved Reliability Standard, IRO-006-3. 

1. Background

42. In Order No. 693, the Commission approved an earlier version of this Reliability 

Standard, IRO-006-3. This Reliability Standard ensures that a reliability coordinator has 

a coordinated transmission service curtailment and reconfiguration method that can be 

used along with other alternatives, such as redispatch or demand-side management, to 
Docket No. RM08-7-000 - 20 - 

avoid transmission limit violations when the transmission system is congested. 

Reliability Standard IRO-006-3 established a detailed TLR procedure for use in the 

Eastern Interconnection to alleviate loadings on the system by curtailing or changing 

transactions based on their priorities and the severity of the transmission congestion. The 

Reliability Standard referenced other procedures for WECC and Electric Reliability 

Council of Texas (ERCOT).24

2. ERO TLR Filing, Reliability Standard IRO-006-4 

43. In its December 2007 filing, NERC submitted for Commission approval a 

modified TLR procedure, Reliability Standard IRO-006-4, which contains five 

requirements. Requirement R1 obligates a reliability coordinator experiencing a potential 

or actual system operating limit (SOL) or IROL violation within its reliability coordinator 

area to select one or more procedures to provide transmission loading relief. The 

requirement also identifies the regional TLR procedures in WECC and ERCOT. 

3. NOPR

44. In the NOPR, the Commission proposed to approve IRO-006-4 as just, reasonable, 

not unduly discriminatory or preferential, and in the public interest.25 The Commission 

also proposed to approve the Reliability Standard based on the interpretation that using a 

 24 The equivalent interconnection-wide TLR procedures for use in WECC and 

ERCOT are known as “WSCC Unscheduled Flow Mitigation Plan” and section 7 of the 

“ERCOT Protocols,” respectively. 

25 NOPR, FERC Stats. & Regs. ¶ 32,632 at P 48. 
Docket No. RM08-7-000 - 21 - 

TLR procedure to mitigate an IROL violation is a violation of the Reliability Standard. 

The Commission asked for comments on whether any compromise in the reliability of the 

Bulk-Power System may result from the removal and transfer to NAESB of the businessrelated issues formerly contained in Reliability Standard IRO-006-3. In addition, the 

Commission proposed to direct the ERO to modify the violation risk factors assigned to 

Requirements R1 through R4 by raising them to “high.” 

4. Comments

45. The Commission received comments on the NOPR proposal. Because the Final 

Rule does not approve or remand the proposed Reliability Standard and, rather, directs 

the ERO to submit a filing that provides an explanation regarding specific language of 

one requirement of IRO-006-4, the Commission will address the comments in a future 

issuance in this proceeding. 

5. Commission Determination

46. Because the Commission has concern regarding the understanding of certain 

language of Requirements R1 and R1.1 of IRO-006-4, the Commission is not approving 

or remanding the proposed Reliability Standard at this time. Rather, the Commission 

directs that the ERO, within 15 days of the effective date of this Final Rule, submit a 

filing that provides an explanation regarding specific language of Requirements R1 and 

R1.1 of IRO-006-4. The Commission will then issue a notice allowing public comment 

on the ERO’s filing, and will act on the proposed Reliability Standard in a future issuance 

in this proceeding. 
Docket No. RM08-7-000 - 22 - 

47. In the Final Blackout Report, an international team of experts studying the causes 

of the August 2003 blackout in North America recommended that NERC “[c]larify that 

the transmission loading relief (TLR) process should not be used in situations involving 

an actual violation of an Operation Security Limit.”26 Based on the Final Blackout 

Report recommendation, the Commission, in Order No. 693, directed NERC to develop a 

modification to the TLR procedure (IRO-006-3) that “(1) includes a clear warning that 

the TLR procedure is an inappropriate and ineffective tool to mitigate actual IROL 

violations and (2) identifies in a Requirement the available alternatives to mitigate an 

IROL violation other than use of the TLR procedure.”27

48. In response to this directive, NERC proposed in Requirement R1.1 of IRO-006-4 

that “[t]he TLR procedure [for the Eastern Interconnection] alone is an inappropriate and 

ineffective tool to mitigate an IROL violation due to the time required to implement the 

procedure.” (Emphasis added.) The Commission is concerned whether this language is 

adequate to satisfy the concern of the Final Blackout Report and Order No. 693. 

