GridView Presentation to PSPC · 2018-01-19 · AS dG Max Economic Dispatch (OPF) ... Integration...

© ABB Group August 23, 2011 | Slide 1

GridView Presentation to PSPCAugust 25, 2011Jin Zhu Jin Zhu (919) 807(919) [email protected]@us.abb.com

GrGridView IntroductionidView Introduction


GridView™ is a Least-Cost, Security-Constrained Unit Commitment and Economic Dispatch Program

Dispatches generators to minimize the production cost given unit characteristics (cost, as well as physical) and chronological load

performs a dispatch such that transmission line limits are not violated under normal, as well as contingency conditions

Calculates spot prices at buses and shadow prices on lines as a part of the process

Introduction to GridView


GridViewTM

Optimal Power Flow

Market Simulation

Generation• size• bids• availability

Transmission• power flow• constraints• operating rules• Tariffs• availability

Load• hourly variation• location• growth

Historical Information

Scenarios

Values of A.S.

ProbabilityDistribution Curves

Flows / Congestion

LMP & CRR Value

Goal: Combine Power Systems Analysis withGoal: Combine Power Systems Analysis withAccurate Economic ModelsAccurate Economic Models

Dispatch & Revenues

GridView Program


UNCONSTRAINED MARKET CLEARING PRICE

0

5

10

15

20

25

30

35

500 600 700 800 900 1000 1100

MW

$/M

Wh

GENERATION BIDPRICES

MARKET CLARING PRICE

TOTAL LOAD

Unconstrained Case


s.t.

G G Min

MaxMin DDD

(Energy Balance)

(Generation Limits)

(Dispatch-able Demands)

(Constraints)

TwSAcDcGcMin tASdg

qASSA Re

MaxMin TLDGT GSFT

(Ancillary Services )

MaxGSAG

Economic Dispatch (OPF)

)( ossesLLDG


Transfer capability from A to C?- Supply Curve Model- Transportation Model- LMP Model

75

075

[100, 0.1]

[100, 0.1]

AA

BB

CC

LowCost

HighCost

150

40190

50 MW

AA

BB

CC

LowCost

HighCost

Limiting line

Unconstrained Constrained

10 $/MWh

25 MW

10 $/MWh

10 $/MWh

20 $/MWh

1

2 2

1

Cost to serve the next MW of load at a specific location, using the lowest

production cost of all generation, while observing all transmission limits.

What is Locational Marginal Pricing (LMP)?


Generator Marginal Costs & BidsLoad Forecasts, Wind ForecastsTransmission ConstraintsSecurity Constrained Unit Commitment (SCUC)Security Constrained Economic Dispatch (SCED)Ancillary Services BidsTransmission and Generator OutagesNetwork Topology and ImpedancesTransmission LossesExternal Transactions / ExchangesSpecial Protection Scheme, Reliability Must Run, etc.

What is behind LMP?


Linear Programming Based program, including Thermal unit dispatching, Hydro scheduling, Pumped Storage Scheduling, Wind Model, Energy Storage, Dispatchable demand (PHEV), and Demand response, etc.

Security Constrained Unit Commitment (SCUC) and Economic Dispatch (SCED)

Co-optimization of Energy and Ancillary Services

Detailed and Flexible Transmission (Transmission Outages, PAR / HVDC model)

Detailed and Flexible Generator Modeling (Steam/CC/GT/Nuk/Wind/HY/PS/Geo/Storage)

Database Management Tool for tracking changes and scenario management

Hydro Thermal Optimization

Marginal Losses including Losses in DC Links and Distributed Reference Buses

Chronological Simulation from 1-day to Multi-years

Monte Carlo simulations for Risks and Reliability Analysis

Strategic bidding model

Ease-of-Use: Debug tool, Data Sanity Checking, Automatic Post Processing, and Standard Reports and Plots, including curves, GIS contour maps, etc.

GridView Features


Integration with PSS/E and PSLF Power Flow Case

• Import from RAW file and EPC file.

• Identify the differences between database and RAW / EPC files.

• Update database with the new power flow case by areas by data field.

• Export power flow case for any given hours.


Flexible Contingency Definition

• Apply to Commitment only, Dispatch only, both, or none.

