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pdfUNITED STATES OF AMERICA
BEFORE THE
FEDERAL ENERGY REGULATORY COMMISSION
North American Electric Reliability Corporation
)
)
Docket No. _______
JOINT PETITION OF THE
NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION AND
WESTERN ELECTRICITY COORDINATING COUNCIL FOR APPROVAL OF
PROPOSED REGIONAL RELIABILITY STANDARD BAL-004-WECC-4
Chris Albrecht
Assistant General Counsel
Western Electricity Coordinating Council
155 North 400 West, Suite 200
Salt Lake City, UT 84103
(801) 582-0353
[email protected]
Counsel for the Western Electricity
Coordinating Council
Lauren Perotti
Assistant General Counsel
Alain Rigaud
Associate Counsel
North American Electric Reliability
Corporation
1401 H Street NW, Suite 410
Washington, D.C. 20005
202-400-3000
[email protected]
[email protected]
Counsel for the North American Electric
Reliability Corporation
March 12, 2025
TABLE OF CONTENTS
I.
SUMMARY ............................................................................................................................ 2
II. NOTICES AND COMMUNICATIONS ................................................................................ 4
III. BACKGROUND .................................................................................................................... 4
a.
Regulatory Framework ....................................................................................................... 4
b.
WECC Reliability Standards Development Procedure....................................................... 6
c.
Development of the Proposed Reliability Standard ............................................................ 6
IV. JUSTIFICATION FOR APPROVAL .................................................................................... 7
a.
Proposed Substantive Revisions to Standard and Requirements ........................................ 9
b.
Proposed Clarifying Revisions to Standard and Requirements ........................................ 11
c.
Enforceability of Proposed Reliability Standard .............................................................. 14
V. EFFECTIVE DATE .............................................................................................................. 14
VI. CONCLUSION ..................................................................................................................... 15
Exhibit A
Exhibit B
Exhibit C
Exhibit D
Exhibit E
Exhibit F
Proposed Regional Reliability Standard BAL-004-WECC-4 – Automatic
Time Error Correction
Exhibit A-1 BAL-004-WECC-4 – (Redline)
Exhibit A-2 BAL-004-WECC-4 – (Clean)
Implementation Plan
Order No. 672 Criteria
Analysis of Violation Risk Factors and Violation Severity Levels
Summary of Development History and Complete Record of Development
Standard Drafting Team Roster for Project WECC-0147
i
UNITED STATES OF AMERICA
BEFORE THE
FEDERAL ENERGY REGULATORY COMMISSION
North American Electric Reliability Corporation
)
)
Docket No. _______
JOINT PETITION OF THE
NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION AND
WESTERN ELECTRICITY COORDINATING COUNCIL FOR APPROVAL OF
PROPOSED REGIONAL RELIABILITY STANDARD BAL-004-WECC-4
Pursuant to Section 215(d)(1) of the Federal Power Act (“FPA”)1 and Section 39.5 of the
regulations of the Federal Energy Regulatory Commission (“FERC” or “Commission”),2 the North
American Electric Reliability Corporation (“NERC”)3 and the Western Electricity Coordinating
Council (“WECC”) hereby submit proposed Regional Reliability Standard BAL-004-WECC-4
Automatic Time Error Correction for Commission approval. Regional Reliability Standard BAL004-WECC-4 seeks to improve upon the existing Reliability Standard by addressing an issue
identified in a five-year review of the standard related to the Western Interchange Tool (“WIT”)
and currently effective Requirement R1 which could prevent new Balancing Authorities from
determining values needed for compliance with the standard. Regional Reliability Standard BAL004-WECC-4 addresses this issue by creating a Standard-specific definition “Interchange
Software” to refer to the software used by Balancing Authorities to submit Automatic Time Error
Correction (“ATEC”) data to WECC to review the data, creating a requirement to use the proposed
1
16 U.S.C. § 824o.
18 C.F.R. § 39.5 (2023).
3
The Commission certified NERC as the electric reliability organization (“ERO”) in accordance with
Section 215 of the FPA. N. Am. Elec. Reliability Corp., 116 FERC ¶ 61,062 (2006), order on reh’g
& compliance, 117 FERC ¶ 61,126 (2006), aff’d sub nom. Alcoa, Inc. v. FERC, 564 F.3d 1342 (D.C. Cir. 2009).
[hereinafter ERO Certification Order].
2
1
Interchange Software, and addressing the treatment of Balancing Authorities that do not have a
full year of operating data.
NERC and WECC request that the Commission approve the proposed Regional Reliability
Standard, provided in Exhibit A hereto, as just, reasonable, not unduly discriminatory or
preferential, and in the public interest. NERC and WECC also request approval of: (1) the
associated Implementation Plan (Exhibit B); the associated Violation Risk Factors (“VRFs”) and
Violation Severity Levels (“VSLs”) (Exhibit D); and the retirement of currently effective Regional
Reliability Standard BAL-004-WECC-3.
As required by Section 39.5(a) of the Commission’s regulations,4 this petition presents the
technical basis and purpose of the proposed Reliability Standard, a summary of the development
history (Exhibit E), and a demonstration that the proposed Reliability Standard meets the criteria
identified by the Commission in Order No. 6725 (Exhibit C). The NERC Board of Trustees adopted
the proposed Regional Reliability Standard on February 13, 2025.
I.
SUMMARY
The purpose of proposed Regional Reliability Standard BAL-004-WECC-4 is to maintain
Western Interconnection (“WI”) frequency and ensure that time error accumulation via Primary
Inadvertent Interchange (“PII”) payback is conducted in a manner that does not result in a negative
impact on reliability. The Commission first approved BAL-004-WECC-01 in 2009, 6 finding it
benefits the reliable operation of the Bulk-Power System (“BPS”) by creating an operating
environment that encourages system operators to balance their generation and interchange with
4
18 C.F.R. § 39.5(a).
Rules Concerning Certification of the Electric Reliability Organization; and Procedures for the
Establishment, Approval, and Enforcement of Electric Reliability Standards, Order No. 672, 114 FERC 61,104 at
PP 262, 321-37 (2006) [hereinafter Order No. 672], order on reh’g, Order No. 672-A, 114 FERC 61,328 (2006).
6
Western Electricity Coordinating Council Regional Reliability Standard Regarding Automatic Time Error
Correction, Order No.723, 127 FERC ¶ 61,176 (2009).
5
2
their load and losses to reduce the number of manual time error corrections. The currently effective
version, BAL-004-WECC-3, was approved in 2018.7
Proposed Regional Reliability Standard BAL-004-WECC-4 improves upon the existing
standard by addressing an issue identified with Requirement R1 of the currently effective standard.
Currently, Regional Reliability Standard BAL-004-WECC- 3 Requirement R1 establishes limits
on Accumulated Primary Inadvertent Interchange (“PIIaccum”) based on a value determined from
the “previous calendar year.” In circumstances such as the creation of a new Balancing Authority
or the shutdown of an existing Balancing Authority, these values may not be available. If a
Balancing Authority does not have data from a previous calendar year, then Requirement R1 as
written would establish a compliance limit of zero (0) MWh. Maintaining a monthly PIIaccum
balance of zero as calculated by the WIT is not operationally feasible and could result in noncompliance with the standard which cannot be mitigated until the end of the calendar year.
Proposed Regional Reliability Standard BAL-004-WECC-4 addresses this concern and improves
upon the currently effective standard by: 1) expanding the existing Background section, 2) creating
a Standard-specific definition “Interchange Software” to refer to the software used by Balancing
Authorities to submit ATEC data to WECC, 3) creating a requirement to use the Interchange
Software, 4) addressing treatment of Balancing Authorities that do not have a full year of operating
data, 5) consolidating and clarifying requirements, and 6) updating the document to NERC's
newest templates.
NERC and WECC respectfully request the Commission approve proposed regional
Reliability Standard BAL-004-WECC-4, the associated VRFs and VSLs, the Implementation
7
N. Am. Elec. Reliability Corp., Docket No. RD18-2-000 (2018) (delegated letter order).
3
Plan, and the retirement of the existing regional Reliability Standard BAL-004-WECC-3. The
following petition presents the justification for approval and supporting documentation.
II.
NOTICES AND COMMUNICATIONS
Notices and communications with respect to this filing may be addressed to the following:8
Chris Albrecht*
Assistant General Counsel
Steve Rueckert*
Director of Standards
Western Electricity Coordinating Council
155 North 400 West, Suite 200
Salt Lake City, UT 84103
(801) 582-0353
[email protected]
[email protected]
III.
Lauren Perotti*
Assistant General Counsel
Alain Rigaud*
Associate Counsel
North American Electric Reliability
Corporation
1401 H Street, N.W., Suite 410
Washington, D.C. 20005
(202) 400-3000
[email protected]
[email protected]
BACKGROUND
The following background information is provided below: (1) an explanation of the
regulatory framework; (2) a description of the WECC Reliability Standards Development
Procedure; and (3) the history of Project WECC-0147: BAL-004-WECC-3, ATEC Five-year
Review with Focus on Requirement R1.
a. Regulatory Framework
By enacting the Energy Policy Act of 2005,9 Congress entrusted the Commission with the
duties of approving and enforcing rules to ensure the reliability of the Bulk-Power System, and
with the duty of certifying an ERO that would be charged with developing and enforcing
mandatory Reliability Standards, subject to Commission approval. Section 215(b)(1) of the FPA
states that all users, owners, and operators of the Bulk-Power System in the United States will be
8
Persons to be included on the Commission’s service list are indicated with an asterisk. NERC and WECC
respectfully request a waiver of Rule 203 of the Commission’s regulations, 18 C.F.R. § 385.203, to allow the
inclusion of more than two persons on the service list in this proceeding.
9
16 U.S.C. § 824o.
4
subject to Commission-approved Reliability Standards.10 Section 215(d)(5) of the FPA authorizes
the Commission to order the ERO to submit a new or modified Reliability Standard.11 Section
39.5(a) of the Commission’s regulations requires the ERO to file for Commission approval each
Reliability Standard that the ERO proposes should become mandatory and enforceable in the
United States, and each modification to a Reliability Standard that the ERO proposes to make
effective.12
The Commission has the regulatory responsibility to approve Reliability Standards that
protect the reliability of the Bulk-Power System and to ensure that such Reliability Standards are
just, reasonable, not unduly discriminatory or preferential, and in the public interest. Pursuant to
Section 215(d)(2) of the FPA and Section 39.5(c) of the Commission’s regulations, the
Commission will give due weight to the technical expertise of the ERO with respect to the content
of a Reliability Standard.13
Similarly, the Commission approves regional differences proposed by Regional Entities,
such as Regional Reliability Standards and Variances, if the regional difference is just, reasonable,
not unduly discriminatory or preferential, and in the public interest.14 In addition, Commission
Order No. 672 requires further criteria for regional differences. A regional difference from a
continent-wide Reliability Standard must either be: (1) more stringent than the continent-wide
Reliability Standard, including a regional difference that addresses matters that the continent-wide
Reliability Standard does not; or (2) necessitated by a physical difference in the Bulk-Power
System.15 The Commission must give due weight to the technical expertise of a Regional Entity,
10
11
12
13
14
15
Id. § 824(b)(1).
Id. § 824o(d)(5).
18 C.F.R. § 39.5(a).
16 U.S.C. § 824o(d)(2); 18 C.F.R. § 39.5(c)(1).
16 U.S.C. § 824o(d)(2) and 18 C.F.R. § 39.5(a).
Order No. 672 at P 291.
