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  1. Define Balancing Authority
    The responsible entity that integrates resource plans ahead of time, maintains load-interchange-generation balance within a Balancing Authority Area, and supports Interconnection frequency in real time
  2. Define Interchange
    Energy transfers that cross Balancing Authorities
  3. What are the benefits of power systems being interconnected
    • Efficiency
    • Markets
    • Reliability
  4. A Transmission Operator (TO) is:
    The entity responsible for the reliability of its local transmission system, and that operates or directs the operations of the transmission facilities
  5. A Purchasing-Selling Entity(PSE) is:
    • The entity that purchases or sells, and takes title to, energy, capacity, and Interconnected Operations Services.
    • PSEs may be affiliated or unaffiliated merchants and may or may not own generating facilities
  6. A Transmission Service Provider is responsible for:
    Administering the transmission tariff and providing transmission services to Transmission Customers under applicable transmission service agreements
  7. Define O.A.T.T.
    • Open Access Transmission Tariff
    • Outlines business rules that will be followed by BCHydro when dealing with its customers
  8. Define NAESB
    • North American Energy Standards Board
    • An industry forum for the development and promotion of standards which will lead to a seamless marketplace for wholesale and retail natural gas and electricity
  9. Define Path
    A path is a transmission line, or combination of transmission lines with an adjacent Balancing Authority.
  10. Define Point of Receipt(POR)
    Place where energy is received by transmission system
  11. Define Point of Delivery(POD)
    Place where energy is dropped off by transmission system
  12. Define Internal Paths
    Transmission Path where transfer of energy is entirely within BCHA
  13. Define Wheelthrough Path
    • A Contractual Path where energy flows on various transmission facilities from one border of a Balancing Authority to the other
    • Zero effect on Net Schedule
  14. Define Total Transfer Capability(TTC)
    • The maximum amount of actual power that can be transferred over direct or parallel transmission elements
    • Market based for Transmission Capability
  15. What is Secondary Transmission
    • Customers that own Firm Transmission may reverse the POR/POD and receive Secondary Tx (Tx in the opposite direction)
    • Customer may also flip again and maintain rights to the original Firm TSR
    • Secondary Tx is of the lowest priority and first to be cut
    • only available in hourly increments
  16. Define Transmission Reliability Margin Unreleased(TRMu)
    • An amount of transmission(buffer zone) set aside to account for uncertainties in load forecasting and other errors
    • Prevents an OTC violation
    • Non-Firm Unreleased amount to marketers
    • Path 1(AESO) = 65 MW
    • Path 3(BPA) = 50 MW
  17. Define Transmission Reliability Margin(TRM)
    • An amount of transmission set aside between the Total Transfer Capability(TTC) Limit and the Available Transfer Capability(ATC) Firm Limit
    • TRM = TTC - Firm ATC Limit
    • TRM is a calculated value that is not enterable in MODS
  18. Define Scheduling Limit(SL)
    • The maximum amount of 'NET' Scheduled Interchange that can exist across a Path
    • SL = TTC – TRMu + CES
  19. Define Counterflow Energy Schedules(CES)
    Energy schedules flowing the opposite direction of the POR/POD direction
  20. Define Firm ATC (Available Transfer Capability)
    • Available firm capacity derived through system studies
    • System Normal less single largest contingency (N-1)
    • ATC Firm = TTC-TRM
  21. Define  ATC ( Available Transfer Capability )
    The amount of transfer capability remaining in the transmission network available over and above firm, committed uses.
  22. What transmission lines make up Path 1?Maximum TTC in each direction?
    • 5L94    Cranbrook - Langdon
    • 1L274    Natal - Pocaterra
    • 1L275    Natal - Coleman
    • BC-AB = 1200 MW
    • AB-BC = 1000 MW
  23. What transmission lines make up Path 3? Maximum TTC in each direction?
    • 5L51_52    Ingledow - Custer
    • 2L112      Nelway - Boundary
    • L71         Waneta - Boundary
    • BC-US = 3150 MW
    • US-BC = 2000 MW
  24. When referencing the transmission network system, appropriate terms are:
    • POR
    • POD
  25. When referencing flow of energy, appropriate terms are:
    • Source
    • Sink
  26. What is MODS
    • Market Operations Development System
    • Software developed by OATI for BCHydro with specific Business Practice Rules built in
  27. What is OASIS
    • Open Access Same-time Information System
    • Platform where all marketers receive transmission information at the same time
  28. What is ACE
    • Area Control Error
    • The instantaneous difference between a Balancing Authority’s net actual interchange and net scheduled interchange, taking into account the effects of Frequency Bias and correction for meter error.