• Default rating, denoted “GV”, will be based branch rate A, B, or C, defined in GridView Simulation Parameters


Contingency AnalysisDefine the branch Groups for contingency events

Menu: Import/Export Branch Group Definition

Define Branch Group as monitored elements

Use Import/Export only

Use screening rule to reduce the number of contingency constraints

Enable “Screening Contingency Constraints”

Set ODF tolerance accordingly

Adjust LODF tolerance to balance run-time with complete coverage

The screening applied to N-1 and N-x contingencies

Branch Branch Branch Branch Branch Branch Branch BranchContingencyID ContingencyName FromBusKV ToBusKV LineType FromBusID FromBusName ToBusID ToBusName CKT Rating

1 X16T89T1 69 138 0 38320 16TH ST 38310 16TH ST 1 NA1 X16T89T1 BRANCHGROUP BranchGr1 1 NA NA NA NA NA NA


Nomograms

LcZbYaX ...


Definition of Nomograms


Conditional Constraint ModelConditional constraint model allows user to adjust operation constraints during the simulation based on system conditions.

Represented as IF condition A, THEN consequence B.

Typical applications:When certain pattern of commitment statuses of a group of generator is satisfied, a interface transfer limit must be reduced. (If 2 out of 3 units are committed, limit of interface “J-PJME” must be reduced to 80%.)

When load reached to certain level, RMR units must be committed to produce.

CC Name If_Then Equation ID Element Type Element Attribute Element Name Coefficient

CCNYISO1 IF E1 GENERATOR COMMITMENT STATUS BRGN2CT1_1 1

CCNYISO1 IF E1 GENERATOR COMMITMENT STATUS HUDSON 2_1 1

CCNYISO1 IF E1 GENERATOR COMMITMENT STATUS LINDNCT1_1 1

CCNYISO1 IF E1 RIGHT HAND SIDE = N/A 2

CCNYISO1 THEN N/A INTERFACE MAX LIMIT J - PJME 0

CCNYISO1 THEN N/A INTERFACE MIN LIMIT J - PJME 0.8


Temporal DataUnit characteristics, such as, heatrate, capacity, must-run, performance factor, etc., can be changed through time.Change interface / nomogram limits and penalty cost through timeChange branch Rate A/B/C, PAR MW/Angle Limits, etc.Adjust Area/Region Reserve Requirements, Fuel Price, etc.Remove / enforce constraints for a period of time

Name Type Attribute Date Hour ValueASTORI10 GENERATOR MINCAP 5/1/9999 1 0ASTORI10 GENERATOR MINCAP 10/1/9999 1 0ASTORI10 GENERATOR MINFUELINPUT 5/1/9999 1 0ASTORI10 GENERATOR MINFUELINPUT 10/1/9999 1 0ASTORI10 GENERATOR INCCAP2 5/1/9999 1 19.6ASTORI10 GENERATOR INCCAP2 10/1/9999 1 28.6ASTORI10 GENERATOR INCHR2 5/1/9999 1 14.362ASTORI10 GENERATOR INCHR2 10/1/9999 1 14.012


Multiple Load Distribution

• Input load distribution through importing PSS/E and PSLF files.• Import / Export load distribution through .csv files.• Program will automatically switch the load distribution profiles based on

Month and Time-Of-Use (TOU).


Generation DistributionA generator is normally assigned to a single bus.

Some steam unit and combined cycle units can have multiple buses with distribution factors.

Distributed generators and demand response programs can be modeled as generators with load distribution.

All generators can be distributed to multiple buses or to areas.

Unit Name Type Element Name RatioCombine Cycle BUS 213 0.3Combine Cycle BUS 212 0.3Combine Cycle BUS 211 0.4

DemandResponse AREA NYCITY 1


Start-up Cost Model ImprovementStart-up cost may vary from a maximum cold-start value to intermediate value to a much smaller hot-start value depending on how long the thermal unit is turned off.

During shut-down period of a thermal unit, GridView updates actual start-up cost based on the following formula


Thermal Unit Ramping Up/Down Model• Enforced thermal unit ramping up/down in commitment / dispatch


Security constrained Unit Commitment and Economic Dispatch

Ideal Dispatch and Physical Disaptch

G-1 reserve during dispatch

Ramping Up / Down Model, Ramping penalty model

Distributed Generation

Strategic Bidding Model (Bid Pattern, Hourly Bid Curve)

Fuel Switching Logic

Quick Start Commitment Logic

Operational Limits, Nomogram, Conditional Constraints

Maintenance Model and Partial Derating Model

Multi-State Transition Rate Model, Temperature derating

Temporal Data Structures (Heatrate Performance Factor, Heatrate, etc.)