5
like WECC, that is organized on an Interconnection-wide basis, with respect to a regional
difference to be applicable within that Interconnection.16
b. WECC Reliability Standards Development Procedure
The proposed Regional Reliability Standard was developed in an open and fair manner and
in accordance with the Commission-approved WECC Reliability Standards Development
Procedures (“RSDP”).17 WECC’s RSDP provides for reasonable notice and opportunity for public
comment, due process, openness, and a balance of interests in developing Reliability Standards
and thus addresses several of the Commission’s criteria for approving Reliability Standards. The
development process is open to any person or entity that is an interested stakeholder. WECC
considers the comments of all stakeholders, and a vote of stakeholders and the WECC Board of
Directors is required to approve a WECC regional Reliability Standard. 18 NERC posts each
regional Variance developed by a Regional Entity for an additional comment period. The NERC
Board of Trustees must adopt the regional Variance before it is submitted to the Commission for
approval.
c. Development of the Proposed Reliability Standard
As further described in Exhibit E hereto, proposed regional Reliability Standard BAL-004WECC-4 was developed as part of a five-year review of the currently effective Regional Reliability
Standard in accordance with the WECC RSDP.19 The project was titled, WECC-0147: BAL-004WECC-3, ATEC Five-year Review with Focus on Requirement R1. The WECC Board of
16
Id. at P 344.
The currently effective WECC RSDP was approved by the Commission on September 13, 2021. See N.
Am. Elec. Reliability Corp., Docket No. RR21-4-000 (2021) (approving revised WECC Reliability Standards
Development Procedures). The WECC Reliability Standards Development Procedures are available at:
https://www.wecc.org/sites/default/files/documents/standards/2024/WECC%20Reliability%20Standards%20Develo
pment%20Procedures%20-%20FERC%20Approved%2009-13-2021.pdf.
18
Id. at 12 (Treatment of Non-Substantive Changes. .Approval by the WECC Board of Directors is not
required for Non-Substantive Changes).
19
Id.at 21 (WECC Reliability Standards Development Procedures, Maintenance of RRSs and CRTs).
17
6
Directors approved the standard on March 13, 2024 and submitted the proposed standard to the
NERC Board of Trustees for adoption. NERC posted the proposed standard for a 45-day comment
period from April 10 – May 28, 2024. During the comment period, NERC staff recommended that
a proposed compliance waiver within the standard be removed because it could cause confusion
regarding responsibilities of standard drafting teams to develop standards and the circumstances
under which NERC Compliance Monitoring and Enforcement Staff may grant a compliance
waiver excusing compliance with those standards, and the matter addressed in the proposed
compliance waiver was already addressed in the mandatory and enforceable elements of the
proposed regional Reliability Standard. The WECC Standards Committee (“WSC”) agreed and
approved the removal of the compliance waiver as a non-substantive change on September 6,
2024.20
The NERC Board of Trustees adopted the proposed regional standard on February 13,
2025.
IV.
JUSTIFICATION FOR APPROVAL
As discussed in detail in Exhibit C, proposed Regional Reliability Standard BAL-004-
WECC-4 is just, reasonable, not unduly discriminatory or preferential, and in the public interest.
As described herein and in Exhibit C, the proposed Regional Reliability Standard provides
reliability benefits for the BPS in the WECC region. As NERC and WECC noted in previous
filings, ATEC reduces manual time error corrections, reduces accumulated Inadvertent
Interchange, and better identifies the Balancing Authorities responsible for the Inadvertent
20
Id.at 12. (“If a Non-Substantive Change to an RRS is required at any time after a WECC ballot window
opens, the proposed change shall be presented to the WSC with a request for approval. If the WSC agrees that the
correction of the error does not change the scope or intent of the associated RRS, and agrees that the correction has
no material impact on the applicable entities, then the correction shall be filed for approval with NERC and
applicable governmental authorities as appropriate.”).
7
Interchange.21 The proposed revisions to Regional Reliability Standard BAL-004-WECC-4 are
intended to reflect current operational practice, provide clarity in Requirements, and resolve issues
identified with the standard. Under the proposed Regional Reliability Standard, Balancing
Authorities would continue to perform required tasks in the same or similar manner to the currently
effective version of the standard.
As summarized above, proposed Regional Reliability Standard BAL-004-WECC-4 was
developed to address an issue identified with Requirement R1 of the currently effective standard.
The currently effective Requirement R1 establishes limits on PIIaccum based on a value
determined from the “previous calendar year.” In circumstances such as the creation of a new
Balancing Authority or the shutdown of an existing Balancing Authority, these values may not be
available. If a Balancing Authority does not have data from a previous calendar year, then
Requirement R1 as written would establish a compliance limit of zero (0) MWh. Maintaining a
monthly PIIaccum balance of zero as calculated by the WIT is not operationally feasible and could
result in non-compliance with the standard which cannot be mitigated until the end of the calendar
year.
As described in further detail below, the proposed Regional Reliability Standard addresses
this concern and improves upon the currently effective standard by: 1) expanding the existing
Background section, 2) creating a Standard-specific definition “Interchange Software”, 3) creating
a requirement to use the Interchange Software, 4) addressing treatment of Balancing Authorities
that do not have a full year of operating data, 5) consolidating and clarifying requirements, and 6)
21
Joint Petition of the North American Electric Reliability Corporation and Western Electricity Coordinating
Council for Approval of BAL-004-WECC-3 Docket No. RD18-2-000 (Mar. 8, 2018) at 7; Joint Petition of the North
American Electric Reliability Corporation and Western Electricity Coordinating Council for Approval of BAL-004WECC-02 and BAL-001-1, Docket No. RD13-11-000 (Aug. 20, 2013) at 6-7; Petition of the North American
Electric Reliability Corporation for Approval of One Proposed Western Electricity Coordinating Council Regional
Reliability Standard Regarding Automatic Time Error Correction and Three Definitions, Docket No. RM08-12-000
(July 29, 2008) at 8.
8
updating the document to NERC's newest templates. The proposed Regional Reliability Standard
continues to address matters not addressed in any other continent-wide Reliability Standard and
remains necessary for reliability in the Western Interconnection.
a. Proposed Substantive Revisions to Standard and Requirements
Proposed Regional Reliability Standard BAL-004-WECC-4 proposes to create and use a
Standard-specific definition for the term “Interchange Software” in a newly proposed Requirement
R1. The proposed definition is as follows:
Interchange Software: The single electronic confirmation tool identified by the Western
Electricity Coordinating Council (WECC), or its successor, to be used by all Balancing
Authorities throughout the Western Interconnection (WI), that serves as the primary
means for confirmation and creation of the final record of Scheduled Net Interchange
(NIS5) and Actual Net Interchange (NIA6), during all periods when the Interchange
Software is available.
[5] Previously called Net Scheduled Interchange.
[6] Previously called Net Actual Interchange
WECC’s proposed definition of “Interchange Software” is intended to allow WECC the
flexibility to change the software Balancing Authorities must use to calculate hourly PII, PIIaccum,
and ATEC if issues or concerns arise without having to revise the standard. Additionally, the
proposed “Interchange Software” definition replaces the legacy terms “Net Actual Interchange”
and “Net Scheduled Interchange” with “Actual Net Interchange” and “Scheduled Net
Interchange”, respectively, to conform with the Glossary of Terms used in NERC Reliability
Standards.22
Proposed Regional Reliability Standard BAL-004-WECC-4 Requirement R1 is as follows:
22
The Glossary of Terms Used in NERC Reliability Standards (“NERC Glossary” or “Glossary”) is available
on the NERC website at https://www.nerc.com/pa/Stand/Glossary%20of%20Terms/Glossary_of_Terms.pdf. Unless
otherwise indicated, all capitalized terms used in this petition shall have the meaning set forth in the NERC Glossary.
9
R1. Each Balancing Authority shall use the Interchange Software as the
sole source of data to calculate its ATEC. [Violation Risk Factor:
Severe] [Time Horizon: Operations Assessment]
As described above, this change would allow WECC to replace the software tool used to
calculate the ATEC if any issues with the software arise.
Proposed Regional Reliability Standard BAL-004-WECC-4 revises the currently effective
version of Requirement R1 to become Requirement R2 to address the issue described above that
Balancing Authorities must have a monthly PIIaccum balance based on a value determined from
the “previous calendar year”. In certain circumstances, these values may not be available, like
when a new Balancing Authority is created or an existing Balancing Authority is shut down. In
these instances, currently effective Requirement R1 would establish a monthly PIIaccum balance
limit of zero (0) MWh and can result in non-compliance for these Balancing Authorities until the
end of the calendar year. Proposed Regional Reliability Standard BAL-004-WECC-4 Requirement
R2 is as follows:
R2. Each Balancing Authority shall operate its system such that, following
the conclusion of each month, the month-end absolute value of its OnPeak and Off-Peak, Accumulated accumulated Primary Inadvertent
Interchange (PIIaccum), as calculated by the WECC Interchange Tool
(WIT) or its successor electronic confirmation tool Software, are each
individually less than or equal to 150% of the previous calendar year’s
integrated hourly peak demand where peak demand is total load plus
total exports. [Violation Risk Factor Medium:] [Time Horizon:
Operations Assessment]
2.1
For load-serving new Balancing Authorities, 150% of
the previous calendar year’s integrated hourly Peak Demand, the peak
demand will be the maximum hourly integrated peak demand as it
increases during the first year of operation.
As shown above, proposed Requirement R2 Part 2.1 moves the language about how to
determine PIIaccum for existing Balancing Authorities into the main body of Requirement R2,
and proposed Requirement R2 Part 2.1 is revised to state how new Balancing Authorities should
10
determine their PIIaccum balance. This revision would prevent new Balancing Authorities from
having no value available for their PIIaccum and causing unintended non-compliance.
b. Proposed Clarifying Revisions to Standard and Requirements
The following proposed revisions to Requirements R3 through R8 are intended to enhance
clarity and make proposed Regional Reliability Standard BAL-004-WECC-4 as unambiguous as
possible to avoid confusion.
Proposed Regional Reliability Standard BAL-004-WECC-4 revises the currently effective
versions of Requirements R2 and R6 to become Requirement R3 to specify PII errors must be
recalculated and corrected by the Balancing Authority within 90 days of being discovered. This
would enhance clarity and ensure PII errors are corrected in a timely manner.
Proposed Regional Reliability Standard BAL-004-WECC-4 Requirement R3 is as follows:
R3. Each Balancing Authority shall, upon discovery of an error in the its
On-Peak or Off-Peak Inadvertent Interchange calculation of PIIhourly,
recalculate and correct the Inadvertent Interchange values within 90
days, the value of PIIhourly and adjust the PIIaccum from the time of the
error is discovered. [Violation Risk Factor: Medium] [Time Horizon:
Operations Assessment]
Proposed Regional Reliability Standard BAL-004-WECC-4 revises the currently effective
version of Requirement R3 to become Requirement R4 to specify that the 24 hours per calendar
quarter exception period for ATEC to be out of service does not include any periods in which the
Interchange Software is unavailable. This would avoid any Interchange Software outages counting
towards a Balancing Authority’s allowed exception time and causing noncompliance outside of its
control.
Proposed Regional Reliability Standard BAL-004-WECC-4 Requirement R4 is as follows:
R4. Each Balancing Authority shall keep its Automatic Time Error
Corrections (ATEC) ATEC in service, with an allowable exception
11
period of less than or equal to an accumulated 24 hours per calendar
quarter for ATEC to be out of service. This period is separate from any
period during which the Interchange Software was unavailable.
[Violation Risk Factor: Medium] [Time Horizon: Same-day
Operations]
Proposed Regional Reliability Standard BAL-004-WECC-4 revises Requirement R5 to
remove the list of operating modes to which a Balancing Authority can change its Automatic
Generation Control (“AGC”) to correspond with current operating conditions. Removing the list
of operating modes eliminates any potential limitation on the kind of operating mode a Balancing
Authority may take to meet the operating conditions and would allow a Balancing Authority to
change its AGC to any operating mode necessary to meet the operating conditions.
Proposed Regional Reliability Standard BAL-004-WECC-4 Requirement R5 is as follows:
R5.
