Interchange

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

Energy transfers that cross Balancing Authorities

• Efficiency
• Markets
• Reliability

The entity responsible for the reliability of its local transmission system, and that operates or directs the operations of the transmission facilities

• 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

Administering the transmission tariff and providing transmission services to Transmission Customers under applicable transmission service agreements

• Open Access Transmission Tariff
• Outlines business rules that will be followed by BCHydro when dealing with its customers

• 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

A path is a transmission line, or combination of transmission lines with an adjacent Balancing Authority.

Place where energy is received by transmission system

Place where energy is dropped off by transmission system

Transmission Path where transfer of energy is entirely within BCHA

• 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

• The maximum amount of actual power that can be transferred over direct or parallel transmission elements
• Market based for Transmission Capability

• 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

• 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

• 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

• The maximum amount of 'NET' Scheduled Interchange that can exist across a Path
• SL = TTC – TRMu + CES

Energy schedules flowing the opposite direction of the POR/POD direction

• Available firm capacity derived through system studies
• System Normal less single largest contingency (N-1)
• ATC Firm = TTC-TRM

The amount of transfer capability remaining in the transmission network available over and above firm, committed uses.

• 5L94    Cranbrook - Langdon
• 1L274    Natal - Pocaterra
• 1L275    Natal - Coleman
• BC-AB = 1200 MW
• AB-BC = 1000 MW

• 5L51_52    Ingledow - Custer
• 2L112      Nelway - Boundary
• L71         Waneta - Boundary
• BC-US = 3150 MW
• US-BC = 2000 MW

• POR
• POD

• Source
• Sink

• Market Operations Development System
• Software developed by OATI for BCHydro with specific Business Practice Rules built in

• Open Access Same-time Information System
• Platform where all marketers receive transmission information at the same time

• 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.

• Through the Enterprise Service Bus
• -Data sent every 4 seconds
• -120 minutes of saved data could transfer if there was an ESB failure

• Operating Transfer Capability
• The maximum Path rating for Reliability based Energy Capability
• OTC=TTC

• 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

• 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

• Hourly
• Daily
• Weekly
• Monthly

• Submission Time
• Valid Path and POR/POD
• MW requested
• Bid Price
• Service Increment
• Start/Stop Time
• Pre-confirm

• 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)

A Transmission Customer may sell all or a portion of its scheduling rights to another Eligible Customer

A Transmission Customer that is Reselling elects to Transfer all of the existing rights and obligations of an existing TSR

An energy sale for which receipt or delivery may be interrupted for any reason or no reason

• 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

• Electronic Documentation of the energy transaction
• Info:
• Tag ID
• Source
• Sink
• Market & Physical Path
• Transmission Contracts
• MW Profiles
• Parties to the Transaction
• Loss Information

OATI ETS (WebTag)

• CONFIRMED
• And Active in OASIS

• OASIS ID Approach
• Blanket Approach
• Stacked Transmission Approach

• Self-Supply losses(loss eTag must be submitted)
• Purchase Loss Compensation from BCHydro

Uninterruptible (Firm) energy that should not be curtailed under Normal operating conditions

Interruptible (Non-Firm) energy that may be interrupted for any reason or no reason

• 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

• 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

• 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

The Net summation of all interchange schedules for a B/A

• The algebraic sum of all metered interchange between all interconnections of B/As
• -calculated after the hour

• 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

The flow of energy that is not on the market path

• Long term agreement for BCHA to receive 1200 MW from BPA for controlling waterflows on the Columbia River Basin
• Mica, Keenleyside, Duncan Dams

• Normal
• Capacity
• Capacity for Recall
• Dynamic
• Emergency

• Space reserved to serve native load
• * calculates as a zero

A reduction in the scheduled capacity or energy delivery of an Interchange Transaction.

• 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

• Remedial Action Scheme
• Automatic protection to maintain system reliability
• Such as changes in demand, generation, system configuration

Combining TSRs of the same transmission type to cover multiple time periods

Combining TSRs of the same transmission type to facilitate a larger capacity tag

The most constraining B/A

Use all reserves and exhaust the marketplace

• Hour Schedules: xx:50 - XX:10  20 minutes
• HalfHour Schedules: XX:25 - XX:35 10 minutes

• The GC as normal
• The TC as well to control voltages

50%

Running and the loaded MW value that can be met in 10 minutes

Online frequency responsive unused generation capacity

• 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

• Manually run Curtailments on eTags with Aref's:
• 74930022
• 74930035

• 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

• Network Economy Transmission that has failed an economic and utilization test
• Curtailment priority of Non-Firm

• The AGC is suspended
• Inform GC so he can monitor AGC

• 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

• Under direction from the GC:
• Curtail Interruptible export schedules
• -including all Fortis export schedules
• Approve late Emergency eTags for import

No action is required

• Under direction from the GC:
• Curtail Firm export schedules
• -should be done pro-rata with shedding domestic load

• 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

A call from a customer that they cannot access OASIS

• 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

• MODS(Int. Summary/ RealTime Summary)
• EMS(AGC Schedules)
• WIT(Int. Summary Screen)

• 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'

• HE 07:00 to 22:00   Mon-Sat
• Sundays and STATs all day are  LowLoadHours (LLH)

• 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

• -Interruptible/ Recallable
• -Normal/ Uninterruptible
• -Reserves/ Capacity
• -Dynamic

• -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

Tag adjustments submitted at  xx:05

Any Firm Tx that wasn't scheduled on is released for purchase(on OASIS) as Non-Firm Hourly Tx

• 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

• 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

• Submission Time
• Source/ Sink
• Market Path
• Start/ Stop Time
• Generation Profile
• Energy Product Code
• Transmission Assignment
• CRR Requirement

• Product Code
• PSE defined cut priority