Thermal Unit Model


Concentrating Solar Power (CSP) with Thermal StorageGiven hourly solar power inputs

Serve load to maximize the storage benefits

Price sensitive re-dispatch

Run overnight to save startup cost ?

Compressed Air Energy Storage (CAES)Pumping high-pressure air into underground cavern

Generating as combust compressed air with natural gas

GT generation is subjected to the availability of compressed air

Pumping if low load and LMP; Generating if high load and LMP

Price sensitive re-dispatch

Energy Storage Model


Load SheddingSeparated prices for area-level load and bus-level load

Demand Side Management (DSM)Bid curves for DSM

At specific buses or areas

Demand Resource (DR)Modeled as hourly resources (e.g. shifting energy from peak to off-peak)

Modeled as pumped storage unit with price-driven logic, which optimizes load shifting based on price curve

Dispatchable Demand Model


Ease-of-Use – A market simulation program should enable the user to manage databases efficiently and understand the results easily. Key ease-of-use features in GridView are:

Intuitive design interfaces for easy of use.“Point-and-Click” approach for using the programData management Tools:

GUI, MS Excel, and MS AccessTracking changes and scenario managementDatabase comparison Data Sanity Checking

Visual representation of resultsConnectivity Viewer Linked with Data EditorDebug tool help user understand LMP and flowAutomatic Post Processing

Key Features of GridView


Transmission Economic Assessment Methodology (TEAM) Report


GridView Plot

Plot multiple variables for one unit in separate charts.

Plot one variable for multiple units in a same chart

Duration Curve

Chronological Curve


Representative Contour Map of LMP


Energy Velocity GridMap


Customized ReportingUse Python Program to create Customized Reports

Call API in Python to access GridView Inputs and OutputsWrite hourly information or summary into XLS filesPlot charts

Automatic Post-Processing

• Record the output post-processing into a script file. • Run the recorded post-processing to generate different reports.• Check “Enable” automatic post-processing will run the simulation and

then run the script file for the outputs.© ABB Group August 23, 2011 | Slide 29

Multiple Case Result Summary• Results will be exported to

Excel spreadsheet.

• For each variable, results from different cases will be presented in columns in a single worksheet.

Total Congestion Cost (M$) Type case 1 case 2 case 3 case 4 case 5 case 6Constraint 1 Contingency 113.51 113.67 79.51 81.05 83.08 86.05 Constraint 2 Contingency 44.24 44.22 42.09 42.02 39.37 39.39 Constraint 3 Branch 35.98 35.98 36.29 36.32 35.41 35.39 Constraint 4 Interface 35.26 35.04 31.11 28.43 28.62 31.24 Constraint 5 Branch 24.83 24.79 24.70 24.56 24.12 24.24 Constraint 6 Contingency 20.34 20.28 20.38 20.39 21.35 21.51 Constraint 7 Contingency 19.47 19.49 22.26 22.26 23.18 23.20 Constraint 8 Interface 17.50 17.93 17.59 17.73 14.90 14.97 Constraint 9 Contingency 17.40 17.46 5.43 5.62 4.35 4.91

Constraint 10 Nomogram 15.04 15.11 20.37 20.30 18.04 17.97 Constraint 11 Branch 11.73 11.65 11.15 11.16 11.32 10.93 Constraint 12 Interface 10.81 10.63 10.11 10.14 10.53 10.58 Constraint 13 Interface 10.13 10.25 9.79 9.77 8.85 8.73

Total Congestion Cost (M$) Type case 1 case 2 case 3 case 4 case 5 case 6Constraint 1 Contingency 113.51 113.67 79.51 81.05 83.08 86.05 Constraint 2 Contingency 44.24 44.22 42.09 42.02 39.37 39.39 Constraint 3 Branch 35.98 35.98 36.29 36.32 35.41 35.39 Constraint 4 Interface 35.26 35.04 31.11 28.43 28.62 31.24 Constraint 5 Branch 24.83 24.79 24.70 24.56 24.12 24.24 Constraint 6 Contingency 20.34 20.28 20.38 20.39 21.35 21.51 Constraint 7 Contingency 19.47 19.49 22.26 22.26 23.18 23.20 Constraint 8 Interface 17.50 17.93 17.59 17.73 14.90 14.97 Constraint 9 Contingency 17.40 17.46 5.43 5.62 4.35 4.91

