Presentation on theme: "Kenneth Wilson WECC Staff"— Presentation transcript:
1Kenneth Wilson WECC Staff Slides:Branden 1-3Michelle 4- 15Richard 16-18Branden 19-28Richard 29-30Bulk Electric System (BES) Definition UpdateMay 14-15, 2013RS Meeting, Salt Lake City
2Overview “Core” BES Definition FERC Order BES Definition Processes Definitional Exclusion Reporting ProcessRules of Procedure Exception ProcessLocal Distribution ProcessDe-registration ProcessStaff Points of ContactFurther emphasize the difference between the core definition inclusions and exclusions and the Rules of Procedure exception process
4BES Definition – Base“… all Transmission Elements operated at 100 kV or higher and Real and Reactive Power resources connected at 100 kV or higher. This does not include facilities used in the local distribution of electric energy.”
5BES Definition – Definitional Inclusions and Exclusions The BES Definition provides specific criteria for “definitional” inclusions and exclusionsI1 – I5, E1 – E4These do not need to be submitted through the Rules of Procedure (RoP) Exception ProcessElement changes to the BES are reported to the Regions for review
6Definitional Inclusions I1 - Transformers with the primary terminal and at least one secondary terminal operated at 100 kV or higher unless excluded under Exclusion E1 or E3.I2 - Generating resource(s) with gross individual nameplate rating greater than 20 MVA or gross plant/facility aggregate nameplate rating greater than 75 MVA including the generator terminals through the high-side of the step-up transformer(s) connected at a voltage of 100 kV or above.I3 - Blackstart Resources identified in the Transmission Operator’s restoration plan.I1 – clarifies transformers; previous discussion of whether it was just one winding or both that had to be above 100 kVI2 – Generation consistent with SCRC. Also includes step-up transformers that connect the generator to at 100 kVI3 – Blackstart resources
7Definitional Inclusions (cont.) I4 - Dispersed power producing resources with aggregate capacity greater than 75 MVA (gross aggregate nameplate rating) utilizing a system designed primarily for aggregating capacity, connected at a common point at a voltage of 100 kV or above.I5 –Static or dynamic devices (excluding generators) dedicated to supplying or absorbing Reactive Power that are connected at 100 kV or higher, or through a dedicated transformer with a high-side voltage of 100 kV or higher, or through a transformer that is designated in Inclusion I1.I4 – meant to capture renewable resources, i.e. wind farmsI5 – reactive resources
8Definitional Exclusions E1 - Radial systems: A group of contiguous transmission Elements that emanates from a single point of connection of 100 kV or higher and:Only serves Load.or,b) Only includes generation resources, not identified in Inclusion I3, with an aggregate capacity less than or equal to 75 MVA (gross nameplate rating). or,c) Where the radial system serves Load and includes generation resources, not identified in Inclusion I3, with an aggregate capacity of non-retail generation less than or equal to 75 MVA (gross nameplate rating).Note – A normally open switching device between radial systems, as depicted on prints or one-line diagrams for example, does not affect this exclusion.Radials serving only load have always been excludedThere was discussion about what “serving only load” really meant – many radials have de minimus generation, such as roof-top solars that the SDT believed were not intended to negate the exclusion. Therefore, they allowed for up to 75 MVA of generationHistoric discussion of whether a N.O. switch meant a line was not radial. Argument that it adds reliability, and should not be penalized.