Specifically, we note that the use of the term “alone” seems to imply that a TLR 

procedure could be used in response to an actual violation of an IROL whereas the Final 

Blackout Report recommendation would prevent the use of the TLR procedure in such 

 26 See U.S.-Canada Power System Outage Task Force, Final Report on the August 

14, 2003 Blackout in the United States and Canada: Causes and Recommendations, at 

163 (April 2004) (Final Blackout Report) (Recommendation 31). 

27 See Order No. 693, FERC Stats. & Regs. ¶ 31,242 at P 577, 964. 
Docket No. RM08-7-000 - 23 - 

situations. Moreover, Requirement R1 of IRO-006-4 further appears to contradict the 

Final Blackout Report recommendation by allowing a reliability coordinator to 

implement transmission loading relief procedures to mitigate not only potential SOL or 

IROL violations but also actual SOL or IROL violations.28 The Commission is 

concerned that Recommendation 31 of the Final Blackout Report and the directive in 

Order No. 693, both of which state the TLR procedures should not be used in situations 

involving an actual violation of an IROL, may not be clearly addressed in the proposed 

Reliability Standard. 

49. The Commission notes that an entity is not prevented from using the TLR 

procedure to avoid a potential IROL violation before a violation occurs. If, while a TLR 

procedure is in progress, an IROL violation occurs, it is not necessary for the entity to 

terminate the TLR procedure. However, the Commission believes that it is inappropriate 

and ineffective to rely on the TLR procedure, even in conjunction with another tool, to 

address an actual IROL violation. 

 28 Requirement R1 provides that “[a] reliability Coordinator experiencing a 

potential or actual SOL or IROL violation within its Reliability Coordinator Area shall, 

with its authority and at its discretion, select one or more procedures to provide 

transmission loading relief. This procedure can be a “local” . . . transmission loading 

relief procedure or one of the following Interconnection-wide procedures....” Subrequirement R1.1 provides that “[t]he TLR procedure alone is an inappropriate and 

ineffective tool to mitigate an IROL violation due to the time required to implement the 

procedure. Other acceptable and more effective procedures to mitigate actual IROL 

violations include: reconfiguration, redispatch, or load shedding.” 
Docket No. RM08-7-000 - 24 - 

50. Therefore, the Commission does not approve or remand IRO-006-4. Rather, the 

Commission directs the ERO to submit a filing, within 15 days of the effective date of 

this Final Rule, that provides an explanation regarding Requirements R1 and R1.1 of 

IRO-006-4. Specifically, in light of the above discussion, the Commission directs the 

ERO to provide an explanation regarding the phrase “[t]he TLR procedure alone is an 

inappropriate and ineffective tool to mitigate an IROL violation . . .” Further, the ERO 

should explain whether Requirements R1 and R1.1 only allow the TLR procedure to 

be continued when already deployed prior to an actual IROL violation or, alternatively, 

whether Requirements R1 and R1.1 allow use of the TLR procedure as a tool to address 

actual violations after they occur. If the latter, the ERO is directed to explain why this 

application is not contrary to both Blackout Report Recommendation 31 and the 

Commission’s determination in Order No. 693. The ERO’s filing should include an 

explanation of those actions that are acceptable, and those that are unacceptable, pursuant 

to Requirement R1 and R1.1. 

C. NERC’s December 26, 2007 Filing: Modification to Five “Interchange 

and Scheduling” Reliability Standards

51. NERC submitted for Commission approval proposed modifications to five 

Reliability Standards from the INT group of Reliability Standards. 