Constraint 10 Nomogram 15.04 15.11 20.37 20.30 18.04 17.97 Constraint 11 Branch 11.73 11.65 11.15 11.16 11.32 10.93 Constraint 12 Interface 10.81 10.63 10.11 10.14 10.53 10.58 Constraint 13 Interface 10.13 10.25 9.79 9.77 8.85 8.73

Total Generation Cost (M$) Type case 1 case 2 case 3 case 4 case 5 case 6Zone A Area 363.84 363.14 379.59 378.58 390.29 392.82 Zone B Area 41.32 41.33 41.28 41.28 41.26 41.27 Zone C Area 695.52 697.24 554.89 560.11 566.54 574.09 Zone D Area 23.37 23.62 29.44 29.49 29.26 29.17 Zone E Area 6.58 6.70 7.28 7.33 6.93 7.11 Zone F Area 1,154.48 1,153.51 1,168.71 1,168.05 1,170.07 1,168.42 Zone G Area 278.34 278.24 280.85 280.96 283.67 284.14 Zone H Area 161.99 161.99 161.99 161.99 161.99 161.99 Zone I Area 0.01 0.01 0.01 0.01 0.01 0.01 Zone J Area 1,393.33 1,390.54 1,444.56 1,443.22 1,479.86 1,474.13 Zone K Area 430.66 430.73 431.87 431.92 434.18 434.25

Total Generation (GWh) Type case 1 case 2 case 3 case 4 case 5 case 6Zone A Area 22,408 22,398 22,712 22,692 22,922 22,969 Zone B Area 4,688 4,688 4,687 4,687 4,687 4,687 Zone C Area 32,499 32,529 27,634 27,722 27,865 27,987 Zone D Area 12,456 12,461 12,562 12,563 12,559 12,558 Zone E Area 2,959 2,961 2,971 2,972 2,965 2,968 Zone F Area 24,462 24,448 24,737 24,726 24,765 24,738 Zone G Area 4,521 4,520 4,568 4,571 4,612 4,613 Zone H Area 17,110 17,110 17,110 17,110 17,110 17,110 Zone I Area 6 6 6 6 6 6 Zone J Area 22,843 22,809 23,694 23,671 24,271 24,193 Zone K Area 7,290 7,291 7,310 7,311 7,351 7,350



Connectivity Viewer


Simulation in Batch Mode

• Program can run a list of cases in a batch mode.

• If you have multiple CPUs in your machine, you could run two GridView at the same time, or run two batch files at the same time.

• If the automatic post processing is enabled, program will generate all the reports based on the script file.


Congestion Analysis and Flow Calculation

• Congestion analysis identifies the limiting constraints and their contributions to the LMP congestion components.

• Flow analysis calculates contribution flow from all generation, load, phase shifter and HVDC.