9Definitional Exclusions (cont.) E2 - A generating unit or multiple generating units on the customer’s side of the retail meter that serve all or part of the retail Load with electric energy if: (i) the net capacity provided to the BES does not exceed 75 MVA, and (ii) standby, back-up, and maintenance power services are provided to the generating unit or multiple generating units or to the retail Load by a Balancing Authority, or provided pursuant to a binding obligation with a Generator Owner or Generator Operator, or under terms approved by the applicable regulatory authority.Retail generation is excluded – this is consistent with the SCRC
10Definitional Exclusions (cont.) E3 - Local networks (LN): A group of contiguous transmission Elements operated at or above 100 kV but less than 300 kV that distribute power to Load rather than transfer bulk power across the interconnected system. LN’s emanate from multiple points of connection at 100 kV or higher to improve the level of service to retail customer Load and not to accommodate bulk power transfer across the interconnected system. The LN is characterized by all of the following:a) Limits on connected generation: The LN and its underlying Elements do not include generation resources identified in Inclusion I3 and do not have an aggregate capacity of non-retail generation greater than 75 MVA (gross nameplate rating) ;b) Power flows only into the LN and the LN does not transfer energy originating outside the LN for delivery through the LN; andc) Not part of a Flowgate or transfer path: The LN does not contain a monitored Facility of a permanent Flowgate in the Eastern Interconnection, a major transfer path within the Western Interconnection, or a comparable monitored Facility in the ERCOT or Quebec Interconnections, and is not a monitored Facility included in an Interconnection Reliability Operating Limit (IROL).E4 – Reactive Power devices owned and operated by the retail customer solely for its own use.Local Networks are meant to be low-impact systems; power flows in, not out or through. Also not part of a major transfer path.E4 is for retail reactive power.
12BES Definition - History Approved by NERC Board of Trustees on 1/19/12FERC proposed to approve definition and revisions to the Rules of Procedure in its 6/22/12 Notice of Proposed RulemakingFERC approval 12/20/12 (Order 773)FERC final approval 4/18/13 (Order 773-A)
13Effective Dates Definition effective July 1, 2013 Compliance for newly added facilities July 1, 2015
14FERC Order Changes Local Distribution E1 and E3 do not apply to generation tie lines (NERC will Modify Definition)100 kV minimum on local networks removed (NERC will Modify Definition)FERC can designate elements as part of the BES on its ownRegistered Entities must notify its Regional Entity of elements that changed BES status per application of the new BES definition (per section 501 of RoP)Discuss the need for FERC to address local distribution in the order
15Definitional Inclusion/Exclusions Reporting Process
16BES Definition Guidance Document Provides guidance on applicationRevisions related to FERC order and comments received expected in AprilNERC Informational webinar after release of documentWECC recommends that entities begin reviewing their systems for conformance to the new BES definition, but where there are grey areas they should wait until the revised Guidance Document to evaluate those elements
17Notification of Self-Determination Required by paragraph 317 of FERC Order 773 and Section 501 of the NERC Rules of ProcedureNotification through “NERC BES Notification and Exception System” available July 1, 2013Submission by asset owner (GO/TO)More detailed info at 5/30 webinarP110 of the rehearing order talked about notification in “Good Faith”Good Faith is proper application of the definitionWill discuss further on 5/30 webinar
18Definitional Exclusion/Inclusion Reporting Process Data RequiredList of element(s) that are included/exclude per the definitionSystem MapIf required two years of flow data into networkWECC registration staff notifies entities of concurrence/non-concurrence of elementsNeed to mention that until the entity receives the results of our review they are assuming the risk that WECC may not agree with their conclusions.WECC anticipates on processing notifications on a first come, first served basis with the exception of upcoming audits – entities with audits may take precedence over othersEven though WECC may accept notification in March, we have no obligation to turn them around, but will work hard to turn around as quickly as possible
20Rules of Procedure Exception Process “ Elements may be included or excluded on a case-by-case basis through the Rules of Procedure exception process.”Exceptions requests will only be considered after Compliance staff determines the network/element is in the BES per the definitionAfter an entity has gone through the definitional inclusions and exclusions they can go through the Rules of Procedure Exception Process
21Ongoing RoP Exception Process Activities (a) Exclusion ExceptionAn entity may request and obtain Approval from NERC for an Exclusion Exception on the grounds that the Element(s) for which the Exception Request is filed is included within the BES based on application of the BES Definition but is not necessary for the Reliable Operation of the interconnected bulk-power transmission system as evidenced by Required Information provided pursuant to Detailed Information to Support an Exception Request (Section III.B of the Exception Request Form).
