System Resource is providing Regulation to the CAISO it is directly responsive to AGC. There are different types of System Resources: 1) Dynamic System Resource: A System Resource that is capable of submitting a Dynamic Schedule, including a Dynamic Resource-Specific System Resource. 2) Non-Dynamic System Resource: A System Resource that is not capable of submitting a Dynamic Schedule, which may be a Non-Dynamic Resource-Specific System Resource. 3) Dynamic Resource-Specific System Resource: A Dynamic System Resource that is physically connected to an actual generation resource outside the CAISO Balancing Authority Area. 4) Non-Dynamic Resource –Specific System Resource: A Non-Dynamic System Resource that is physically connected to an actual generation resource outside the CAISO Balancing Authority Area. Products & Services This subsection describes the types of products and services that are traded in the CAISO Markets. The BPM for Market Instruments describes these in greater detail. Energy SCs can supply Energy into the CAISO markets from the following resources: Generating Units System Units – associated with Metered Subsystems Physical Scheduling Plants – group of tightly coupled Generating Units Participating Loads (modeled as a PSHU) System Resources – located outside the CAISO Balancing Authority Area SCs can purchase Energy from the CAISO markets, via: Loads within the CAISO Balancing Authority Area Exports from the CAISO Balancing Authority Area
8 Expanded North of Path 15 All Generators residing North of Path 15 NW1, NW2, SR5, SR2, SMUD, TID, Sutter Active 9 North of Path 26 All Generators residing North of Path 26 None Active 10 Expanded North of Path 26 All Generators residing North of Path 26 NW1, NW2, SR5, SR2, SMUD, TID, Sutter Active All AS Regions shown in Exhibit 4-1 are “active”. However, this does not necessarily mean that a minimum (or maximum) procurement limit is enforced for each of these AS Sub-Regions for a given hour. The term “active” here indicates that the AS Sub-Region is defined in the CAISO Tariff, and is included in the daily determination of applicable Regional AS limits. However, an AS Sub-Region may be “active” but also have a zero MW minimum procurement limit and a 9,999 MW maximum procurement limit, which effectively renders the AS Sub-Region as unconstrained. AS requirements, procurement, and pricing are expressed by AS Region. The minimum and/or maximum procurement constraints are each determined individually and serve as separate constraints on the procurement of resources. A purchase of AS capacity in a specific Location on the grid may contribute to meet the requirements of several AS Regions simultaneously. As conditions evolve, the CAISO may need to establish additional AS Regions to manage AS procurement limits for sub-AS Regions. These conditions may include: A pocket of Generation or Load for which more localized limits are needed to ensure sufficient capacity procurement under certain system conditions A System Resource at a Scheduling Point from which CAISO foresees a need to limit the AS procurement, under certain system conditions CAISO follows the AS Region change process described in the next section, as power system conditions warrant.
pseudo-tie generator is located. Transmission constraints: branch, corridor, nomogram (base case and contingency analysis) 5000 750 In the scheduling run, the market optimization enforces transmission constraints up to a point where the cost of enforcement (the “shadow price” of the constraint) reaches the parameter value, at which point the constraint is relaxed. Transmission Ownership Right (TOR) self schedule 5900, 5900 750, -30 A TOR Self-Schedule will be honored in the market scheduling in preference to enforcing transmission constraints. Existing Transmission Contract (ETC) self schedule 5100 to 5900, 5100 to 5900 750, -30 An ETC Self-Schedule will be honored in the market scheduling in preference to enforcing transmission constraints. The typical value is set at $5500, but different values from $5100 to $5900 are possible if the instructions to the ISO establish differential priorities among ETC rights. For some ETC rights the ISO may use values below the stated scheduling run range if that is required for consistency with the instructions provided to the ISO by the PTO. Converted Right (CVR) self schedule 5500, 5500 750, -30 A CVR Self-Schedule is assigned the same priority as the typical value for ETC Self-Schedules. Ancillary Service Region Regulation-up and Regulation-down Minimum Requirements 2500 250 In the event of bid insufficiency, AS minimum requirements will be met in preference to serving generic demand, but not at the cost of overloading transmission into AS regions. Ancillary Service Region Spin Minimum Requirements 2250 250 Spinning reserve minimum requirement is enforced with priority lower than regulation up minimum requirement in scheduling run. Ancillary Service Region Non-Spin Minimum Requirements 2000 250 Non-spin reserve minimum requirement is enforced with priority lower than spin minimum requirement in scheduling run. Ancillary Service Region Maximum Limit on Upward Services 1500 250 In the event of multiple AS regional requirements having bid insufficiency, it is undesirable to have multiple constraints produce AS prices equaling multiples of the AS bid cap. An alternative way to enforce sub-regional AS requirements is to enforce a maximum AS requirement on other AS regions, thereby reducing the AS prices in the other regions without causing excessive AS prices in the sub-region with bid insufficiency.
allowing sub-regional relaxation of the maximum requirement. AS market bid cap as pricing run to reflect the otherwise system-wide shortage. Self-scheduled exports not using identified non-RA supply resource 1200 750 Scheduling run penalty price reflects relatively low priority in protection as compared to other demand categories. Energy bid cap as pricing run parameter to reflect energy supply shortage. Final IFM Supply Schedule -3000 -30 Scheduling run penalty price is much higher in magnitude than supply generic self-schedule but lower than ETCs. Energy bid floor is the pricing parameter for all energy supply self-schedules. Regulatory Must-Run and Must Take supply curtailment -1125 -30 Scheduling run penalty price reflects the higher priority of regulatory must-run and must-take supply received over generic self-schedules for supply resources. Energy bid floor is the pricing parameter for all energy supply self-schedules. Price-taker supply bids -825 -30 Scheduling run penalty price for generic supply self-schedules is 10% higher in priority than Economic Bids at the bid cap. Energy bid floor is the pricing parameter for all energy supply self-schedules. Qualified Load Following self-provision Up or Down -8500 0 Scheduling run penalty price reflects the highest priority among all categories of AS self-provision. AS bid floor is used as the pricing parameter for any type of AS Day ahead conditionally qualified Reg Up or Down Award -7750 0 Scheduling run penalty price is higher than the penalty price for energy balance constraint to reflect higher in priority over energy. AS bid floor is pricing parameter for any type of AS self-provision. Day ahead conditionally qualified Spin Award -7700 0 Scheduling run penalty price is lower than the one for Reg-up. AS bid floor is pricing parameter for any type of AS Day ahead conditionally qualified Non-spin Award -7650 0 Scheduling run penalty price is lower than the one for Spin. AS bid floor is pricing parameter for any type of AS Conditionally qualified Reg Up or Down Real Time (RTPD only) -400 0 Scheduling run penalty price allows the conversion of AS self-schedules to Energy to prevent LMP of local area from rising so high as to trigger transmission constraint relaxation. AS bid floor is pricing