Electric distribution system | % | Description |
---|---|---|
Portion of distribution system with SCADA due to SGIG/SGD program | 0% | |
Portion of distribution system with DA due to SGIG/SGD program | 0% |
DA devices installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Automated feeder switches | 0 | None | $0 |
Automated capacitors | 0 | $0 | |
Automated regulators | 0 | $0 | |
Feeder monitors | 0 | $0 | |
Remote fault indicators | 0 | $0 | |
Transformer monitors (line) | 0 | $0 | |
Smart relays | 0 | ||
Fault current limiter | 0 | $0 | |
Other devices | 0 | $0 |
SCADA and DA communications network | Cost |
---|---|
Communications equipment and SCADA | $0 |
Distribution management systems integration | Integrated | Description |
---|---|---|
AMI | No | |
Outage management system | No | |
Distributed energy resource interface | No | |
Other | No |
Distribution automation features / functionality | Function enabled | Description |
---|---|---|
Fault location, isolation and service restoration (FLISR) | No | |
Voltage optimization | No | |
Feeder peak load management | No | |
Microgrids | No | |
Other functions | No |
Electric transmission system | Portion | Description |
---|---|---|
Portion of transmission system covered by phasor measurement systems | 100.00% |
Phasor measurement systems | Quantity* | Description | Cost |
---|---|---|---|
PMUs | 393 | Within the $108M SGIG program scope. They may be standalone PMUs, upgraded relays, or digital fault recorders above 345kV. In Q1 2014, the PMUs deployed were DFR Type Magnetic Instrument USI Mod 2002. In Q3 2013, the PMUs deployed were SEL type 487e stand alone relays. In Q2 2013, the PMUs deployed were SEL type 487e stand alone relays . In Q1 2013, the PMUs deployed were GE type UR-N60 relays,SEL type 487e stand alone relays, and DFR type Magnetic Instrument USI Model 2002. In Q4 2012, the PMUs deployed were SEL type 487e stand alone PMUs, GE type UR-N60 relays, and DFR type Ametek. In Q3 2012, the PMUs deployed were SEL type 487e stand alone PMUs and DFRs type Ametek. In Q2 2012, the 11 PMUs deployed were SEL type 487e stand alone PMUs (8) and DFRs type Ametek (3). In Q1 2011, the 7 PMUs deployed were relays with PMU functional capability: type SEL-421; and digital fault recorders with PMU functionality: type Hathaway IDM models T3 and T5. The PMUs deployed in Q3 2011 were standalone PMUs: type SEL-487e. No EHV PMUs were deployed in Q4 2011. The 11 PMUs deployed in Q1 2012 were standalone PMUs: type SEL 487e. | $43,667,241 |
Phasor data concentrators | 57 | Within the $108M SGIG program scope. Concentrates and aligns PMU data. Deployed at reliability centers, control centers, and substations (with data streaming to other PDCs). In Q4 of 2013, the PDCs deployed were ePDCs. In Q1 2013, the PDCs deployed were ePDC and EPG Phasor Gateways. In Q4 2012, the PDCs deployed were openPDCs. In Q3 2012, the PDCs deployed were ePDCs (11). In Q2 2012, the PDCs deployed were ePDCs (18) and SEL 3306 (1). In Q1 of 2011, the PDCs deployed were type SEL-3306. In Q3 of 2011, The PDCs deployed were the ePDC. The WECC Reliability Centers deployed their PDCs in Q4 2011: type openPDC. PacifiCorp, BPA, and PG&E deployed 12 PDCs in Q1 of 2012: type openPDC (PAC) and ePDC (PG&E and BPA). | $5,171,725 |
Communications network | Within the $108M SGIG program scope. Includes the WAN connecting all parties up to and including the redundant edge routers at the utilities/ISO facilities -- both cost share partners as well as the additional 10 utilities/ISO. Does not include the field communications within the cost share partners (that investment is captured as part of the PMU deployment in the first 2 categories above). In Q1 of 2011, WISP is close to selection of its wide area network (WAN) provider, following an RFP process. The top 2 vendors are identified, with negotiations set to begin in May. | $10,369,655 |
Other transmission assets | Quantity* | Description | Cost |
---|---|---|---|
Dynamic Capability Rating System (DCRS) - Transmission Lines | 0 | $0 | |
Other transmission assets | $0 | ||
Other transmission assets | 0 | $0 | |
Other transmission assets | 0 | $0 |
Angle/frequency monitoring | Operational | Description | Cost |
---|---|---|---|
Angle/frequency monitoring | Yes | Within the $108M SGIG program scope. Includes the following applications: 1. Angle and Frequency Monitoring 2. Voltage and Voltage Stability Monitoring 3. Oscillation Energy and Mode Meter Monitoring 4. Reactive Reserves Monitoring 5. Alarm Management 6. Improved State Estimation 7. Remedial Action Scheme - control of reactive devices for California-Oregon Intertie 8. Remedial Action Scheme - control of primary and secondary reactive for wind generation 9. Steady-state model baselining, validation, and improvement 10. Dynamic model baselining, validation, and improvement 11. Power system restoration 12. Post-mortem analysis 13. Archival data mining 14. Island detection and restoration 15. Fault detection 16. Congestion Management 17. Dynamic capability rating systems | $40,263,134 |
Post-mortem analysis (including compliance monitoring) | Yes | ||
Voltage stability monitoring | Yes | ||
Thermal overload monitoring | Yes | ||
Improved state estimation | Yes | ||
Steady-state model benchmarking | Yes | ||
DG/IPP applications | No | ||
Power system restoration | Yes |
* In some circumstances, costs are incurred before devices are installed resulting in a reported cost where the quantity is zero.
* All dollar figures are the total cost, which is the sum of the federal investment and cost share of the recipient (the recipient cost share must be at least 50% of the total overall project cost).
** In some cases the number of entities reporting is greater than the total number of projects funded by the Recovery Act because some projects have multiple sub-projects that report data. View list of sub-projects.