1. INT-001-3 – Interchange Information and INT-004-2 – Dynamic 

Interchange Transaction Modifications

52. The Interchange Scheduling and Coordination or “INT” group of Reliability 

Standards address interchange transactions, which occur when electricity is transmitted 
Docket No. RM08-7-000 - 25 - 

from a seller to a buyer across the Bulk-Power System. Reliability Standard INT-001 

applies to purchasing-selling entities and balancing authorities. The stated purpose of the 

Reliability Standard is to “ensure that Interchange Information is submitted to the NERCidentified reliability analysis service.” Reliability Standard INT-004 is intended to 

“ensure Dynamic Transfers are adequately tagged to be able to determine their reliability 

impacts.” 

53. In Order No. 693, the Commission approved earlier versions of these Reliability 

Standards, INT-001-2 and INT-004-1.29 Further, when NERC initially (in April 2006) 

submitted these two Reliability Standards for Commission approval, NERC also asked 

the Commission to approve a “regional difference” that would exempt WECC from 

requirements related to tagging dynamic schedules and inadvertent payback provisions of 

INT-001-2 and INT-004-1. The Commission, in Order No. 693, stated that it did not 

have sufficient information to address the ERO’s proposed regional difference and 

directed the ERO to submit a filing either withdrawing the regional difference or 

providing additional information needed for the Commission to make a determination on 

the matter.30 The effect of NERC’s December 26, 2007 filing is to withdraw the regional 

difference with respect to WECC. 

 29 Order No. 693, FERC Stats. & Regs. ¶ 31,242 at P 821, 843. In addition, the 

Commission directed that the ERO develop modifications to INT-001-2 and INT-004-1 

that address the Commission’s concerns. 

30 Id. P 825. 
Docket No. RM08-7-000 - 26 - 

54. In its December 26, 2007 filing, NERC stated that, by rescinding the e-tagging 

waivers, NERC maintains uniformity and makes no structural changes to the 

requirements in the current Commission-approved version of the Reliability Standards. 

55. In the NOPR, the Commission proposed to approve INT-001-3 and INT-004-2. 

a. Comments

56. NERC and the IESO support the Commissions proposal to approve these 

Reliability Standards. 

b. Commission Determination

57. Pursuant to section 215(d) of the FPA, the Commission approves Reliability 

Standards INT-001-3 and INT-004-2 as mandatory and enforceable. 

2. INT-005-2 – Interchange Authority Distributes Arranged Interchange,

INT-006-2 – Response to Interchange Authority, and INT-008-2 –

Interchange Authority Distributes Status

58. Reliability Standard INT-005-1 applies to the interchange authority. The stated 

purpose of proposed Reliability Standard INT-005-1 is to “ensure that the 

implementation of Interchange between Source and Sink Balancing Authorities is 

distributed by an Interchange Authority such that Interchange information is available for 

reliability assessments.” 

59. Reliability Standard INT-006-1 applies to balancing authorities and transmission 

service providers. The stated purpose of the Reliability Standard is to “ensure that each 

Arranged Interchange is checked for reliability before it is implemented.” 
Docket No. RM08-7-000 - 27 - 

60. Reliability Standard INT-008-1 applies to the interchange authority. The stated 

purpose of the Reliability Standard is to “ensure that the implementation of Interchange 

between Source and Sink Balancing Authorities is coordinated by an Interchange 

Authority.” This means that it is an interchange authorities’ responsibility to oversee and 

coordinate the interchange from one balancing authority to another. 

61. In its December 26, 2007 filing, NERC addressed a reliability need identified by 

WECC in its urgent action request. Specifically, Requirement R1.4 of INT-007-1 

requires that each balancing authority and transmission service provider provide 

confirmation to the interchange authority that it has approved the transactions for 

implementation. NERC stated that for WECC the timeframe allotted for this assessment 

is five minutes in the original version of the Commission-approved Reliability Standards. 

62. Reliability Standards for INT-005-2, INT-006-2, and INT-008-2 increase the 

timeframe for applicable WECC entities to perform the reliability assessment from five to 

ten minutes for next hour interchange tags submitted in the first thirty minutes of the hour 

before. According to NERC, this modification is needed because the majority of nexthour tags in WECC are submitted between xx:00 and xx:30. The existing five minute 

assessment window makes it nearly impossible for balancing authorities and transmission 

service providers to review each tag before the five minute assessment time expires. 