Each Balancing Authority shall be able to change its Automatic
Generation Control (AGC) operating mode between Flat Frequency
(for blackout restoration); Flat Tie Line (for loss of frequency
telemetry); Tie Line Bias; and Tie Line Bias plus Time Error Control
(used in ATEC mode), to correspond to current operating
conditions. [Violation Risk Factor: Medium] [Time Horizon: RealTime Operations]
Proposed Regional Reliability Standard BAL-004-WECC-4 revises currently effective
version of Requirement R4 to become Requirement R6 to specify the ATEC data computed needs
to be uploaded to the Interchange Software, as well as specifying how often the data needs to be
uploaded. This would ensure that ATEC data is not only calculated but also shared with WECC in
a timely manner. Additionally, proposed Requirement R6 updates the legacy term “Net Actual
Interchange” with “Actual Net Interchange” to conform with the NERC Glossary term.
Proposed Regional Reliability Standard BAL-004-WECC-4 Requirement R6 is as follows:
R6.
Each Balancing Authority shall recalculate the PIIhourly and
PIIaccum for the On-Peak and Off-Peak periods whenever
adjustments are made to upload hourly Inadvertent Actual Net
Interchange (NIA) to the Interchange Software no later than 50
12
minutes after each hour. [Violation Risk Factor: Medium] [Time
Horizon: Operations Assessment]
Proposed Regional Reliability Standard BAL-004-WECC-4 revises Requirement R7 to
specify that, if a Balancing Authority makes a month-end adjustment, that value must be included
as a part of the Actual Net Interchange data it submits to the Interchange Software. This would
ensure that any month-end adjustment is not only accounted for but also recorded in a timely
manner.
Proposed Regional Reliability Standard BAL-004-WECC-4 Requirement R7 is as follows:
R7.
Each Balancing Authority shall make the same adjustment to the
PIIaccum as it did for any making a month-end meter reading
adjustments to Inadvertent adjustment shall input that value as part
of its Actual Net Interchange (NIA). [Violation Risk Factor:
Medium] [Time Horizon: Operations Assessment]
Proposed Regional Reliability Standard BAL-004-WECC-4 revises Requirement R8 to
specify that, if a Balancing Authority makes a month-end adjustment, that value must be included
in its PIIaccum balance. This would ensure that any month-end adjustment is accurately accounted
for.
Proposed Regional Reliability Standard BAL-004-WECC-4 Requirement R8 is as follows:
R8.
Each Balancing Authority making a month-end adjustment shall
payback ensure that value is added to its accumulated Primary
Inadvertent Interchange using ATEC rather than bilateral and
unilateral payback. [Violation Risk Factor: Medium] [Time
Horizon: Operations Assessment]
Additionally, WECC proposes to revise the existing Background section to add additional
context regarding the history of WECC’s ATEC procedure as well as providing a brief description
of what was revised in each previous version of the standard. WECC also proposes to clarify that
the proposed Regional Reliability Standard BAL-004-WECC-4 uses the term “ATEC” as defined
in the WECC Regional Definitions section of the NERC Glossary.
13
c. Enforceability of Proposed Reliability Standard
The proposed Regional Reliability Standard includes VRFs and VSLs. The VRFs and
VSLs provide guidance on the way the ERO will enforce the requirements of the proposed
Reliability Standard. The VRFs and VSLs are substantively unchanged from the currently effective
version of the Regional Reliability Standard. As such, they continue to comport with NERC and
Commission guidelines related to their assignment.
In addition, the proposed Regional Reliability Standard also includes measures that support
each requirement by clearly identifying what is required and how the ERO will enforce the
requirement. These measures help ensure that the requirements will be enforced in a clear,
consistent, and non-preferential manner and without prejudice to any party.23 The measures are
substantively unchanged from the currently effective version of the Regional Reliability Standard.
V.
EFFECTIVE DATE
NERC and WECC respectfully request that the Commission approve the proposed
Reliability Standard to become effective as set forth in the proposed Implementation Plan provided
in Exhibit B hereto. The proposed Implementation Plan provides that the proposed Reliability
Standard shall become effective on the first day of the second quarter following the effective date
of the Commission’s order approving the proposed Reliability Standard.
As proposed, many of the required tasks of proposed Reliability Standard BAL-004WECC-4 are already being performed in the same or similar manner as those under the currently
effective version of the standard. The new or modified tasks impose a minimal burden achievable
in the time window between regulatory approval and the proposed Effective Date.
23
Order No. 672 at P 327.
14
VI.
CONCLUSION
For the reasons set forth above, NERC and WECC respectfully request that the
Commission approve:
Proposed Regional Reliability Standard BAL-004-WECC-4, and associated elements
included in Exhibit A, effective as proposed herein;
the proposed Implementation Plan included in Exhibit B; and
the retirement of Regional Reliability Standard BAL-004-WECC-3 effective as
proposed herein.
Respectfully submitted,
/s/ Alain Rigaud
Chris Albrecht
Assistant General Counsel
Western Electricity Coordinating Council
155 North 400 West, Suite 200
Salt Lake City, UT 84103
(801) 582-0353
[email protected]
Counsel for the Western Electricity
Coordinating Council
Lauren Perotti
Assistant General Counsel
Alain Rigaud
Associate Counsel
North American Electric Reliability Corporation
1401 H Street, N.W., Suite 410
Washington, D.C. 20005
(202) 400-3000
[email protected]
[email protected]
Counsel for the North American Electric Reliability
Corporation
Date: March 12, 2025
15
Exhibit A
Proposed Regional Reliability Standard
BAL-004-WECC-4 – Automatic Time Error Correction
Exhibit A-1
Proposed Regional Reliability Standard
BAL-004-WECC-4 – Automatic Time Error Correction
(Redline)
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Proposed Regional Reliability Standard
BAL-004-WECC-4 – Automatic Time Error Correction
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Exhibit B
Implementation Plan
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Exhibit C
Order No. 672 Criteria
Attachment K
Order 672 Criteria
WECC-0147 BAL-004-WECC-4
Automatic Time Error Correction
Introduction
The North American Electric Reliability Corporation (NERC) is responsible for ensuring that the
Reliability Standards, Violation Risk Factors (VRF), Violation Severity Levels (VSL), definitions,
Variances, and Interpretations developed by drafting teams are developed in accordance with NERC
processes. These standards must also meet NERC’s benchmarks for Reliability Standards, as well as
criteria for governmental approval.
In Federal Energy Regulatory Commission (FERC) Order No. 672, 1 FERC identified criteria that it will
use to analyze proposed Reliability Standards for approval to ensure they are just, reasonable, not
unduly discriminatory or preferential, and in the public interest. The discussion below identifies these
factors, and explains how the proposed Reliability Standard meets or exceeds the criteria.
For purposes of this filing, the use of the terms Reliability Standard and Standard are synonymous with
Regional Reliability Standard, unless otherwise specified.
Designed for a Specific Goal
Proposed Reliability Standards must be designed to achieve a specified reliability goal.
The proposed Reliability Standard must address a reliability concern that falls within the requirements
of Section 215 of the Federal Power Act. That is, it must provide for the reliable operation of BulkPower System facilities. It may not extend beyond reliable operation of such facilities or apply to other
facilities. Such facilities include all those necessary for operating an interconnected electric energy
transmission network, or any portion of that network, including control systems. The proposed
Reliability Standard may apply to any design of planned additions or modifications of such facilities
that is necessary to provide for reliable operation. It may also apply to cybersecurity protection. Order
No. 672 at P 321.
Further, NERC Reliability Standards are based on certain reliability principles that define the
foundation of reliability for North American bulk power systems. Each Reliability Standard shall
enable or support one or more of the reliability principles, thereby ensuring that each standard serves a
purpose in support of reliability of the North American bulk power systems. Each Reliability Standard
1
FERC Order 672
155 N ort h 400 We st | Suite 200 | Salt Lake Cit y, U t ah 84103
www.we cc .org
Attachment K
shall also be consistent with all of the reliability principles, thereby ensuring that no standard
undermines reliability through an unintended consequence.
This project updates BAL-004-WECC-3, Automatic Time Error Correction (ATEC), resulting in a
nomenclature of BAL-004-WECC-4.
Reliability Principle 2
BAL-002-WECC-4 meets NERC’s Reliability Principle #1:
•
1. Interconnected bulk power systems shall be planned and operated in a coordinated manner
to perform reliably under normal and abnormal conditions as defined in the NERC Standards.”
Purpose
The purpose of the standard is:
•
To maintain Western Interconnection (WI) frequency, and ensure that time error accumulation
via Primary Inadvertent Interchange (PII) payback is conducted in a manner that does not result
in a negative impact on reliability.
Applicability
The standard applies to the following entities:
•
Balancing Authorities operating synchronously within the Western Interconnection.
Technically Sound
Proposed Reliability Standards must contain a technically sound method to achieve the goal.
The proposed Reliability Standard must be designed to achieve a specified reliability goal and must
contain a technically sound means to achieve this goal. Although any person may propose a topic for a
Reliability Standard to the Electric Reliability Organization (ERO), in the ERO’s process, the specific
proposed Reliability Standard should be developed initially by persons within the electric power
industry and community with a high level of technical expertise and be based on sound technical and
engineering criteria. It should be based on actual data and lessons learned from past operating
incidents, where appropriate. The process for ERO approval of a proposed Reliability Standard should
be fair and open to all interested persons. Order No. 672 at P 324.
Technically Sound
Although a technical white paper is not provided with this filing, only proposed Requirement R1
includes new concepts. The remainder of the document reflects existing tasks and concepts. Proposed
Requirement R1 requires the applicable entities to use one specified software for purposes of
2
https://www.nerc.com/pa/Stand/Resources/Documents/Reliability_Principles.pdf
2
Attachment K
calculating ATEC. By mandating the use of a single piece of software, the output needed for ATEC
becomes more standardized.
Applicability
Proposed Reliability Standards must be applicable to users, owners, and operators of the bulk
power system, and not others.
The proposed Reliability Standard may impose a requirement on any user, owner, or operator of such
facilities, but not on others. Order No. 672 at P 322.
BAL-004-WECC-4 applies to the following entities:
•
Balancing Authorities operating synchronously within the Western Interconnection.
The applicable entities have not changed between BAL-004-WECC-3 and BAL-004-WECC-4.
Clear and Unambiguous
Proposed Reliability Standards must be clear and unambiguous as to what is required and who is
required to comply.
The proposed Reliability Standard should be clear and unambiguous regarding what is required and
who is required to comply. Users, owners, and operators of the Bulk-Power System must know what
they are required to do to maintain reliability. Order No. 672 at P 325.
BAL-004-WECC-4 is clear and unambiguous.
The standard specifies: 1) a purpose, 2) designates the entities to which that standard applies, and 3)
provides a background section.
The Requirements and Measures section: 1) specifies which entity is required to perform each task, 2) is
supported by a Measure indicating that evidence must be available to prove performance of the
assigned task, and 3) is augmented by a Rationale section.
Whereas each Requirement is assigned a Violation Risk Factor, each Requirement is also supported by
the compliance Violation Severity Table illustrating the potential consequences for failure to comply
with the standard.3
See the Technically Sound and Applicability sections of this document. See also Attachment H – VSL and VRF
Justifications provided with this filing.
3
3
Attachment K
Understandable Consequence
Proposed Reliability Standards must include clear and understandable consequences and a range of
penalties (monetary and/or non-monetary) for a violation.
The possible consequences, including range of possible penalties, for violating a proposed Reliability
Standard should be clear and understandable by those who must comply. Order No. 672 at P 326.