  29. How does MODS and AREVA(EMS) communicate
    • Through the Enterprise Service Bus
    • -Data sent every 4 seconds
    • -120 minutes of saved data could transfer if there was an ESB failure
  30. Define   OTC
    • Operating Transfer Capability
    • The maximum Path rating for Reliability based Energy Capability
    • OTC=TTC
  31. What happens if the actual schedule exceeds the TTC limit in the OTC monitoring display?
    • An OTC violation timer will start and alarms will be received by the TC and GC
    • Actual flow must be reduced within OTC limits within the alloted timeframes for compliance
  32. What are the two types of Transmission service?Lengths of Terms?
    • Long Term Firm Point-to-Point
    • -minimum term of one year

    • Short Term Firm and Non-Firm Point-to-Point
    • -term of one hour to less than one year
  33. What increments is Transmission sold in
    • Hourly
    • Daily
    • Weekly
    • Monthly
  34. On what attributes are TSRs validated
    • Submission Time
    • Valid Path and POR/POD
    • MW requested
    • Bid Price
    • Service Increment
    • Start/Stop Time
    • Pre-confirm
  35. Define Redirect  (re:TSRs)
    • A request to change the POR/POD of a Firm TSR
    • The new TSR can be:
    • Firm Redirect(different path & cannot be flipped back)
    • Non-Firm Secondary Redirect(opposite path & can be flipped back to Firm)
  36. What is a Resale  (re:TSRs)
    A Transmission Customer may sell all or a portion of its scheduling rights to another Eligible Customer
  37. What is a Transfer (re:TSRs)
    A Transmission Customer that is Reselling elects to Transfer all of the existing rights and obligations of an existing TSR
  38. Define Non-Firm Sale
    An energy sale for which receipt or delivery may be interrupted for any reason or no reason
  39. How is OTC monitored?Are there inputs from MODs into AREVA for OTC Monitoring?
    • AREVA monitors OTC
    • Proper OTC is based on the minimum input from either of:
    • MODs(Effective TTC Entry)
    • TSA-PM(Transient Stability Analysis-Path Manager)(automatic AREVA generated #)
    • Manual Entry
  40. What is an eTag? What information is on it?
    • Electronic Documentation of the energy transaction
    • Info:
    • Tag ID
    • Source
    • Sink
    • Market & Physical Path
    • Transmission Contracts
    • MW Profiles
    • Parties to the Transaction
    • Loss Information
  41. What System are eTags submitted through
    OATI ETS (WebTag)
  42. eTags must be on _______________transmission service requests
    • And Active in OASIS
  43. What approaches can be used to specify eTags
    • OASIS ID Approach
    • Blanket Approach
    • Stacked Transmission Approach
  44. How can a customer account for losses associated with their transmission
    • Self-Supply losses(loss eTag must be submitted)
    • Purchase Loss Compensation from BCHydro
  45. What is a 'Normal' energy schedule
    Uninterruptible (Firm) energy that should not be curtailed under Normal operating conditions
  46. What is an Interruptible energy schedule
    Interruptible (Non-Firm) energy that may be interrupted for any reason or no reason
  47. What is a 'Capacity' energy schedule
    • Capacity energy is 'Energy on Demand' that could be delivered when called upon by the sinking B/A
    • Firm Transmission capacities are left unfilled to accomodate the eTag
  48. What is a 'Capacity for Recall' (C-RE) energy schedule
    • C-RE energy is 'reserves' that a source B/A has sold but wants to recall on
