hmtf update tas nov 3-4, 2015 kevin harris, columbiagrid teppc\hydro modeling work group - chair
TRANSCRIPT
HMTF UpdateTAS Nov 3-4, 2015
Kevin Harris, ColumbiaGridTEPPC\Hydro Modeling Work Group - Chair
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Outline
• Background• Change in Hydro Operations on Columbia
River 2011+• Understanding PLF and developing K Factor• Hydro Dispatch Against Load – Wind• Summary of Findings
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Background
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Objective of Current Hydro Modeling Review
• Review the modeling of Core Columbia River projects:– Determine if existing modeling represents current
operations?• Make recommendations to correct any operational issues
• Develop tools/method to determine appropriate Hydro modeling parameters/coefficients for in GridView
• Test Load – Wind for BPA
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The Core Columbia• The Core Columbia River is used to
evaluate Hydro modeling in GridView
• The Core Columbia River represents 45% of Western US Hydro generation (2001-12)
• Upper Columbia:– Coulee- Priest Rapids
• Lower Columbia– McNary-Bonneville
• Think of the Snake River as the dividing point between Northern and Southern System
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Example Historic Operations• Example operation for January 2010 through 2013
Per unit of generation the operating range of
Upper Columbia is greater than the Lower
Columbia
Load Used:= 100% of BPA
+ 100% of MidC + 6% of CAISO
Aggregated and some individual projects Hydro
generation are proportional to load
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Change in Hydro Operations on Columbia River 2011+
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Operational Change Starting in 2011• Starting in 2011 the annual average
daily operating range decrease by 2,224 MW (38%)
• Any forecast run should reflect this reduction in operational flexibility
Average Weekday Operating Range (MW)2005-10 2011-13 Diff %Diff
Apr-Jul 5,537 1,918 -3,619 -65%Balance of Yr 6,087 4,560 -1,527 -25%Annual 5,904 3,679 -2,224 -38%
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Operational Change Starting in 2011
Note the polynomial for 2011, 2012, and 2013 for operational
Min and Max rating over-lap
Date PointsSpring Run-Off: 122/yrBalance of year: 243/yr
Just received hourly 2014 dataIt’s operation overlays on 2011-13
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Understanding PLF and Developing K Factor
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Proportional Load Following (PLF)• How PLF works
– The reference frame for PLF is the average monthly load and Hydro generation– Hourly Hydro generation is equal to the hourly percent change in load, from
average load, multiplied by K Factor and applied to average monthly Hydro generation
– Min and Max rating is enforced on Calc Hydro generation– K=0 results in a flat monthly shape equal to the average monthly Hydro generation
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K Factor - Hourly Shape (PLF)
• Positive K Factor result in Hydro generation proportional to load– K Factor 0> and < 1, results in a contraction of the daily operating range
in Hydro generation relative to the load shape– K Factor > 1, results in expanding the daily operating range in Hydro
generation relative to the load shape• Negative K Factor result in
Hydro generation inversely proportional to load
Note: In the example daily average is equal to monthly
average
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Calculating K Factor
• The reference frame for PLF is the average monthly load and Hydro generation
• K Factor:= Slope of– Y= Hydro Gen(Hr i)/Avg Mo Hydro Gen– X:= Load(Hr i)/Avg Mo Load– Example K:= 2.4111
• You only need two data points to calc a slope: Weekday min and max
• Consider multi hour avg for weekday min & max
The avg WKD min/max do not set operational min/max rating
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If Slope is all we need:= Delta(Y Axis)/Delta(X Axis)• Delta(Y Axis) and Delta(X Axis) can be calculated independently • K Factor can be split into two components:
– Hydro K’ [Delta(Y Axis)]: Is tailored to the desired average weekday operating range– Load K’ [Delta(X Axis)]: Is based on the load Hydro is to be dispatched to