BAL-004-WECC-4 creates a single new Requirement: R1. The assigned Violation Risk Factor (VRF) is
“Medium,” and the assigned Violation Severity Level (VSL) is “High.” Because the balance of the
document does not propose any new concepts, the VRF/VSL levels previously assigned to that content
has been adopted for BAL-004-WECC-4.4
Measurability for Compliance
Proposed Reliability Standards must identify a clear and objective criterion or measure for
compliance, so that it can be enforced in a consistent and non-preferential manner.
There should be a clear criterion or measure of whether an entity is in compliance with a proposed
Reliability Standard. It should contain or be accompanied by an objective measure of compliance so
that it can be enforced and so that enforcement can be applied in a consistent and non-preferential
manner. Order No. 672 at P 327.
BAL-004-WECC-4 creates a single new Requirement: R1. The Requirement and associated Measure is
as follows:
A. Requirements and Measures
R1.
Each Balancing Authority shall use the Interchange Software as the sole source of data to
calculate its ATEC. [Violation Risk Factor: Medium] [Time Horizon: Operations Assessment]
M1. Each Balancing Authority will have evidence that it used the Interchange Software as the
sole source of data to calculate its ATEC, as required in Requirement R1.
Evidence may include, but is not limited to production of a corporate attestation or
operating procedure indicating use of the Interchange Software as the sole source for
calculating ATEC.
The balance of the standard includes content from Requirements and Measures previously approved.5
4
5
See Attachment H – VSL and VRF Justifications provided with this filing.
See Attachment I, Mapping Document.
4
Attachment K
Effective and Efficient
Proposed Reliability Standards should achieve a reliability goal effectively and efficiently - but
does not necessarily have to reflect “best practices” without regard to implementation cost.
The proposed Reliability Standard does not necessarily have to reflect the optimal method, or “best
practice,” for achieving its reliability goal without regard to implementation cost or historical regional
infrastructure design. It should however achieve its reliability goal effectively and efficiently. Order
No. 672 at P 328.
During the four postings of this project at WECC, no concerns were raised regarding implementation
costs.
Lowest Common Denominator
Proposed Reliability Standards cannot be “lowest common denominator,” i.e., cannot reflect a
compromise that does not adequately protect bulk power system reliability.
The proposed Reliability Standard must not simply reflect a compromise in the ERO’s Reliability
Standard development process based on the least effective North American practice — the so-called
“lowest common denominator” — if such practice does not adequately protect Bulk-Power System
reliability. Although the Commission will give due weight to the technical expertise of the ERO, we
will not hesitate to remand a proposed Reliability Standard if we are convinced it is not adequate to
protect reliability. Order No. 672 at P 329.
BAL-004-WECC-4 maintains the previously approved content but adds a single proposed requirement:
R1. In that requirement, the applicable entities are required to use a single, specified software platform.
The platform is easily accessible, and the cost is commercially reasonable, as evidenced by the large
number of applicable entities already using the product.
Costs
Proposed Reliability Standards may consider costs to implement for smaller entities but not at
consequence of less than excellence in operating system reliability.
A proposed Reliability Standard may take into account the size of the entity that must comply with the
Reliability Standard and the cost to those entities of implementing the proposed Reliability Standard.
However, the ERO should not propose a “lowest common denominator” Reliability Standard that
would achieve less than excellence in operating system reliability solely to protect against reasonable
expenses for supporting this vital national infrastructure. For example, a small owner or operator of the
Bulk-Power System must bear the cost of complying with each Reliability Standard that applies to it.
Order No. 672 at P 330.
5
Attachment K
BAL-004-WECC-4 maintains the previously approved content but adds a single proposed requirement:
R1. In that requirement, the applicable entities are required to use a single, specified software platform.
The platform is easily accessible, and the cost is commercially reasonable, as evidenced by the large
number of applicable entities already using the product.
Continent-wide and Regional Variations
Proposed Reliability Standards must be designed to apply throughout North America to the
maximum extent achievable with a single reliability standard while not favoring one area or
approach.
A proposed Reliability Standard should be designed to apply throughout the interconnected North
American Bulk-Power System, to the maximum extent this is achievable with a single Reliability
Standard. The proposed Reliability Standard should not be based on a single geographic or regional
model but should take into account geographic variations in grid characteristics, terrain, weather, and
other such factors; it should also take into account regional variations in the organizational and
corporate structures of transmission owners and operators, variations in generation fuel type and
ownership patterns, and regional variations in market design if these affect the proposed Reliability
Standard. Order No. 672 at P 331.
In the Order 740 Remand at P4, the Commission states that:
“Reliability Standards that the ERO proposes to the Commission may include Reliability Standards that
are proposed to the ERO by a Regional Entity… When the ERO reviews a regional Reliability Standard
that would be applicable on an interconnection-wide basis and that has been proposed by a Regional
Entity organized on an interconnection-wide basis, the ERO must rebuttably presume that the regional
Reliability Standard is just, reasonable, not unduly discriminatory or preferential, and in the public
interest. In turn, the Commission must give “due weight” to the technical expertise of the ERO and of a
Regional Entity organized on an interconnection-wide basis.”
Further, regional entities may propose Regional Reliability Standards that set more stringent reliability
requirements than the NERC Reliability Standard or cover matters not covered by an existing NERC
Reliability Standard. NERC Rules of Procedure, Section 312, Regional Reliability Standards.
BAL-004-WECC-4 addresses calculation of ATEC specifically within the Western Interconnection.
There are no continent-wide Standards using the more granular calculation approach specified in the
proposed standard.
6
Attachment K
No Undue Negative Effect
Proposed reliability standards should cause no undue negative effect on competition or restriction
of the grid.
As directed by section 215 of the FPA, the Commission itself will give special attention to the effect of a
proposed Reliability Standard on competition. The ERO should attempt to develop a proposed
Reliability Standard that has no undue negative effect on competition. Among other possible
considerations, a proposed Reliability Standard should not unreasonably restrict available transmission
capability on the Bulk-Power System beyond any restriction necessary for reliability and should not
limit use of the Bulk-Power System in an unduly preferential manner. It should not create an undue
advantage for one competitor over another. Order No. 672 at P 332.
The assigned drafting team does not foresee any negative impacts on competition resulting from the
proposed standard.
BAL-004-WECC-4 was posted for comment on four occasions at WECC. No cost issues were raised in
those four postings. However, in the single NERC 45-day posting, Berkshire Hathway and NV Energy
raised concerns that the proposed standard may have an adverse impact on reliability or commerce in a
neighboring region or interconnection. (See NERC 45-day Response to Comments provided with this
filing).
The drafting team responded as follows:
“Although [Berkshire and NV Energy opine] that the proposed standard poses “an adverse
impact to reliability or commerce in a neighboring region or interconnection,” [neither entity
specified] any concerns here nor [did they] raise any concerns during the estimated 21 public
meetings during which the standard was developed, nor the mandatory Standards Briefing
prior to balloting.
The record shows that [neither entity entered] the Ballot Pool nor engage[d] the WSC or WECC
Board of Directors regarding this project.
As such, [neither Berkshire nor NV] has…provided the DT with anything to address.”
No changes were made in response to the comments provided by Berkshire or NV.
Implementation of New Requirements (Effective Date)
The implementation time for the proposed Reliability Standards must be reasonable.
In considering whether a proposed Reliability Standard is just and reasonable, the Commission will
consider also the timetable for implementation of the new requirements, including how the proposal
balances any urgency in the need to implement it against the reasonableness of the time allowed for
7
Attachment K
those who must comply to develop the necessary procedures, software, facilities, staffing or other
relevant capability. Order No. 672 at P 333.
Proposed Effective Date6
The proposed effective date is the first day of the second quarter following regulatory approval.
Justification
As proposed, many of the required tasks are already being performed in the same or similar manner as
those currently approved. The new or modified tasks impose a minimal burden achievable in the time
window between regulatory approval and the proposed Effective Date.
Fair and Open Process
The Reliability Standard development process must be open and fair.
Further, in considering whether a proposed Reliability Standard meets the legal standard of review, we
will entertain comments about whether the ERO implemented its Commission-approved Reliability
Standard development process for the development of the particular proposed Reliability Standard in a
proper manner, especially whether the process was open and fair. However, we caution that we will
not be sympathetic to arguments by interested parties that choose, for whatever reason, not to
participate in the ERO’s Reliability Standard development process if it is conducted in good faith in
accordance with the procedures approved by the Commission. Order No. 672 at P 334.
BAL-004-WECC-4 was developed using the WECC Reliability Standards Development Procedures
(Procedures) approved by FERC in effect at the time of each step in the process.
In accordance with the Procedures
1) All drafting team meetings are open to the public.
2) All drafting team meetings were announced via the WECC Standards Email List for the period
prescribed in the Procedures.
3) Notice of the meetings was provided to NERC and posted on the WECC Calendar.
4) All meetings were supported by a telephone conference bridge associated with an online
internet visual capability allowing all participants to see the document(s) as they were being
developed. Further, this team held an open-mic Standards Briefing before balloting, which
afforded the industry an additional opportunity to have its questions addressed.
BAL-004-WECC-4 is the result of approximately 21 publicly noticed and convened meetings during
which the public was invited to comment on the project.
6
See Attachment F Implementation Plan provided with this filing.
8
Attachment K
On December 7, 2021, the WECC Standards Committee (WSC) reviewed and approved the WECC-0147
BAL-004-WECC-4, Automatic Time Error Correction (ATEC) Standard Authorization Request (SAR), at
the duly noticed public meeting.
Per the WSC’s request, WECC solicited and the WSC approved a standards drafting team (DT).
Thes project was posted for public comment on four occasions at WECC, prior to a single 45-day
posting at NERC, resulting from 16 publicly noticed drafting team meetings. The drafting team
meetings were augmented by a publicly noticed WECC Standards Briefing, held prior to opening a
WECC ballot.
(For dates, see Attachment E, Project Roadmap, provided with this filing.)
After reaching a 100% quorum: 1) this project’s publicly solicited Ballot Pool approved this project with
a 100% affirmative ballot, 2) the WSC publicly vetted its decision to approve the Procedural
machinations of this project, 3) and the WECC Board of Directors publicly approved the project for
further regulatory review at NERC/FERC.
All of these forums are public; public comment was invited in every forum.
Balanced with Other Vital Interests
Proposed Reliability Standards must balance with other vital public interests.
Finally, we understand that at times development of a proposed Reliability Standard may require that
a particular reliability goal must be balanced against other vital public interests, such as environmental,
social and other goals. We expect the ERO to explain any such balancing in its application for approval
of a proposed Reliability Standard. Order No. 672 at P 335.
Neither WECC nor the drafting team is aware of any other vital public interests.
However, in the NERC 45-day posting provided with this filing, although:
“NV Energy opines that the proposed standard poses “a serious and substantial threat to public
health, safety, welfare, or national security,” NV [did] not specify any concerns…nor did NV
raise any concerns during the estimated 21 public meetings during which the standard was
developed, nor the mandatory Standards Briefing prior to balloting.
The record shows that NV did not enter into the Ballot Pool nor engage the WSC or WECC
Board of Directors regarding this project.
As such, NV does not provide the DT with anything to address.”
No changes were made in response to NV Energy’s conclusory statement.
9
Attachment K
Consideration of Other Facts
Proposed Reliability Standards must consider any other relevant factors.
In considering whether a proposed Reliability Standard is just and reasonable, [FERC] will consider
[several] general factors, as well as other factors that are appropriate for the particular Reliability
Standard proposed. Order No. 672 at P 323.
Neither WECC nor the drafting team raises any further concern.
10
Exhibit D
Analysis of Violation Risk Factors and Violation Security
Levels
Attachment H
VSL and VRF Justification
WECC-0147 ATEC
VSL and VRF Justification - Proposed
Although portions of the standard have been rearranged and redrafted for clarity,1 the project only
proposes one new requirement.