    • Can be recalled within 10 mins
    • These eTags must be approved 'in-hour' and require manual action
  49. What is a 'Dynamic' energy schedule
    • Dynamic energy schedules are essentially transmission capacities left unfilled from an energy perspective which are not resold as unused transmission
    • The energy profile may vary during the hour as per the sinking BA
    • Calculated after the hour as part of Net Actual Interchange(NAI) in order to not affect the ACE calculation
  50. What is Net Scheduled Interchange (NSI)
    The Net summation of all interchange schedules for a B/A
  51. What is Net Actual Interchange (NAI)
    • The algebraic sum of all metered interchange between all interconnections of B/As
    • -calculated after the hour
  52. True/Fasle: Curtailing a Capacity tag will improve the Scheduling Limit
    • False
    • Because transmission space is reserved but the energy flow is zero
    • The PSE must make an adjustment to the 'transmission profile' on the etag
  53. Define unscheduled flow
    The flow of energy that is not on the market path
  54. Describe 'downstream benefits'
    • Long term agreement for BCHA to receive 1200 MW from BPA for controlling waterflows on the Columbia River Basin
    • Mica, Keenleyside, Duncan Dams
  55. What types of eTags are there
    • Normal
    • Capacity
    • Capacity for Recall
    • Dynamic
    • Emergency
  56. Define Capacity Benefit Margin (CBM)
    • Space reserved to serve native load
    • * calculates as a zero
  57. Define Curtailment
    A reduction in the scheduled capacity or energy delivery of an Interchange Transaction.
  58. With respect to Curtailments, when do we curtail? How do we Curtail?
    • Curtail when energy schedules exceed the SL
    • Curtail when a transmission or generation component is unexpectantly OOS

    Curtail by placing Reliability Limits against Transmission

    MODS will use the Curtailment Manager to populate a cutlist(based on NERC priority codes) to releive -SL
  59. Define RAS
    • Remedial Action Scheme
    • Automatic protection to maintain system reliability
    • Such as changes in demand, generation, system configuration
  60. Define horizontal stacking of a TSR
    Combining TSRs of the same transmission type to cover multiple time periods
  61. Define vertical stacking of a TSR
    Combining TSRs of the same transmission type to facilitate a larger capacity tag
  62. When establishing TTC on a Path, which entity determines the TTC
    The most constraining B/A
  63. What conditions must be met before AESO can request an Emergency Energy Transfer from BCH
    Use all reserves and exhaust the marketplace
  64. When and how long are the generation ramps
    • Hour Schedules: xx:50 - XX:10  20 minutes
    • HalfHour Schedules: XX:25 - XX:35 10 minutes
  65. Who needs to know about a large Ramp (500 + MW)
    • The GC as normal
    • The TC as well to control voltages
  66. What percentage of Contingency Reserves(CR) are Spinning Reserves(SR)
  67. For a unit to be counted for Contingency Reserves, what conditions must be met
    Running and the loaded MW value that can be met in 10 minutes
  68. For a unit to be counted for Spinning Reserves, what conditions must be met
    Online frequency responsive unused generation capacity
  69. What is the L71 Scheduling rights?
    • Teck has up to 370 MW of firm export & import on the BC-US interties
    • Considered 8F. Not a NERC Priority code but will not get curtailed pro-rata with 7F