Congestion Analysis

PG&E_VLY PG&E_VLY PG&E_BAY PG&E_BAY SANDIEGO SANDIEGO SOCALIF SOCALIF Constraint Name Type Shadow Price ($/MWh) GSF LMP_Cong GSF LMP_Cong GSF LMP_Cong GSF LMP_Cong37520_37546_2 Branch -0.77536 -1.50E-02 0.01 -1.24E-03 0.00 -1.10E-03 0.00 -1.26E-03 0.0030280_30330_1 Branch -52.3453 1.31E-16 (0.00) -3.55E-16 0.00 -2.68E-17 0.00 -2.94E-17 0.0030330_30335_1 Branch -57.244 -1.06E-02 0.61 -4.97E-03 0.28 -6.33E-04 0.04 -7.58E-04 0.0437567_37548_1 Branch 1.66753 0 0.00 0 0.00 0 0.00 0 0.0014003_26123_1 Branch -3.68431 -2.57E-02 0.09 -2.47E-02 0.09 7.40E-03 (0.03) -2.55E-02 0.0945087_31468_1 Branch -2.62164 -4.59E-03 0.01 -3.54E-03 0.01 -2.11E-03 0.01 -2.23E-03 0.0124086_26105_1 Branch 5.219464 7.53E-02 0.39 7.33E-02 0.38 3.40E-02 0.18 4.37E-02 0.2314000_14004_1 Branch -142.366 -2.70E-03 0.38 -2.18E-03 0.31 -1.73E-02 2.47 -1.08E-02 1.5450784_50822_2 Branch 0.320449 -1.98E-02 (0.01) -1.96E-02 (0.01) -2.15E-02 (0.01) -2.13E-02 (0.01)11014_11017_1 Branch -5.98032 2.29E-03 (0.01) 2.47E-03 (0.01) -1.67E-03 0.01 -1.93E-04 0.0047126_47009_1 Branch 0.014614 -1.13E-05 (0.00) -8.49E-06 (0.00) -3.71E-05 (0.00) -3.34E-05 (0.00)64017_64018_1 Branch 1.514464 5.04E-03 0.01 8.64E-03 0.01 4.22E-04 0.00 1.36E-03 0.0064025_64023_1 Branch -6.76187 -2.29E-02 0.16 -1.48E-02 0.10 -4.74E-03 0.03 -5.88E-03 0.0464053_64048_1 Branch 0.139427 3.56E-03 0.00 3.08E-03 0.00 -2.01E-03 (0.00) -1.63E-03 (0.00)64094_64096_1 Branch -8.71215 1.11E-04 (0.00) 1.86E-04 (0.00) -1.99E-03 0.02 -2.46E-03 0.0224728_24730_1 Branch 2.762739 -5.62E-05 (0.00) -2.03E-05 (0.00) -7.52E-04 (0.00) -2.61E-04 (0.00)30560_30525_1 Branch 72.29074 -5.59E-03 (0.40) 8.48E-02 6.13 2.00E-03 0.14 2.34E-03 0.17SOUTHWEST OF FOUR CORNERSInterface -2.36475 -3.71E-02 0.09 -0.0331231 0.08 -8.62E-02 0.20 -8.38E-02 0.20TOT 1A Interface -25.8887 -2.22E-02 0.57 -2.32E-02 0.60 -3.94E-03 0.10 -7.32E-03 0.19TOT 2A Interface -16.3785 -0.0239383 0.39 -2.12E-02 0.35 -6.31E-02 1.03 -5.65E-02 0.93TOT 2C Interface -4.76928 -5.64E-03 0.03 -3.51E-03 0.02 -3.21E-02 0.15 -3.19E-02 0.15Z7-Path 45 Interface -0.5438 -0.0172016 0.01 -0.0172016 0.01 -0.0172016 0.01 -0.0172016 0.01Z6-COI Interface -2.83821 -0.3391598 0.96 -0.3569841 1.01 -0.2342644 0.66 -0.2499277 0.71Z8-Crystal - H Allen230 kV PSInterface -2.19E-02 6.72E-03 (0.00) 5.95E-03 (0.00) 1.55E-02 (0.00) 1.59E-02 (0.00)WYOMING TO UTAH Interface -0.73993 2.58E-03 (0.00) 4.23E-03 (0.00) -1.40E-02 0.01 -1.19E-02 0.01Eldor Mohav_24042_24086_1Contingency -12.7145 -3.83E-02 0.49 -3.70E-02 0.47 -3.70E-03 0.05 -3.70E-02 0.47PDCI Nomogram -0.17842 0 0.00 0 0.00 0 0.00 0 0.00Canada to NW 2 Nomogram -2.07374 -0.1004266 0.21 -0.1004266 0.21 -0.1004266 0.21 -0.1004266 0.21

3.99 10.04 5.29 5.01Congestion Price


Database Management ToolReview Scenario / Changes

Data changes arranged by Table Names and Change Category

Delete tables or records in the change file

Modify values of the records, as needed

Export changes into excel file


Database ManagementApply Scenarios to Other Cases

Select Scenarios to be applied to selected cases

The scenario order can be adjusted


Data Sanity Checking• All GridView simulation required data, including transmission lines, generators, load areas, regions, transmission constraints, etc., will be verified.

• Warning and error message will be printed to a report.



Emission Model – A market simulation program to calculate emission amounts and emission costs (no limits on emission types). Three emission model options are available in GridView.

Simple adders

Calculated emission adders based on emission rates (lb/MWh or lb/MMbtu) and emission trading prices (changed by month, daily, or hourly)

Fuel based emission rate, Emission rate curve

Iteratively adjust emission trading prices to reduce emission to meet the targets. The marginal emission rates are calculated.