For BAL-002-WECC-4, Automatic Time Error Correction, Requirement R1, the proposed VRF is
“Medium,” matching the rest of the document.2 The proposed VSL is “Severe” as the required task is
binary.3
The VSLs and VRFs as previously approved were adopted for this project.
Proposed Requirement R1
R#
R1.
Violation Severity Levels
Lower VSL
Moderate VSL
High VSL
Severe VSL
NA
NA
NA
The Balancing Authority
failed to use the Interchange
Software as the sole source
to calculate ATEC.
1
See Attachment I Mapping Document.
NERC Violation Risk Factors.
https://www.nerc.com/pa/Stand/Resources/Documents/Violation_Risk_Factors.pdf
2
3
NERC Violation Severity levels. https://www.nerc.com/pa/Stand/Resources/Documents/VSL_Guidelines.PDF
155 N ort h 400 We st | Suite 200 | Salt Lake Cit y, U t ah 84103
www.we cc .org
Exhibit E
Summary of Development History and Complete Record
of Development
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Attachment I
Mapping Document
WECC-0147
BAL-004-WECC-4 ATEC
Mapping Document
As-Proposed (New)
As-Approved (Old)
R1
Comment
This is a new Requirement.
R2
R1
Improved readability
R3
R2 and R6
Improved readability; includes a requirement to
correct errors. As-approved R2 and R6 are
consolidated into As-proposed R3.
R4
R3
Improved readability. Clarifying sentence has
been added addressing Interchange Software
unavailability.
R5
R5
Eliminates superfluous list in favor of responding
to current operating conditions.
R6
R4
Shifts the task from computing to uploading
(Computing is assumed as the upload cannot
occur without the computation.)
R7
R7
Improved readability
R8
R8
Eliminates proscriptions in favor of ensuring
values are correct.
155 N ort h 400 We st | Suite 200 | Salt Lake Cit y, U t ah 84103
www.we cc .org
NERC Posting – Record of Development
(1) Redline
(2) Info
BAL-004-WECC-4
(3)
Clean | (4) Redline to Last Approved
(5) Implementation Plan
(6) Unofficial Comment Form (Word)
Submit Comments
(7) Comments Received
(8) Consideration of Comments
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BAL‐004‐WECC‐34 ─ Automatic Time Error Correction WECC‐0147 Att D – Att B Redlined to Att C
A. Introduction
1. Title:
Automatic Time Error Correction
2. Number:
BAL‐004‐WECC‐34
3. Purpose:
To maintain Western Interconnection (WI) frequency, and to ensure that
Time Error Corrections andtime error accumulation via Primary
Inadvertent Interchange (PII) payback are effectivelyis conducted in a
manner that does not adversely affect the result in a negative impact on
reliability of the Interconnection..
5.4.Applicability:
5.1.4.1.
Functional Entities:
4.1.1.
Balancing Authorities that operateoperating synchronously
inwithin the Western Interconnection.WI
4.2. Compliance Waiver:
4.2.1.
See Section C., Compliance, 1.4 Compliance Waiver, for applicability
during periods of Interchange Software unavailability.
5. Effective Date:
On the The first day of the second quarter, after applicable
following regulatory approval has been received (or the.
6. Background:
Pre‐2000 (prior to mandatory Standards), the Western Electricity Coordinating Council
(WECC) operated using the Minimum Operating Reliability Standard otherwise
becomesCriteria (MORC). Per MORC Section D. Time Control, Control Areas were
required to assist in maintaining frequency at or near 60.0 Hz, as prescribed in the
Western System Coordinating Council (WSCC)1 Procedure for Time Error Control (PTEC).
Various versions of the PTEC predate 1980.
In February 2003, the WECC Automatic Time Error Correction (ATEC) Procedure
(Procedure) became effective the first day of the fourth quarter following for all
Balancing Authorities in the WI. The original intent of the Procedure was to minimize
the number of manual Time Error Corrections in the WI.2
In June 2007, the Procedure was translated into BAL‐STD‐004‐1, Time Error Correction,
followed by BAL‐004‐WECC‐1 through 3, Time Error Correction.3 BAL‐004‐WECC‐1
required Balancing Authorities within the WI to maintain Interconnection frequency
within a predefined frequency profile, and to ensure that Time Error Corrections would
WECC began in 1967 as the Western Systems Coordinating Council (WSCC), a group of 40 power systems
with a common goal of providing reliable power to the public whom they served. WECC was founded
March 22, 1994.
2
The Procedure provided for cost assignment and equitable payback of Inadvertent Interchange, not
otherwise addressed in BAL‐004‐4, Time Error Correction.
3
See Version History Table.
1
Page 1 of 25
BAL‐004‐WECC‐34 ─ Automatic Time Error Correction WECC‐0147 Att D – Att B Redlined to Att C
not result in a negative impact on Interconnection reliability.
In September 2009, in response to Federal Energy Regulatory Commission (FERC) Order
723, WECC received Standard Authorization Request (SAR) WECC‐0068 requesting
modification of BAL‐004‐WECC‐1. Modifications were effective April 1, 2014, creating
BAL‐004‐WECC‐2. BAL‐004‐WECC‐2 introduced two performance metrics: 1) in
Requirement R1, a 150% metric, and 2) in Requirement R2, a 90‐day metric. Neither of
these metrics are supported by technical studies. They were included in BAL‐004‐WECC‐
2 as a compromise during drafting.
In May 2018, FERC approved minor revisions to BAL‐004‐WECC‐2 as part of WECC SAR
WECC‐0124, effective October 1, 2018, creating BAL‐004‐WECC‐3.4
In 2023, this Standard was reviewed as part of the WECC SAR WECC‐0147. The drafting
team noted: 1) Version 3, Requirement R5 migrated from the pre‐2000 MORC without
initial or subsequent technical support, and 2) R5 addresses capabilities of Automatic
Generator Control (AGC) found in no other Standard, without mandating its use or
stating how that capability interfaces with ATEC. R5 is retained herein until it can be
properly addressed per a NERC Board adoption where regulatory approval is not
required).Standard Authorization Request.
7. Standard‐Only Definition:
7.1 Interchange Software:
This Standard uses the Standard‐Only term “Interchange Software” to mean:
The single electronic confirmation tool identified by the Western Electricity
Coordinating Council (WECC), or its successor, to be used by all Balancing Authorities
throughout the Western Interconnection (WI), that serves as the primary means for
confirmation and creation of the final record of Scheduled Net Interchange (NIS5) and
Actual Net Interchange (NIA6), during all periods when the Interchange Software is
available.
7.2. ATEC:
This Standard uses the term “ATEC” as defined in the WECC Regional Definitions
section of the NERC Glossary of Terms Used in Reliability Standards.
FERC Docket No. RD18‐2‐000. Effective Date October 1, 2018.
5
Previously called Net Scheduled Interchange
6
Previously called Net Actual Interchange
4
Page 2 of 25
BAL‐004‐WECC‐34 ─ Automatic Time Error Correction WECC‐0147 Att D – Att B Redlined to Att C
B. Requirements and Measures
R1. Each Balancing Authority shall use the Interchange Software as the sole source of data
to calculate its ATEC. [Violation Risk Factor: Severe] [Time Horizon: Operations
Assessment]
M1. Each Balancing Authority will have evidence that it used the Interchange Software as
the sole source of data to calculate its ATEC, as required in Requirement R1.
Evidence may include, but is not limited to production of a corporate attestation or
operating procedure indicating use of the Interchange Software as the sole source for
calculating ATEC.
R2. Each Balancing Authority shall operate its system such that, following the conclusion of
each month, the month‐end absolute value of its On‐Peak and Off‐Peak,
Accumulatedaccumulated Primary Inadvertent Interchange (PIIaccum), as calculated by
the WECC Interchange Tool (WIT) or its successor electronic confirmation toolSoftware,
are each individually less than or equal to: 150% of the previous calendar year’s
integrated hourly peak demand where peak demand is total load plus total exports.
[Violation Risk Factor Medium:] [Time Horizon: Operations Assessment]
2.1. For load‐servingnew Balancing Authorities, 150% of the previous calendar year’s
integrated hourly Peak Demand,the peak demand will be the maximum hourly
integrated peak demand as it increases during the first year of operation.
1.1 For generation‐only Balancing Authorities, 150% of the previous calendar year’s
integrated hourly peak generation.
M1M2. Each Balancing Authority will have evidence that it operated its system such that,
following the conclusion of each month, the month‐end absolute value of its On‐Peak
and Off‐Peak, Accumulatedaccumulated Primary Inadvertent Interchange (PIIaccum),
as calculated by the WECC Interchange Tool (WIT)Software, are each individually less
than or its successor electronic confirmation tool, meets all criteria statedequal to
150% of the previous calendar year’s integrated hourly peak demand where peak
demand is total load plus total exports, average load in those hours, as calculated by
the Interchange Software, per Requirement R1R2, or per the exception allowed in R2.1.
R2R3. Each Balancing Authority shall, upon discovery of an error in theits On‐Peak or
Off‐Peak Inadvertent Interchange calculation of PIIhourly, recalculate and correct the
Inadvertent Interchange values within 90 days, the value of PIIhourly and adjust the
PIIaccum from the time of the error. is discovered. [Violation Risk Factor: Medium]
[Time Horizon: Operations Assessment]
M2. Forms of acceptableM3.
Each Balancing Authority discovering an error in its On‐
Peak or Off‐Peak Inadvertent Interchange calculation will have evidence of
compliance withthat it recalculated and corrected the Inadvertent Interchange values,
within 90 days from the time the error is discovered, as required in Requirement
R2R3.
Page 3 of 25
BAL‐004‐WECC‐34 ─ Automatic Time Error Correction WECC‐0147 Att D – Att B Redlined to Att C
Evidence may include, but areis not limited to any one of the following:
Data, screenScreen shots from the WECC Interchange Tool (WIT) or its successor
electronic confirmation tool,Software;
Data, screenScreen shots from the Balancing Authority’s internal Balancing
Authority tool, or
Production of data from any othersoftware functions such as internal databases,
spreadsheets, and displays.;
R3Dated archive files; and
Historic data.
R4. Each Balancing Authority shall keep its Automatic Time Error Correction (ATEC)ATEC
in service, with an allowable exception period of less than or equal to an
accumulated 24 hours per calendar quarter for ATEC to be out of service. This period
is separate from any period during which the Interchange Software was unavailable.
[Violation Risk Factor: Medium] [Time Horizon: Same‐day Operations]
M3. Forms of acceptableM4. Each Balancing Authority will have evidence of
compliance withthat it kept ATEC in service as required in Requirement R3R4,
subject to the allowable exceptions provided.
Evidence may include, but areis not limited to:
Dated archived files,
Historical data,
Other data that demonstrates the ATEC was out of service for less than 24
hours per calendar quarter.
R4. Each Balancing Authority shall compute each of the following using the WECC
Interchange Tool (WIT) or its successor electronic confirmation tool, no later than 50
minutes after each hour,
3.0. PIIhourly,
3.0. PIIaccum,
3.0. Automatic Time Error Correction term (IATEC).
[Violation Risk Factor: Medium] [Time Horizon: Operations Assessment]
M4. Forms of acceptable evidence of compliance with Requirement R4 include but are
not limited to any one of the following:
Data, screen shots from the WECC Interchange Tool (WIT) or its
successor electronic confirmation tool, that demonstrate compliance;
Data, screenScreen shots from the Interchange Software;
Screen shots from internalthe Balancing Authority tool that demonstrate
Page 4 of 25
BAL‐004‐WECC‐34 ─ Automatic Time Error Correction WECC‐0147 Att D – Att B Redlined to Att C
compliance; or,
Data from any otherAuthority’s internal software functions such as internal
databases, spreadsheets, and displays that demonstrate compliance.;
Dated archive files; and
Historical data.