• Formula:
• K can be tailed to dispatch to a forecasted load shape• Feedback loop: Spreadsheet Calculate - resulting hourly Hydro generation
can be compared to actual Hydro generation without simulation run
𝑲 (𝑺𝒍𝒐𝒑𝒆)=
𝑯𝒚𝒅𝒓𝒐𝑮𝒆𝒏(𝒂𝒗𝒈𝒅𝒂𝒊𝒍𝒚 𝒎𝒂𝒙)𝑯𝒚𝒅𝒓𝒐𝑮𝒆𝒏(𝒂𝒗𝒈)
−𝑯𝒚𝒅𝒓𝒐𝑮𝒆𝒏(𝒂𝒗𝒈𝒅𝒂𝒊𝒍𝒚𝒎𝒊𝒏)
𝑯𝒚𝒅𝒓𝒐𝑮𝒆𝒏(𝒂𝒗𝒈)𝑳𝒐𝒂𝒅(𝒂𝒗𝒈𝒅𝒂𝒊𝒍𝒚 𝒎𝒂𝒙)
𝑳𝒐𝒂𝒅 (𝒂𝒗𝒈)−𝑳𝒐𝒂𝒅(𝒂𝒗𝒈𝒅𝒂𝒊𝒍𝒚 𝒎𝒊𝒏)
𝑳𝒐𝒂𝒅 (𝒂𝒗𝒈)
=𝑫𝒆𝒍𝒕𝒂 (𝑯𝒚𝒅𝒓𝒐𝑮𝒆𝒏)
𝑫𝒆𝒍𝒕𝒂(𝑳𝒐𝒂𝒅)=𝑯𝒚𝒅𝒓𝒐𝑲 ′
𝑳𝒐𝒂𝒅𝑲 ′
Two Point K Factor
𝑳𝒐𝒂𝒅𝑲 ′=𝑳𝒐𝒂𝒅𝑹𝒂𝒏𝒈𝒆¿¿𝑯𝒚𝒅𝒓𝒐𝑲 ′=𝑯𝒚𝒅𝒓𝒐𝑮𝒆𝒏¿ ¿
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Calc Operational Min/Max Ratings• Calc operational min and max rating based on historic operations
– Base min rating on min gen curve at a 15% probability and max on the max gen curve at 85% probability
– Use the target average monthly generation for the average– The StDev is based on:
• Backcast use actual StDev• Forecast use calc StDev based on 2011-13 operations
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Summary of Modeling Change
• Split the 11 projects into upper and lower Columbia River to calculate PLF coefficients and compare to expected operations– Upper Columbia: Coulee through Priest Rapids– Lower Columbia: McNary through Bonneville
• Use a flat monthly generation shape for previously hourly shapes K:=0
ObjectiveTake a desired
operating year and have it’s monthly
operation conform to operation from 2011-
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Error Check 2010 BackcastCompare calculated hourly weekday generation shape with historic operation for accuracy in duplicating hourly shape
(hour ending 1-24)
2010 backcast matches actual operations
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Error Check 2013 BackcastCompare calculated hourly weekday generation shape with historic operation for accuracy in duplicating hourly shape
(hour ending 1-24)
2013 backcast matches actual operations
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Hydro Dispatch Against Load – Wind
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Hydro Dispatch Load - Wind• Relative to load, wind generation serves up to 64% of BPA daily load in 2014
or 20% of annual load• Changing from “Load” to “Load – Wind” increases the deviation in daily a
factor of 2.7• The expanded daily StDev directly impacts the daily allocation of Hydro
generation. This impact can be amplified when K is > 1BPA 2014 BA Load and Wind
Avg StDev StDev/Avg
Load 6,282 646 10%Wind 1,271 1,084 85%Load-Wind 5,011 1,351 27%
Installed Wind Capacity in BPA for 2014 4,515
MW
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Hydro Dispatch Load - Wind• The top right chart BPA load vs Core
Columbia gen (R^2=0.616)• The bottom right chart: BPA Load –
Wind vs Core Columbia gen (R^2:= 0.252)
• Bottom chart show daily Hydro generation tracking BPA load
Op Range (X Axis)BPA 0.9 to 1.1BPA-Wind 0.5 to 1.5
StDevAct HY 0.081HY (Load) 0.063HY (Load-Wind) 0.041
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Hydro Dispatch Load - Wind
• Compare backcasting April 2013 Hydro operation:– Against Load: A better match against actual Hydro
operation– Against Load-Wind: When wind comes on and off for a
couple of days the result Hydro diverges from actual Hydro generation
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Summary of Findings
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Summary of Findings
• Current modeling does not reflect operational changes on the Columbia River which starting in 2011– Base Hydro operating on year 2011-2013 for any forecast year
• K factor can be adjusted to account for different load forecast• Dispatching Hydro against “Load – Wind – Solar”
– In the Pacific Northwest, K based on:• “Load” is more predictable and matches historic operation• “Load –Wind” results in increase volatility in daily allocation of monthly
Hydro generation which is greater than historic operations
• Next step working on Hydro Thermal Coordination (HTC)
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Proposed GridView Improvements• Load – Wind – Solar: Add two new dimensions that control
how Load – Wind – Solar is set:– The ability to set Load – Wind – Solar by area/region– The ability to set a percentage (0% to 100%) of wind and solar that is
subtracted from the load– Example:
• BPA: 10% Wind and 100% Solar• CAISO: 100% Wind and 100% Solar