Bidding Strategy Capabilities – A market simulation program to allow generator to bid other than cost curve. Key bidding strategy capabilities of GridView are:

Empirical Bidding Logic

Bidding is the function of residual supply index, TOU, unhedged load percentage, Season, and its cost

Coefficients may be changed

Unit specific bidding strategyBy sectionBy hour, by day, by month, by TOU

Hourly Bidding Adder Curve




Co-optimization of Energy Market and Ancillary Service (AS) Markets – GridView simultaneously clear energy bids and AS bids to minimize the cost to serve loads and meet the AS requirements and transmission constraints. It can calculate hourly AS marginal prices for each market.

AS bids are composites of type, amount, and bidding price. AS bids and requirements can be imported/exported. AS types defined in GridView are:

Regulation DownRegulation UpSpinning Reservenon-Spinning ReserveReplacement Reserve



Ancillary Service ModelAncillary Service (AS) Bids

Unit’s Bid Amount and Price for each AS marketAS quality order (high to low): RUP/RDN, SR, NSR, RRBid price for high quality AS is higher than that low quality AS

RR < NSR < SR < RUP/RDN (not required)AS Requirements

AS requirements by Area, Region, and/or System AS requirements by type

Cascading RulesHigh quality AS can replace low quality ASThe clearing price for high quality AS is not lower than that of low quality AS

Marginal economic AS bid always sets AS Marginal Price with opportunity cost of providing energy




Monte Carlo Simulation – A market simulation program should able capture volatility by taking system uncertainties into account. Key probabilistic simulation features in GridView are:

Monte Carlo simulation for outages of generators and transmission lines with multi-state transition model

Monte Carlo simulation for uncertainty of load forecast, fuel price, and their correlation

Wind forecast uncertainty modelThermal unit capacity temperature derationStatistical information such as mean, min, max, standard deviation,

and confidence intervalsReliability indices such as LOLE, EENS.



Monte Carlo Simulation Improvement

State 0200MW

State 1100MW

State 20MW

10

2121

01

1202

State 0 State 1 State 2

State 0 0 (0,1) (0,2)

State 1 (1,0) 0 (1,2)

State 2 (2,0) (2,1) 0

Multiple States Transition Rate Model

Default as two-state model with FOR and duration

Applicable to generator outages and transmission outages

Up to 7 states


Monte Carlo Simulation ImprovementIEEE RTS Case

Load shape and ForecastMTTF and MTTRCapacity and locationGenerator Maintenance

GridView Can run Monte Carlo with transmission Constraints and detailed network dataGeneration forced outages

Multi-State transition rate modelTransmission forced outages

Multi-State interface limit Line forced outages

Model the uncertainty for loadProbability distribution function Uncertainty pattern

Thermal generation temperature deration model


Monte Carlo Simulation Improvement

Comparison with Analytical Approach

LOLE by DayAnalytical: 1.36886 days/yr

GridView: 1.3740 days/yr

LOLE by HourAnalytical: 9.394 hrs/yr

GridView: 9.389 hrs/yr

Comparison with Commercial Software

Step# CAP IN OUT PROB CUMULATIVE443 2850 555 0.010953 0.095531288444 2849 556 3.45E-06 0.084578061445 2848 557 4.95E-05 0.084574608446 2847 558 2.47E-05 0.08452509447 2846 559 0.000334 0.084500358448 2845 560 5.02E-05 0.084166192449 2844 561 3.61E-05 0.084116027450 2843 562 6.28E-05 0.084079953451 2842 563 9.85E-08 0.084017183452 2841 564 2.95E-05 0.084017085453 2840 565 2.75E-05 0.08398759454 2839 566 4.18E-05 0.0839601455 2838 567 0.002562 0.083918293456 2837 568 4.98E-06 0.081355876457 2836 569 0.000149 0.081350893458 2835 570 0.000288 0.081201684459 2834 571 1.37E-05 0.08091331460 2833 572 9.29E-05 0.080899651461 2832 573 1.87E-06 0.080806801462 2831 574 3.1E-06 0.080804935463 2830 575 0.004868 0.080801837464 2829 576 0.00068 0.075933852465 2828 577 1.33E-05 0.075253504466 2827 578 8.81E-06 0.075240213467 2826 579 0.000193 0.075231402468 2825 580 2.37E-06 0.075038359469 2824 581 0.000295 0.075035985470 2823 582 2.97E-05 0.074740891471 2822 583 3.2E-05 0.074711186472 2821 584 1.03E-05 0.074679154473 2820 585 4.43E-06 0.074668876474 2819 586 4.47E-06 0.074664443475 2818 587 0.000737 0.074659976476 2817 588 6.97E-05 0.073922749477 2816 589 2.55E-05 0.073853082478 2815 590 5.42E-05 0.073827607479 2814 591 4.18E-05 0.073773448