R5. Each Balancing Authority shall be able to change its Automatic Generation Control
(AGC) operating mode between Flat Frequency (for blackout restoration); Flat Tie
Line (for loss of frequency telemetry); Tie Line Bias; and Tie Line Bias plus Time
Error Control (used in ATEC mode), to correspond to current operating conditions.
[Violation Risk Factor: Medium] [Time Horizon: Real‐Time Operations]
M5. Forms of acceptableEach Balancing Authority will have evidence of compliance with
Requirementthat its AGC is able to change operating modes to correspond to current
operating conditions, as required in R5.
Evidence may include, but areis not limited to any one of the following::
Screen shots from Energy Management System,; and
Demonstration using an off‐line system.
R6. Each Balancing Authority shall recalculate the PIIhourly and PIIaccum for the On‐
Peak and Off‐Peak periods whenever adjustments are made to upload hourly
InadvertentActual Net Interchange or DTE(NIA) to the Interchange Software no
later than 50 minutes after each hour. [Violation Risk Factor: Medium] [Time
Horizon: Operations Assessment]
M6. Forms of acceptableEach Balancing Authority will have evidence of compliance
withthat it uploaded hourly Actual Net Interchange (NIA) to the Interchange
Software no later than 50 minutes after each hour, as required in Requirement R6.
Evidence may include, but areis not limited to any one of the following:
Data, screenScreen shots from the Interchange Software;
Screen shots from the WECC Interchange Tool (WIT) or its successor
electronic confirmation tool, that demonstrate compliance;
Data, screen shots from anBalancing Authority’s internal Balancing
Authority tool that demonstrate compliance with; or,
Data from any other software functions such as internal databases,
spreadsheets, and displays that demonstrate compliance.;
Dated archive files; and
Historical data.
Page 5 of 25
BAL‐004‐WECC‐34 ─ Automatic Time Error Correction WECC‐0147 Att D – Att B Redlined to Att C
R7. Each Balancing Authority shall make the same adjustment to the PIIaccum as it did for
anymaking a month‐end meter reading adjustments to Inadvertentadjustment shall
input that value as part of its Actual Net Interchange. (NIA). [Violation Risk Factor:
Medium] [Time Horizon: Operations Assessment]
M7. Forms of acceptable
Each Balancing Authority making a month‐end
adjustment will have evidence of compliance withthat it input that value as part of
its Actual Net Interchange (NIA), as required in Requirement R7 include but are not
limited to any one of the following:.
Data, screen shots from the WECC Interchange Tool (WIT) or its
successor electronic confirmation tool, that demonstrate compliance;
Data, screen shots from an internal Balancing Authority tool that
demonstrate compliance; or,
Production of data from any other databases, spreadsheets, displays that
demonstrate compliance.
R8. Each Balancing Authority making a month‐end adjustment shall paybackensure
that value is added to its accumulated Primary Inadvertent Interchange using ATEC
rather than bilateral and unilateral payback. [Violation Risk Factor: Medium] [Time
Horizon: Operations Assessment]
M8.
M8. Forms of acceptableEach Balancing Authority making a month‐end adjustment will
have evidence of compliance with Requirement R8 include but are not limitedthat
the value was added to historical On‐Peak and Off‐Peakits accumulated Primary
Inadvertent Interchange data, data from the WECC Interchange Tool, and ACE
data., as required in Requirement R8.
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BAL‐004‐WECC‐34 ─ Automatic Time Error Correction WECC‐0147 Att D – Att B Redlined to Att C
C. Compliance
2.1. Compliance Monitoring Process
2.2.1.1.
Compliance Enforcement Authority:
The Regional Entity shall serve asAs defined in the NERC Rules of
Procedure, “Compliance Enforcement Authority.
For entities that do not work for ” means NERC or the Regional Entity, in their
respective roles of monitoring and enforcing compliance with the Regional Entity
shall serve as the Compliance Enforcement Authority.
ForNERC Reliability Coordinators and other functional entities that work for their
Regional Entity, the ERO or a Regional Entity approved by the ERO and FERC or
other applicable governmental authorities shall serve as the Compliance
Enforcement AuthorityStandards.
For responsible entities that are also Regional Entities, the ERO or a Regional Entity
approved by the ERO and FERC or other applicable governmental authorities shall
serve as the Compliance Enforcement Authority.
0.0 Compliance Monitoring and Assessment Processes:
Compliance Audits
Self‐Certifications
Spot Checking
Compliance Investigations
Self‐Reporting
Complaints
2.9.1.2.
Evidence Retention:
The following evidence retention periodsperiod(s) identify the period of time an
entity is required to retain specific evidence to demonstrate compliance. For
instances where the evidence retention period specified below is shorter than the
time since the last audit, the Compliance Enforcement Authority may ask an entity
to provide other evidence to show that it was compliant for the full ‐time period
since the last audit.
Each BalancingThe applicable entity shall keep data or evidence to show
compliance as identified below unless directed by its Compliance Enforcement
Authority in the Western Interconnection shall to retain specific evidence for a
longer period of time as part of an investigation.
Each Balancing Authority in the WI shall keep the following records for the
preceding calendar year (January – December) plus the current calendar year:
Its values offor PIIhourly, PIIaccum (On‐Peak and Off‐Peak), D∆TE, and any
month‐end adjustments for the preceding calendar year (January –
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BAL‐004‐WECC‐34 ─ Automatic Time Error Correction WECC‐0147 Att D – Att B Redlined to Att C
December), as well as the current calendar year.
Each Balancing Authority in the Western Interconnection shall retain the amount
of time Documentation illustrating any period(s) during which the Balancing
Authority operated without ATEC for the preceding calendar year (January –
December), as well as the current calendar year., including the reason ATEC
was not in operation.
1.1
Additional Compliance Information
None
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Table of Compliance Elements
1.3 Compliance Monitoring and Enforcement Program: As defined in the NERC Rules
of Procedure, “Compliance Monitoring and Enforcement Program” refers to the
identification of the processes that will be used to evaluate data or information for
the purpose of assessing performance or outcomes with the associated Reliability
Standard.
1.4 Compliance Waiver: Compliance with this Standard is waived for all periods during
which the Interchange Software is deemed unavailable.
Interchange Software is deemed unavailable when it fails to function as designed by
the software’s vendor, or when the applicable entity(ies) is unable to access the
Interchange Software due to hardware, software, or communications difficulties,
such as but not limited to, communications failure, lack of internet connectivity, or
catastrophic hardware/software system failure.
Failure of the applicable entity(ies) to procure access to the Interchange Software,
such as but not limited to failure to contract for Interchange Software services,
does not constitute unavailability.
Page 99 of 25
13
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Violation Severity Levels
R#
Violation Severity Levels
Lower VSL
R1.
High VSL
Severe VSL
NA
NA
The Balancing Authority
failed to use the Interchange
Software as the sole source
to calculate ATEC.
R1R2. Following the conclusion of
each month each Balancing
Authority’s absolute value of
PIIaccum for either the On‐
Peak period or Off‐Peak
period exceeded 150%, but
was less than or equal to
160% of the previous
calendar year’s Peak
Demandpeak demand or
peak generation for
generation‐only Balancing
Authorities.
Following the conclusion of
each month each Balancing
Authority’s absolute value of
PIIaccum for either the On‐
Peak period or Off‐Peak
period exceeded 160%, but
was less than or equal to
170% of the previous
calendar year’s Peak
Demandpeak demand or
peak generation for
generation‐only Balancing
Authorities.
Following the conclusion of
each month each Balancing
Authority’s absolute value of
PIIaccum for either the On‐
Peak period or Off‐Peak
period exceeded 170%, but
was less than or equal to
180% of the previous
calendar year’s Peak
Demandpeak demand or
peak generation for
generation‐only Balancing
Authorities.
Following the conclusion of
each month each Balancing
Authority’s absolute value of
PIIaccum for either the On‐
Peak period or Off‐Peak
period exceeded 180% of
the previous calendar year’s
Peak Demandpeak demand
or peak generation for
generation‐only Balancing
Authorities.
R2R3. The Balancing Authority did
not recalculate PIIhourly and
adjust the PIIaccum within
90 days of the discovery of
the error; but made the
required recalculations and
adjustments within 120
days.
The Balancing Authority did
not recalculate PIIhourly and
adjust the PIIaccum within
120 days of the discovery of
the error; but made the
required recalculations and
adjustments within 150
days.
The Balancing Authority did
not recalculate PIIhourly and
adjust the PIIaccum within
150 days of the discovery of
the error; but made the
required recalculations and
adjustments within 180
days.
The Balancing Authority did
not recalculate PIIhourly and
adjust PIIaccum within 180
days of the discovery of the
error.
R4.
The Balancing Authority
operated during a calendar
The Balancing Authority
operated during a calendar
The Balancing Authority
operated during a calendar
NA
Moderate VSL
The Balancing Authority
operated during a calendar
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quarter without ATEC in
service for more than an
accumulated 24 hours, but
less than or equal to 72
hours.
quarter without ATEC in
service for more than an
accumulated 72 hours, but
less than or equal to 120
hours.
quarter without ATEC in
service for more than an
accumulated 120 hours, but
less than or equal to 168
hours.
quarter without ATEC in
service for more than an
accumulated 168 hours.
R5.
N/A
N/A
N/A
The Balancing Authority is
not able to change its AGC
operating mode to
correspond to current
operating conditions.
R6.
The Balancing Authority
failed to upload hourly
Actual Net Interchange to
the Interchange Software no
later than 50 minutes after
each hour, but uploaded the
required data in less than or
equal to two hours.
The Balancing Authority
failed to upload hourly
Actual Net Interchange to
the Interchange Software no
later than 50 minutes after
each hour, but uploaded the
required data in less than or
equal to four hours.
The Balancing Authority
failed to upload hourly
Actual Net Interchange to
the Interchange Software no
later than 50 minutes after
each hour, but uploaded the
required data in less than or
equal to six hours.
The Balancing Authority
failed to upload hourly
Actual Net Interchange to
the Interchange Software no
later than 50 minutes after
each hour, but uploaded the
required data in more than
six hours.
R7.
NA
NA
NA
The Balancing Authority
making a month‐end
adjustment failed to input
that value as part of its Net
Actual Interchange.
R8.
NA
NA
NA
The Balancing Authority
making a month‐end
adjustment failed to add
that value to its
accumulated Primary
Inadvertent Interchange.
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D. Regional Variances
None.
E. Associated Documents
None.
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Version History
Version
1
1
1
1
1
1
1
2
2
Date
February 4, 2003
October 17, 2006
February 6, 2007
Action
Effective Date.
Created Standard from Procedure.
Changed the Standard Version from 0 to
1 in the Version History Table.
February 6, 2007
The upper limit bounds to the amount of
Automatic Time Error Correction term
was inadvertently omitted during the
Standard Translation. The bound was
added to the requirement R1.4.
The statement “The Time Monitor may
February 6, 2007
declare offsets in 0.001‐second
increments” was moved from TEoffset to
TDadj and offsets was corrected to
adjustments.
February 6, 2007
The reference to seconds was deleted
from the TE offset term.
The standard number BAL‐STD‐004‐1
June 19, 2007
was changed to BAL‐004‐WECC‐01 to be
consistent with the NERC Regional
Reliability Standard Numbering
Convention.
December 19, 2012 Adopted by NERC Board of Trustees.
A FERC Letter Order was issued on
October 16, 2013
October 16, 2013, approving BAL‐004‐
WECC‐02. This standard will become
enforceable on April 1, 2014.
Change Tracking
New
Errata
Errata
Errata
Errata
Errata
Errata
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BAL‐004‐WECC‐34 ─ Automatic Time Error Correction WECC‐0147 Att. BC ‐ Clean as ApprovedProposed
Version
3
Date
December 6, 2017
Action
Approved by the WECC Board of
Directors.
3
February 8, 2018
Adopted by the NERC Board of
Trustees.