    • If L71 is OOS, Teck loses all rights to schedule
  70. If L71 is OOS, what do you do?
    • Manually run Curtailments on eTags with Aref's:
    • 74930022
    • 74930035
  71. Define Network Economy Transmission
    • Network economy transmission may be purchased for imports to serve native load
    • Only BCPS has a NITS contract and is eligible to purchase NE
    • Any unused NE is retracted at xx:40 and is not resold
  72. What is Network Economy Type 2
    • Network Economy Transmission that has failed an economic and utilization test
    • Curtailment priority of Non-Firm
  73. What happens with a mid-hour curtailment of greater than 75 MW
    • The AGC is suspended
    • Inform GC so he can monitor AGC
  74. What function does WIT perform
    • Summarizes all the APPROVED webtag transactions for a BA
    • Calculates NSI using the eTag infrastructure
    • All BAs in WECC use WIT so all NSIs to each other should match up
    • WIT and MODS are both eTag driven so their NSI numbers should always match up
  75. What are the Int. Scheduler's duties under a Level I Energy Emergency
    • Under direction from the GC:
    • Curtail Interruptible export schedules
    • -including all Fortis export schedules
    • Approve late Emergency eTags for import
  76. What are the Int. Scheduler's duties under a Level II Energy Emergency
    No action is required
  77. What are the Int. Scheduler's duties under a Level III Energy Emergency
    • Under direction from the GC:
    • Curtail Firm export schedules
    • -should be done pro-rata with shedding domestic load
  78. What is the General Wheeling Agreement(GWA)
    • Agreement between BCHA and Fortis to wheel electricity (from point of supply)  on a Firm basis over BCHydro transmission facilities to Fortis's load
    • There are 3 points of interconnection
  79. What is usually the first indication that there is a problem or a failure with OASIS
    A call from a customer that they cannot access OASIS
  80. What info is in Portfolio Management
    • Summary of TSR's and associated eTags
    • O - Original MW value
    • R - Remaining amount after Redirects and Resales
    • L - The Reliability Limit placed against TSR(if applicable)
    • E - Event ID : only appears if there was a RL
    • S - the Scheduled energy against the TSR
    • A - the remaining Available amount of energy that could still be scheduled
  81. On which displays can you find info on the NSI required by the AGC
    • MODS(Int. Summary/ RealTime Summary)
    • EMS(AGC Schedules)
    • WIT(Int. Summary Screen)
  82. What would an Int. Scheduler do if there was a MODS/ESB connectivity  failure
    • 1. Contact MODS Helpdesk right away
    • 2. For checkout, call AESO & BPA and ask them to apply curtailments and use their NSI # for AGC
    • 3. Connect the SHAW backup cable and reconfigure internet settings
    • 4. Ask the GC to run the 'Backup Scheduler'
  83. What are the High Load Hours (HLH)
    • HE 07:00 to 22:00   Mon-Sat
    • Sundays and STATs all day are  LowLoadHours (LLH)
  84. List NERC priority codes from lowest to highest
    • LIFO
    • 0NX - Next hour market
    • 1NS - NonFirm Secondary
    • 2NH - NonFirm Hourly
    • 6NN - Network Economy(Type 2)
    • 3ND - NonFirm Daily
    • 4NW - NonFirm Weekly
    • 5NM - NonFirm Monthly
    • PRO-RATA
    • 6NN - Network Economy (Type 1)
    • 7F - Conditional Firm(Conditional period)
    • PRO-RATA
    • 7F - Conditional Firm(NonConditional Period)
    • Teck -L71
    • Not Cut unless L71 OOS
    • 8F - Teck's Grandfathered Rights
  85. List BCHydros curtailment priority for eTags lowest to highest
    • -Interruptible/ Recallable
    • -Normal/ Uninterruptible
    • -Reserves/ Capacity
    • -Dynamic
  86. Describe the way MODS/EMS/PI/WIT are connected
    • -MODs is connected to AREVA(EMS) and provides info to AGC 
    • -AREVA  sends info to PI
    • -PI sends info to WIT
    • -PI and WIT do not directly communicate to MODs
  87. What time does Powerex submit the Dynamic adjustments
    Tag adjustments submitted at  xx:05
  88. Why is xx:00 a significant time for Tx scheduling
    Any Firm Tx that wasn't scheduled on is released for purchase(on OASIS) as Non-Firm Hourly Tx
  89. What is the SSW
    • Simultaneous Submission Window
    • Period of 00:00-00:05 where Short-Term Firm and Non-Firm TSRs may be submitted and receive the same time-stamp
  90. Describe Ancilliary Services
    • Transmission Customers must purchase Ancilliary Services as part of Transmission Service, including such things as:
    • Scheduling, Dispatch, System Control
    • Reactive Supply and Voltage Control
    • Frequency Response
    • Loss Compensation
  91. What are some validation rules for eTags
    • Submission Time
    • Source/ Sink
    • Market Path
    • Start/ Stop Time
    • Generation Profile
    • Energy Product Code
    • Transmission Assignment
    • CRR Requirement
  92. Curtailments of eTags are performed based on what two factors
    • Product Code
    • PSE defined cut priority
Card Set:
2013-10-15 17:14:32

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