According to NERC, when the time expires, the tags are denied and must be resubmitted. 

63. In its December 26, 2007 filing, NERC stated that WECC has experienced 

numerous instances of transactions being denied because one or more applicable 
Docket No. RM08-7-000 - 28 - 

reliability entities did not actively approve the tag. In NERC’s view, the current structure 

causes frustration and inefficiencies for entities involved in this process, as requestors are 

required to re-create tags that are denied. Further, NERC stated that there is no reliability 

basis for a five minute assessment period for tags submitted at least thirty minutes ahead 

of the ramp-in period. 

64. NERC noted that, prior to January 1, 2007, when the new INT group of Reliability 

Standards was implemented WECC had a ten-minute reliability assessment period for 

next-hour tags. NERC states that the urgent action request restores assessment times 

back to ten minutes. 

65. In the NOPR, the Commission proposed to approve INT-005-2, INT-006-2, and 

INT-008-2. 

a. Comments

66. NERC and IESO support the Commissions proposal to approve these Reliability 

Standards. 

b. Commission Determination

67. Pursuant to section 215(d) of the FPA, the Commission approves Reliability 

Standards INT-005-2, INT-006-2, and INT-008-2 as mandatory and enforceable.31

 31 The Commission notes that NERC’s compliance with Order No. 693, with 

respect to Reliability Standard INT-006-1, is ongoing. See Order No. 693, FERC Stats. 

& Regs. ¶ 31,242 at P 866. 
Docket No. RM08-7-000 - 29 - 

III. Information Collection Statement

68. The Office of Management and Budget (OMB) regulations require that OMB 

approve certain reporting and recordkeeping (collections of information) imposed by an 

agency.32 The information contained here is also subject to review under section 3507(d) 

of the Paperwork Reduction Act of 1995.33 As stated above, the Commission previously 

approved, in Order No. 693, each of the Reliability Standards that are the subject of the 

current rulemaking. In the NOPR, the Commission explained that the modifications to 

the Reliability Standards are minor and the interpretations relate to existing Reliability 

Standards; therefore, they do not add to or increase entities’ reporting burden. Thus, in 

the NOPR, the Commission stated that the modified Reliability Standards and 

interpretations of Reliability Standards do not materially affect the burden estimates 

relating to the earlier version of the Reliability Standards presented in Order No. 693.34

69. In response to the NOPR, the Commission received no comments concerning its 

estimate for the burden and costs and therefore uses the same estimate here. 

 32 5 CFR 1320.11. 

33 44 U.S.C. 3507(d). 

34 See Order No. 693, FERC Stats. & Regs. ¶ 31,242 at P 1905-07. The NOPR, 

FERC Stats. & Regs. ¶ 32,632 at P 76-78, provided a detailed explanation why each 

modification and interpretation has a negligible, if any, affect on the reporting burden. 
Docket No. RM08-7-000 - 30 - 

Title: Modification of Interchange and Transmission Loading Relief Reliability 

Standards; and Electric Reliability Organization Interpretation of Specific Requirements 

of Four Reliability Standards. 

Action: Proposed Collection. 

OMB Control No.: 1902-0244. 

Respondents: Businesses or other for-profit institutions; not-for-profit institutions. 

Frequency of Responses: On Occasion. 

Necessity of the Information: This Final Rule approves five modified Reliability 

Standards that pertain to interchange scheduling and coordination. It directs NERC to 

make a filing with the Commission regarding one modified Reliability Standard that 

pertains to transmission loading relief procedures. In addition, the Final Rule approves 

interpretations of five specific requirements of Commission-approved Reliability 

Standards. The Final Rule finds the Reliability Standards and interpretations just, 

reasonable, not unduly discriminatory or preferential, and in the public interest. 