Change Tracking
Five‐year review. The
project: 1) relocates the
Background section to
the preamble of the
Guidance section, 2)
adds On‐Peak and Off‐
Peak parameters in
Requirement R1/M1, 3)
addresses WECC
Interchange Tool
software successors
throughout, 4)
conforms the
document to current
drafting conventions
(R1/M1, R4/M4), and 5)
addresses non‐
substantive syntax and
template concerns.
R #
Time
Horizon
VRF
Violation Severity Levels
Lower VSL
Moderate VSL
High VSL
Severe VSL
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R3
Real‐Time
Operations
Medium
The Balancing
Authority operated
during a calendar
quarter without ATEC
in service for more
than an accumulated
24 hours, but less than
or equal to 72 hours.
The Balancing
Authority operated
during a calendar
quarter without ATEC
in service for more
than an accumulated
72 hours, but less than
or equal to 120 hours.
The Balancing
Authority operated
during a calendar
quarter without ATEC
in service for more
than an accumulated
120 hours, but less
than or equal to 168
hours
The Balancing
Authority operated
during a calendar
quarter without ATEC
in service for more
than an accumulated
168 hours.
R4
Operations Medium
Assessment
The Balancing
Authority did not
compute PIIhourly,
PIIaccum, and IATEC
within 50 minutes, but
made the required
calculations in less
than or equal to two
hours.
The Balancing
Authority did not
compute PIIhourly,
PIIaccum, and IATEC
within two hours, but
made the required
calculations in less
than or equal to four
hours.
The Balancing
Authority did not
compute PIIhourly,
PIIaccum, and IATEC
within four hours, but
made the required
calculations in less
than or equal to six
hours.
The Balancing
Authority did not
compute PIIhourly,
PIIaccum, and IATEC
within six hours.
R5
Real‐Time
Operations
Medium
N/A
N/A
N/A
The Balancing
Authority is not able
to change its AGC
operating mode
between Flat
Frequency (for
blackout restoration;
Flat Tie Line (for loss
of frequency
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R #
Time
Horizon
VRF
Violation Severity Levels
Lower VSL
Moderate VSL
High VSL
Severe VSL
telemetry); Tie Line
Bias; or Tie Line Bias
plus Time Error
control (used in ATEC
mode).
R6
Operations Medium
Assessment
N/A
N/A
N/A
When making
adjustments to hourly
Inadvertent
Interchange or DTE,
the Balancing
Authority did not
recalculate the PIIhourly
and the PIIaccum for the
On‐Peak and Off‐Peak
periods.
R7
Operations
Assessment
N/A
N/A
N/A
When making any
month‐end meter
reading adjustments
to Inadvertent
Interchange, the
Balancing Authority
did not make the
same adjustment to
the PIIaccum.
Medium
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R #
Time
Horizon
VRF
R8
Operations
Assessment
Medium
Violation Severity Levels
Lower VSL
Moderate VSL
High VSL
N/A
N/A
N/A
Severe VSL
The Balancing
Authority paid back
Inadvertent
Interchange using
bilateral and unilateral
payback rather than
using ATEC.
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Guidelines and Technical Basis
Background
In February 2003, the WECC Automatic Time Error Correction (ATEC) Procedure (Procedure)
became effective for all Balancing Authorities in the Western Interconnection. The original
intent of the Procedure was to minimize the number of Manual Time Error Corrections in the
Western Interconnection. ATEC provides the added benefit of a superior approach over NERC
Reliability Standard BAL‐ 004‐0 – Time Error Correction for assigning costs and providing for
the equitable payback of Inadvertent Interchange. In October 2006, the Procedure became a
WECC Criterion. In May 2009, FERC issued Order No.723 that approved Regional Reliability
Standard BAL‐004‐WECC‐1 ‐ Automatic Time Error Correction, as submitted by NERC. In
addition, the Commission directed WECC to develop several clarifying modifications to BAL‐
004‐WECC‐1 using the FERC‐approved Process for Developing and Approving WECC Standards.
The Effective Date of the BAL‐004‐WECC‐1 standard was July 1, 2009. BAL‐ 004‐WECC‐1
required Balancing Authorities within the Western Interconnection to maintain
Interconnection frequency within a predefined frequency profile and to ensure that Time
Error Corrections were effectively conducted in a manner that did not adversely affect the
reliability of the Interconnection. In September 2009, WECC received WECC
Standards/Regional Criterion Request Form (Request) WECC‐0068, which was a request for
modification of BAL‐004‐WECC‐1. In July 2010, the chair of the WECC Operating Committee
assigned the Request to the Performance Work Group (PWG) for development.
Requirement R1:
FERC Order issued approving BAL‐004‐
Premise: May 30, 2018
WECC‐3. Docket No. RD18‐2‐000. Effective
Each3
Date October 1, 2018.
4
March 13, 2024
WECC Board of Directors Approved
This project: 1) expands
the existing Background
section, 2) creates a
Standard‐specific
definition (Interchange
Software); 3) creates a
requirement to use the
Interchange Software;
4) addresses treatment
of Balancing Authorities
that do not have a full
year of operating data;
5) consolidates and
clarifies requirements;
and 6) updates the
document to NERC's
newest templates.
Standard Attachments
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Not used.
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G. Rationale
Nomenclature Update
To conform to NERC’s definitional approach, the legacy term Net Actual Interchange (NAI) was
replaced with Actual Net Interchange (NIA). Net Scheduled Interchange (NSI) was replaced
with Scheduled Net Interchange (NIS). The legacy terms and the updated terms are
synonymous.
Requirement R1:
The goal of Requirement R1 is to ensure a consistent ATEC calculation within the WI.
Because ATEC is an automatic process, allowing inconsistent calculation of ATEC will cause
imbalance in accumulations.
Requirement R2:
The goal of Requirement R2 is to limit the amount of PIIaccum that a Balancing Authority can
have at the end of each month.
To reach the goal, each Balancing Authority should ensure that the absolute value of its
PIIaccum for both the On‐ Peakon‐peak period and the Off‐Peakoff‐peak period each
individually does not exceed 150% of the previous year’s Peak Demand for load‐serving
Balancing Authorities, and 150% of the previous year’s peak generation for generation‐only
Balancing Authorities. The Balancing Authority is required to keep each PIIaccum period
within the limit. For example, the Balancing Authorities actions may include:
Identifying and correcting the source of any metering or accounting error(s) and
recalculating the hourly Primary Inadvertent Interchange (PIIhourly) and the PIIaccum
from the time of the error;
Validating the implementation of ATEC; or
Setting Lmax equal to L10.until the PIIaccum is below the limit in Requirement R1.
Justification:This approach is required because PIIaccum may grow from month‐end
adjustments and metering errors, even with the inclusion of IATEC in the ACE equation.
Goal: To limit the amount of PIIaccum that a Balancing Authority can have at the end of each
month.
Requirement R2:
Premise: Requirement R3:
The goal of Requirement R3 is to promote: 1) the timely correction of errors in the calculation
of PII and PIIaccum, and 2) the accurate, fair, and timely payback of accumulated PII balances.
When a Balancing Authority finds an error in the calculation of its PII, the Balancing Authority
needs time to correct the error and recalculate PII and PIIaccum.
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Justification: Hourly adjustments to hourly Inadvertent Interchange (II) require a recalculation
of the corresponding hourly PII value, the corresponding PIIaccum, and all subsequent
PIIaccum for every hour up to the current hour.
The drafting team selected 90 days as a reasonable amount of time to correct an error and
recalculate PII and PIIaccum, since recalculation of PII and PIIaccum is not a real‐time
operations reliability issue. As PII hourly is corrected, then PIIaccum should be recalculated.
Goal: ToRequirement R4:
The goal of Requirement R4 is to promote thefair and timely correction of errors in the
calculationpayback of PII and PIIaccum. balances by ensuring that ATEC remains in service
whenever possible.
Requirement R3:
Premise: When a Balancing Authority is not participating in ATEC, payback of PIIaccum is
delayed.
Justification: The limit of 24 hours per quarter discourages a Balancing Authority from
withdrawing ATEC participation, for example, for economic gain during selected hours. If the
limits were increased to 60 hours, a Balancing Authority could technically withdraw ATEC
participation for one hour from Monday to Friday.
Goal: To promote fair and timely payback of PIIaccum balances.
Requirement R4R5:
Premise: PIIhourly, PIIaccum, and IATEC should be determined before the next scheduling hour
begins.
Justification: To promote timely calculations 50 minutes was selected because it is before the
next hour ramp begins and permits timeA review of NERC Standards conducted by the Version
4 drafting team concluded that this Requirement is best located in a Standard focused on
Automatic Generator Control (AGC). However, until an AGC‐specific Standard is drafted, the
Requirement should not be retired.
The goal of Requirement R5 is to collectensure that AGC has the data and resolve interchange
metering values.
Goal: To promote the timely calculation of PIIhourly, PIIaccum, and IATEC.
Requirement R5:
Premise: The ACE equation, and hence the AGC mode, will contain any number of parameters
based on systemability to respond to varying operating conditions. Various AGC modes are
identified corresponding to those operating conditions, as well as the specific sets of
parameters included in the ACE equation.
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WECC‐0147 Att. BC ‐ Clean as
Justification: Changing to the proper operating mode, corresponding to current operating
conditions, affords proper movement of generating units in response to those conditions. The
addition of the ATEC term results in an additional AGC mode and a different set of parameters.
The inability to correctly calculate the ATEC term would dictate that AGC not be operated in
the ATEC mode.
Goal: To set the AGC mode and calculate ACE in a manner that corresponds to the system
operating conditions and to accommodate changes in those conditions.
Requirement R6:
Premise: Not used.
Hourly adjustments to hourly Inadvertent Interchange (II) require a recalculation of the
corresponding hourly PII value, the corresponding PIIaccum, and all subsequent PIIaccum for
every hour up to the current hour.
Justification: As PIIhourly is corrected, then PIIaccum should be recalculated.
Goal: To promote accurate, fair and timely payback of accumulated PII balances.
Requirement R7:
Premise: Month‐end meter‐reading adjustments are made, for example, when a Balancing
Authority performs monthly comparisons of recorded month‐end Net Actual Interchange (NIA)
values derived from hourly Actual Interchange Telemetered Values against month‐end Actual
Interchange Register Meter readings.
Justification: Month‐end adjustments to IIaccum are applied as 100% PIIaccum. 100% was chosen
for simplicity to bilaterally assign PIIaccum to both Balancing Authorities, since the effect of this
metering error on system frequency is not easily determined over the course of a month.
Goal: To provide a mechanism by which corresponding month‐end II adjustments can be
applied to PIIaccum, when such adjustments cannot be attributed to any one hour or series of
hours.
Not used.
Requirement R8:
Premise: ATEC includes automatic unilateral payback of Primary Inadvertent Interchange and
Secondary Inadvertent Interchange.
Justification: Additional unilateral and bilateral exchanges disturb the balance and distribution
between Primary Inadvertent Interchange and Secondary Inadvertent Interchange throughout
the Interconnection; thereby stranding Secondary Inadvertent Interchange.
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Goal: To not strand Secondary Inadvertent Interchange.
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Not used.
Version History
Version
1
1
1
1
1
1
1
2
2
Date
February 4, 2003
October 17, 2006
February 6, 2007
Action
Effective Date.
Created Standard from Procedure.
Changed the Standard Version from 0 to
1 in the Version History Table.
February 6, 2007
The upper limit bounds to the amount of
Automatic Time Error Correction term
was inadvertently omitted during the
Standard Translation. The bound was
added to the requirement R1.4.
The statement “The Time Monitor may
February 6, 2007
declare offsets in 0.001‐second
increments” was moved from TEoffset to
TDadj and offsets was corrected to
adjustments.
February 6, 2007
The reference to seconds was deleted
from the TE offset term.