22Ongoing RoP Exception Process Activities (b) Inclusion ExceptionAn entity may request and obtain Approval from NERC for an Inclusion Exception on the grounds that the Element(s) for which the Exception Request is filed is not included within the BES based on application of the BES Definition but is necessary for the Reliable Operation of the interconnected bulk-power transmission system as evidenced by Required Information provided pursuant to Detailed Information to Support an Exception Request (Section III.B of the Exception Request Form).
23Federal Power Act Section 215 of the FPA states: ‘‘(4) The term ‘reliable operation’ means operating the elements of the bulk-power system within equipment and electric system thermal, voltage, and stability limits so that instability, uncontrolled separation, or cascading failures of such system will not occur as a result of a sudden disturbance, including a cybersecurity incident, or unanticipated failure of system elements.”
24RoP Exception Process Entity submits request Regional Entity accepts or rejects (submitting entity can appeal)If accepted, Regional Entity performs substantive reviewRegional Entity recommends approval or disapproval (if recommending disapproval, forward request to Technical Review Panel (TRP))NERC makes final decision (submitting entity can appeal)
26Initial ScreeningComplete screening either 60 days after initial receipt or 30 days after receiving owner’s response, whichever is laterAssign unique identifierReview for whether:Submitting entity was eligibleRequired information was submittedSend notice to submitterRegional Entity Can accept or reject in whole or in part
27Substantive Review Complete within six months of acceptance Regional Entity may request additional infoRegional Entity develops recommendationIf recommendation is for disapproval, engage a TRPNot involved in original reviewRegional Entity not bound by recommendation of TRPSubmitting entity or owner can supplement the request at any time
28Approval or Disapproval Complete 90 days after receiving RecommendationNERC develops team of three subject matter experts to review requestNERC may request interviews with Regional Entity, submitting entity, or ownerNERC President makes final decision
29Ongoing RoP Exception Process Activities Registered entity training/outreach to comeSubmittal processAcceptable file formatsStart datesGuidance on detailed information for Section III
30Outreach and other important dates May 24, 9am MT, Application of Definition webinarMay 30, 2pm MT, Notification of Self Determination webinarJune 4-5, Compliance Users GroupJune 11, 2pm MT, Exception Process for TO/GOs webinarJune 13, 2pm MT, Exception Process for TOP/BA/RC/PC webinarJune 20, 3pm MT, Next Steps and Q&A webinarJune 17-28, NERC webinars on BES Notification and Exception SystemJuly 1, 2013 BES Definition Effective Date
31Detailed Information to Support an Exception Request A one-line breaker diagram identifying the Element(s) for which the exception is requested must be supplied with every request. The diagram(s) supplied should also show the Protection Systems at the interface points associated with the Elements for which the exception is being requested.The Detailed Information to Support an Exception Request provides a list of questions for Transmission Elements and Generation Resources that should be addressed (see
32Detailed Information to Support an Exception Request Entities are required to supply the data and studies needed to support their submittal. Studies should:Be based on an Interconnection-wide base case that is suitably complete and detailed to reflect the electrical characteristics and system topology;Clearly document all assumptions used;Address key performance measures of BES reliability through steady-state power flow; and, transient stability analysis as necessary to support the entity’s request, consistent with the methodologies described in the Transmission Planning (TPL) standard and commensurate with the scope of the request.Supporting statements for the submitted position from other entities are encouraged.
34Local Distribution Submit requests directly to FERC FERC will use the 7 Factor Test (Order 888) to determine applicabilityOnce FERC issues a favorable decision the Local Distribution network is no longer part of the BES.
36De-registration Process Current ProcessSubmit letter to identifying reason for request (i.e. definitional exclusion, exception request etc.)Future ProcessNotification through “NERC BES Notification and Exception System” available July 1, 2013
37WECC Staff ContactsApplication of “Core” Definition and Definitional Exclusion Submittals, De-registration ProcessRichard Mabry:Phone:Rules of Procedure Exception ProcessKenneth Wilson:Phone:
38Questions? Kenneth Wilson – firstname.lastname@example.org Richard Mabry –