Monte Carlo SimulationSettings

1. Random seed2. Transmission Rating3. N-x limits4. Correlations of

uncertainties5. Unit Derating6. Load uncertainty7. Interface limit

transition rate model


Economic Benefit Calculation

Wind / Renewable Integration Study

Market Simulation

Energy and Ancillary Services Co-Optimization

LMP Forecasting, CRR Valuation

Risk Assessment

Transmission and Generation Forced Outages

LOLE and EUE Calculations

Environmental Study

RGGI Impacts

Hydro Thermal Co-Optimization

Integrated with Power Flow Study

GridView Applications


2006 DOE Congestion Study for West

CAISO Sunrise and C3ETP Economic Assessment

SPP LOLE study

Nevada Power & Sierra Pacific Wind Study

Regional Greenhouse Gas Initiative (RGGI) Impact Study

NYISO Congestion Analysis and Resource Integration Study (CARIS)

New York State Transmission Assessment and Reliability Study (STARS)

Congestion Revenue Right (CRR) Study in CAISO and ERCOT

Analysis of PacifiCorp Transmission Options

NREL 80% Renewable Energy Study for EI/WECC/ERCOT in 2050

SPP Minimum Bulk Production Cost Project

GridView Project Highlights


Production Simulation and Transmission Analysis

NYISO CARIS Process

http://www.nyiso.com/public/webdocs/services/planning/caris_process_flowcharts/Visio_CARIS__Process_maps.pdf

NYISO CARIS Load PaymentLoad LBMP Payment m$

Area 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018

West 677 833 843 882 903 950 981 1,030 1,068 1,123

Genessee 436 548 555 580 587 622 647 683 712 744

Central 723 913 930 971 1,002 1,052 1,089 1,148 1,192 1,251

North 304 386 396 412 424 444 459 480 498 520

Mohawk Valley 329 424 433 453 466 489 506 531 551 566

Capital 531 684 700 739 762 800 832 883 926 982

Hudson Valley 528 673 697 731 752 791 825 870 914 954

Millwood 133 169 175 184 191 200 208 220 231 242

Dunwoodie 322 407 420 438 449 467 485 508 533 555

NYCity 2,868 3,648 3,774 4,001 4,160 4,442 4,704 5,024 5,308 5,480

Long Island 1,174 1,496 1,531 1,591 1,610 1,671 1,732 1,824 1,905 1,962

NYISO Total 8,025 10,182 10,454 10,983 11,307 11,928 12,468 13,199 13,839 14,379

IESO 5,646 6,435 6,452 6,763 6,914 7,824 8,175 8,357 8,640 9,192

IESO Total 5,646 6,435 6,452 6,763 6,914 7,824 8,175 8,357 8,640 9,192

PJM Total 26,072 31,012 31,249 32,508 33,416 34,498 34,716 36,039 37,034 39,226

TE-Pump 0 0 0 0 0 0 0 0 0 0

HQ Total 0 0 0 0 0 0 0 0 0 0

ISO-NE Total 6,381 8,279 8,398 8,836 8,950 9,328 9,513 9,787 10,108 10,785

Total 46,124 55,908 56,553 59,090 60,587 63,578 64,872 67,383 69,621 73,582

http://www.nyiso.com/public/webdocs/services/planning/Caris_Report_Final/CARIS_Final_Report_1-19-10.pdf


LOLE Study - STARS

http://www.nyiso.com/public/webdocs/services/planning/stars/Phase_1_Final_Report_1_13_2010.pdf


LOLE and EUE Calculations


Jinxiang (Jin) ZhuSenior Principal Consultant, ABB Inc.

940 Main Campus Drive, Suite 300Raleigh, NC 27606

Email: [email protected]: (919) 807-8246Fax: (919) 807-5060

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