The standard number BAL‐STD‐004‐1
June 19, 2007
was changed to BAL‐004‐WECC‐01 to be
consistent with the NERC Regional
Reliability Standard Numbering
Convention.
December 19, 2012 Adopted by NERC Board of Trustees.
A FERC Letter Order was issued on
October 16, 2013
October 16, 2013, approving BAL‐004‐
WECC‐02. This standard will become
enforceable on April 1, 2014.
Change Tracking
New
Errata
Errata
Errata
Errata
Errata
Errata
Page 2424 of
2513
BAL‐004‐WECC‐34 ─ Automatic Time Error Correction
ApprovedProposed
WECC‐0147 Att. BC ‐ Clean as
Version
3
Date
December 6, 2017
Action
Approved by the WECC Board of
Directors.
3
February 8, 2018
Adopted by the NERC Board of
Trustees.
3
May 30, 2018
Change Tracking
Five‐year review. The
project: 1) relocates the
Background section to
the preamble of the
Guidance section, 2)
adds On‐Peak and Off‐
Peak parameters in
Requirement R1/M1, 3)
addresses WECC
Interchange Tool
software successors
throughout, 4)
conforms the
document to current
drafting conventions
(R1/M1, R4/M4), and,
5) addresses non‐
substantive syntax and
template concerns.
FERC Order issued approving BAL‐004‐
WECC‐3. Docket No. RD18‐2‐000. Effective
Date October 1, 2018.
Page 2525 of
2513
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Unofficial Comment Form
Regional Reliability Standard
BAL-004-WECC-4
DO NOT use this form for submitting comments. Use the electronic form to submit comments on the
proposed modifications to Regional Reliability Standard, BAL-004-WECC-4 (Automatic Time Error
Correction). The electronic form must be submitted by 8 p.m. Eastern, Tuesday, May 28, 2024.
Documents and information about this project are available on the WECC’s Standards page. If you have
questions, contact Reliability Standards Analyst, Kimberlin Harris (via email) or at (404) 446-9794.
Background Information
Proposed Regional Reliability Standard BAL- 004-WECC-4 – Automatic Time Error Correction modifies the
current effective regional standard BAL-004-WECC-3 as follows:
1. Expanding the existing Background section
2. Creating a Standard-specific definition (Interchange Software)
3. Creating a requirement to use the Interchange Software
4. Addressing treatment of Balancing Authorities that do not have a full year of operating data
5. Consolidating and clarifying requirements
6. Updating the documents to NERC's newest templates
7. Adding a Standard-specific definition, applicable only to this RRS
8. Clarifying that when used, the term “ATEC” is as defined in the WECC Regional Definitions section
of the NERC Glossary of Terms Used in Reliability Standards (Glossary)
The WECC Board of Directors approved the proposed regional standard on March 13, 2024.
NERC Criteria for Developing or Modifying a Regional Reliability Standard
Each regional difference (i.e., Regional Reliability Standard or Variance) shall be: (1) is more stringent than
the continent-wide Reliability Standard, including a regional difference that addresses matters that the
continent-wide reliability standard does not; or (2) necessitated by a physical difference in the bulk power
system. Regional Reliability Standards and Variances shall provide for as much uniformity as possible with
Reliability Standards across the interconnected bulk power system of the North American continent.
Regional Reliability Standards and Variances, when approved by FERC and applicable authorities in Mexico
and Canada, shall be made part of the body of NERC Reliability Standards and shall be enforced upon all
applicable Bulk Power System owners, operators, and users within the applicable area, regardless of
membership in the region.
RELIABILITY | RESILIENCE | SECURITY
The approval process for a proposed Regional Reliability Standard or Variance, or the retirement of an
existing standard or Variance, requires NERC to publicly notice and request comment. Comments shall be
permitted only on the following criteria (technical aspects of the standard are vetted through the regional
standards development process):
Unfair or Closed Process – The Regional Reliability Standard was not developed in a fair and open process
that provided an opportunity for all interested parties to participate. Although a NERC-approved Regional
Reliability Standards development procedure shall be presumed to be fair and open, objections could be
raised regarding the implementation of the procedure.
Adverse Reliability or Commercial Impact on Other Interconnections – The Regional Reliability Standard
would have a significant adverse impact on reliability or commerce in other interconnections.
Deficient Standard – The Regional Reliability Standard fails to provide a level of reliability of the Bulk
Power System such that the Regional Reliability Standard would be likely to cause a serious and
substantial threat to public health, safety, welfare, or national security.
Adverse Impact on Competitive Markets within the Interconnection – The Regional Reliability Standard
would create a serious and substantial burden on competitive markets within the interconnection that is
not necessary for reliability.
Questions
1. Do you agree that the proposed Regional Reliability Standard was developed in a fair and open
process, using the associated Regional Reliability Standards Development Procedure?
Yes
No
Comments:
2. Does the proposed Regional Reliability Standard pose an adverse impact to reliability or commerce
in a neighboring region or interconnection?
Yes
No
Comments:
3. Does the proposed Regional Reliability Standard pose a serious and substantial threat to public
health, safety, welfare, or national security?
Yes
No
Comments:
Unofficial Comment Form
BAL-004-WECC-4 | April 10-May 28, 2024
2
4. Does the proposed Regional Reliability Standard pose a serious and substantial burden on
competitive markets within the interconnection that is not necessary for reliability?
Yes
No
Comments:
5. Does the proposed Regional Reliability Standard meet at least one of the following criteria?
•
The proposed Regional Reliability Standard has more specific criteria for the same
requirements covered in a continent-wide standard.
•
The proposed Regional Reliability Standard has requirements that are not included in the
corresponding continent-wide standard.
•
The proposed regional difference is necessitated by a physical difference in the Bulk Power
System.
Yes
No
Comments:
Unofficial Comment Form
BAL-004-WECC-4 | April 10-May 28, 2024
3
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Exhibit F
Standard Drafting Team Roster for Project WECC-0147
BAL-004-WECC-3
Attachment L
Drafting Team Roster
WECC-0147
BAL-004-WECC-4 ATEC
Drafting Team Roster
Below please find a biographical snapshot for the members of the WECC‐0147 BAL‐004‐WECC‐4,
Automatic Time Error Correction (ATEC) Five‐year Review Drafting Team.
Name
Qualifications
David Kirsch,
Presently employed by the Bonneville Power Administration (BPA) as an
Bonneville Power
electrical engineer in the Technical Operation Controls group. Mr.
Administration
Kirsch’s core work relates to Automatic Generation Control, Balancing
Authority management, and the accompanying NERC and WECC BAL
standard implementation and compliance. Mr. Kirsch has provided solid,
functional solutions to AGC issues in the Technical Operation Controls
area for the last 13 years. He has worked for BPA for 21 years and has
been an engineer in the utility industry for 32 years.
Experience and Education:
Member of the WECC‐0124 BAL‐004‐WECC‐3 Drafting Team in
2016.
Member of the WECC Performance Work Group Resources
Subcommittee since 2015. This work group discusses and analyzes
performance issues in the Western Interconnection, of which some
topics of discussion are Primary Inadvertent Interchange, time
error, and ATEC.
As one of BPA’s NERC BAL‐001, 002, 005 and BAL‐002‐WECC and
BAL‐004‐WECC SMEs, he ensures reliability compliance for BPA
by providing expert analysis, keeping current with industry trends,
and participating in standards development activities.
Coordinates across multiple technical groups to consolidate BPA’s
agency experience in Balancing Authority management and
Contingency Reserves.
Obtained electrical engineering degree from Portland State University.
155 North 400 West | Suite 200 | Salt Lake City, Utah 84103
www.wecc.org
Attachment L
Don Kovacs,
BC Hydro
Presently employed by British Colombia Hydro (BC) with responsibilities
for Automatic Generator Control (AGC) compliance with BAL standards.
With 25 years’ experience in the utility industry, Mr. Kovacs has
experience in Emergency Management System (EMS) programming
focusing on AGC and BA operations. Mr. Kovacs implemented Automatic
Time Error Correction (ATEC) for BC from its onset to present including
production of compliance evidence. Mr. Kovacs holds a Bachelor of
Science degree in electrical engineering and is a registered Professional
Engineer in British Columbia.
Kathy Downey,
Presently employed with PacifiCorp with over 15 years of experience
PacifiCorp
serving as PacifiCorp’s representative to WECC’s ISAS, MIC, and OC, plus
participation on multiple drafting teams. Ms. Downey has expertise in the
area of Interchange Scheduling, the Interchange Scheduling and
Accounting Sub‐Committee (ISAS), the Market Interface Committee
(MIC), the Operating Committee, and Federal Energy Regulatory
Commission (FERC) Order 764. Currently, she is serving as PacifiCorpʹs
representative on the Operating Committee and ISAS.
Kokou
Presently employed by the California Independent System Operator
Agbassekou,
(CAISO) 15 years of experience including Operations Compliance Analyst
California
and Emergency Response Coordinator, Control Room Operator‐in‐
Independent
training, Operations Engineer, Real‐Time Interchange Scheduler, System
System Operator
Operations Specialist, and currently Reliability Coordinator (RC) West
Western Interconnect Tool (WIT) Interconnection Administrator in charge
of Delta Time Error (DTE) to include daily monitoring, Primary
Inadvertent recording in the West, WIT Schedule Change. Mr.
Agbassekou is a member and attendee of multiple WECC and other
working groups such as ISAS, PWG, WITWG, ATFWG, USF, ECCWG.
Based on those roles, he is familiar with the primary inadvertent data, the
Delta Time Error calculation and Time Error Correction process in the
West using ATEC. In his current role in Operations Compliance, his team
is responsible for compliance on BAL‐004‐WECC‐3, INT‐006‐5, INT‐009‐3,
TOP‐003 and IRO‐010, among other standards, for both CAISO Balancing
Authority and RC West.
Rich Hydzik,
Rich Hydzik is a Senior Transmission Operations Engineer at Avista. He
Avista
has worked in System Operations since 2004 with responsibilities for
operational powerflow studies, coordination of regional contingency
2
Attachment L
reserve programs, system operating procedures, and organizational
compliance with various NERC BAL, INT, PRC, TOP, and VAR standards,
and system operator training. Prior to working in System Operations, he
was a system protection engineer for ten years on generation, distribution,
and transmission (69kV through 500kV) applications from design to field
commissioning. He worked for three years as a transmission system
planning engineer. Mr. Hydzik holds a Bachelor of Science degree with a
concentration in electrical engineering from Gonzaga University and is a
registered Professional Engineer in the state of Washington.
Sean Erickson,
Presently employed by the Western Area Power Administration (WAPA)
Western Area
as a Senior Power Operations Specialist.
Power
Administration
His qualifications include:
Two years of experience as a WECC Reliability Coordinator (2009–
2011);
Two years of experience as a WECC Reliability Coordination
Operations Engineer (2007–2009);
Four years of experience as an Operations Engineer (2011–2015);
Serving as the Transmission Alternate on the WECC Operating
Committee as well as the WECC Ballot Body representative for
both WECC and NERC;
Previous member of the WECC Performance Work Group during
the BAL‐001 field trial evaluations;
Previous member of the Path Operator Task Force (POTF) (after
September 8, 2011, NERC/FERC findings and mitigation regarding
path operations) and the POTF—Implementation Team for the
operational adoption of the POTF findings; and
Contributor to retiring TOP‐007‐WECC‐1a, System Operating
Limits.
Craig Figart
Avista
(Augmentee)
Presently employed by Avista, serving as manager of Avista’s Supervisory
Control and Data Acquisition (SCADA) systems. Mr. Figart did not seek
assignment to this team due to time constraints at his employment;
however, he actively participated in a supporting role to the team.
3
| File Type | application/pdf |
| Author | bryants |
| File Modified | 2025-03-11 |
| File Created | 2025-03-11 |