70. Interested persons may obtain information on the reporting requirements by 

contacting: Federal Energy Regulatory Commission, Attn: Michael Miller, Office of the 

Executive Director, 888 First Street, N.E. Washington, D.C. 20426, Tel: (202) 502-8415, 

Fax: (202) 273-0873, E-mail: michael.miller@ferc.gov, or by contacting: 

Office of Information and Regulatory Affairs, Attn: Desk Officer for the Federal Energy 

Regulatory Commission (Re: OMB Control No. 1902-0244), Washington, D.C. 20503, 

Tel: (202) 395-4650, Fax: (202) 395-7285, E-mail: <oira_submission@omb.eop.gov>. 
Docket No. RM08-7-000 - 31 - 

IV. Environmental Analysis

71. The Commission is required to prepare an Environmental Assessment or an 

Environmental Impact Statement for any action that may have a significant adverse effect 

on the human environment.35 The Commission has categorically excluded certain actions 

from this requirement as not having a significant effect on the human environment. 

Included in the exclusion are rules that are clarifying, corrective, or procedural or that do 

not substantially change the effect of the regulations being amended.36 The actions 

proposed herein fall within this categorical exclusion in the Commission’s regulations. 

V. Regulatory Flexibility Act

72. The Regulatory Flexibility Act of 1980 (RFA)37 generally requires a description 

and analysis of final rules that will have significant economic impact on a substantial 

number of small entities. The RFA mandates consideration of regulatory alternatives that 

accomplish the stated objectives of a proposed rule and that minimize any significant 

economic impact on a substantial number of small entities. The Small Business 

Administration’s Office of Size Standards develops the numerical definition of a small 

business. (See 13 CFR 121.201.) For electric utilities, a firm is small if, including its 

affiliates, it is primarily engaged in the transmission, generation and/or distribution of 

 35 Regulations Implementing the National Environmental Policy Act of 1969, 

Order No. 486, FERC Stats. & Regs. ¶ 30,783 (1987). 

36 18 CFR 380.4(a)(2)(ii). 

37 5 U.S.C. 601-12. 
Docket No. RM08-7-000 - 32 - 

electric energy for sale and its total electric output for the preceding twelve months did 

not exceed four million megawatt hours. The RFA is not implicated by this Final Rule 

because the minor modifications and interpretations discussed herein will not have a 

significant economic impact on a substantial number of small entities. 

VI. Document Availability

73. In addition to publishing the full text of this document in the Federal Register, the 

Commission provides all interested persons an opportunity to view and/or print the 

contents of this document via the Internet through FERC’s Home Page 

(http://www.ferc.gov) and in FERC’s Public Reference Room during normal business 

hours (8:30 a.m. to 5:00 p.m. Eastern time) at 888 First Street, N.E., Room 2A, 

Washington D.C. 20426. 

74. From FERC’s Home Page on the Internet, this information is available on 

eLibrary. The full text of this document is available on eLibrary in PDF and Microsoft 

Word format for viewing, printing, and/or downloading. To access this document in 

eLibrary, type the docket number excluding the last three digits of this document in the 

docket number field. 

75. User assistance is available for eLibrary and the FERC’s website during normal 

business hours from FERC Online Support at (202) 502-6652 (toll free at 1-866-208-

3676) or e-mail at ferconlinesupport@ferc.gov, or the Public Reference Room at (202) 

502-8371, TTY (202) 502-8659. E-mail the Public Reference Room at 

public.referenceroom@ferc.gov. 
Docket No. RM08-7-000 - 33 - 

VII. Effective Date and Congressional Notification

76. These regulations are effective [insert date 30 days from publication in 

FEDERAL REGISTER]. The Commission has determined, with the concurrence of the 

Administrator of the Office of Information and Regulatory Affairs of OMB, that this rule 

is not a “major rule” as defined in section 351 of the Small Business Regulatory 

Enforcement Fairness Act of 1996. 

List of subjects in 18 CFR Part 40 

Electric power, Electric utilities, Reporting and recordkeeping requirements. 

By the Commission. 

( S E A L ) 

 Nathaniel J. Davis, Sr., 

 Deputy Secretary.