Kansas Electric Transmission Authority
(KETA) Study
April 2007
SPP ENGINEERING DEPARTMENT,
PLANNING SECTION
Kansas Electric Transmission Authority (KETA) Study
TABLE OF CONTENTS
1.
2.
3.
4.
EXECUTIVE SUMMARY ....................................................................................................... 3
INTRODUCTION ..................................................................................................................... 4
STUDY METHODOLOGY .................................................................................................... 10
RESULTS OF ANALYSIS ..................................................................................................... 13
A. Primary Analysis ................................................................................................................. 13
B. Study Results Summary ...................................................................................................... 14
C. High Fuel Sensitivity Analysis ............................................................................................ 17
D. Other Sensitivities ............................................................................................................... 18
5. CONCLUSIONS AND RECOMMENDATIONS .................................................................. 20
6. APPENDICES ......................................................................................................................... 22
A. Detailed Results .................................................................................................................. 22
B. High Fuel Pricing ................................................................................................................ 31
C. MUST Solution Settings ..................................................................................................... 35
D. Economic Model Options ................................................................................................... 36
1. Modeling Footprint .......................................................................................................... 36
2. Violation Cost .................................................................................................................. 36
3. Hurdle Rates..................................................................................................................... 37
4. Generator Benefit Equation ............................................................................................. 37
5. Wind Profiles ................................................................................................................... 38
6. PowerWorld Simulator Solution Options ........................................................................ 39
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Kansas Electric Transmission Authority (KETA) Study
1. EXECUTIVE SUMMARY
The purpose of the Kansas Electric Transmission Authority (KETA) Study (referred to hereafter
as “the Study”) is to determine potential 345 kV expansions having the greatest benefit to the
state of Kansas as conditions are known to exist in 2007. The KETA contracted Southwest
Power Pool (SPP) to perform this analysis. The goal of the KETA Study is to determine the best
fit project given a proposed set that would meet the needs of the state of Kansas and future wind
development.
This Study begins with the assumption that in the year 2010 Kansas will have an installed wind
capacity relative to 10% of the native load in the state. By the year 2020 this installed wind
capacity will grow to 20%. Failure to achieve these levels or if these levels are exceeded by
substantive amounts, the results would be impacted.
The four proposed project options that were conceptually approved by the KETA were used in
this Study. The first plan was Spearville – Reno Co. 345 kV. The next option was Spearville –
Knoll – Axtell 345 kV. The third was Summit – Concordia – Pauline 345 kV. Lastly,
Mooreland – Wichita 345 kV was considered. The last plan connects Kansas to the state of
Oklahoma, whereas the third and fourth options connect Kansas to the state of Nebraska. The
first option was the only option that did not consider ties outside Kansas.
Global Energy Decisions (GED) MarketSYMtm, Power Technologies Incorporated (PTI)
PSS/Etm and Managing and Utilizing System Transmissiontm (MUST), as well as PowerWorldtm
study analysis tools and software were used for this Study.
The Study found that transmission system expansion is, by nature, very lumpy. Forecasting as
far out as 2020 becomes very difficult due to sensitivities to not only transmission system
assumptions but also generation assumptions. SPP found that the Study was very sensitive to the
timing of the X-Plan development as well as the Competitive Renewable Energy Zones (CREZ)
assumptions. Additionally, the Study found that the development of the Mooreland – Wichita
345 kV project is highly sensitive to the status and timing of the Mooreland – Northwest 345 kV
upgrade. As such, SPP conducted sensitivities to document these issues.
Based on the Study results, SPP recommends that the Summit – Concordia – Pauline 345 kV
project be eliminated from future consideration at this time. The benefits of Spearville – Reno
Co. 345 kV project do not seem to be large enough to alter prior study results which supported
the X-Plan, which includes the Mooreland – Wichita 345 kV projects. The largest benefits
appear to result from the Spearville – Knoll – Axtell 345 kV project. This project offers the best
benefits based on the approved SPP Transmission Expansion Plan. Sensitivities indicate that the
Spearville – Knoll portion of this project provide stand alone savings to the state of Kansas. As
such, SPP recommends discussion with the Nebraska Public Power District (NPPD) about the
possibility of jointly funding the Knoll – Axtell portion of this project.
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Kansas Electric Transmission Authority (KETA) Study
2. INTRODUCTION
The Kansas Electric Transmission Authority (KETA) Study was a contracted study and involved
joint collaboration between Southwest Power Pool (SPP) and the KETA. The KETA requested
that SPP analyze a given set of projects to determine what project yields the most benefit to the
state of Kansas.
SPP analyzed two cases, a 2010 case and a 2020 case to be used in this Study. The models
incorporated the 2006-2016 SPP Transmission Expansion Plan (STEP) upgrades, as well as
including the following:










Economic Modeling & Methods Task Force (EMMTF) Assumptions Added (See
EMMTF report Transmission Network Economic Modeling & Methods, April 2006)
All upgrades in the 2006-2016 STEP up to 2016
Updated flowgate definitions
Updated import/export limits to account for 2006-2016 STEP additions
Wichita – Reno Co. – Summit 345 kV (2010)
Rose Hill – Sooner 345 kV (2010)
Spearville – Mooreland – Tuco & Mooreland - Northwest 345 kV upgrade (2016)
Holcomb East (2010)
Iatan Unit 2 (2010)
Red Rock (2016)
The Study also contained the following assumptions for wind:



1,500 MW of nameplate capacity of new wind development in the Texas Panhandle
which is delivered to Electric Reliability Council of Texas (ERCOT) North via an
HVDC station
Wind in Kansas at 10% capacity, proportional to Kansas load, in 2010
Wind in Kansas at 20% capacity, proportional to Kansas load, in 2020
The Study considered four options for transmission expansion in and out of the state of Kansas.
The upgrades were as follows:
Spearville – Reno Co. 345 kV
 Spearville – Reno Co. 345 kV Line
 Estimated Cost: $82M
Spearville – Knoll – Axtell 345 kV
 Spearville – Knoll 345 kV Line
 Knoll 345-230 kV Transformer
 Knoll 230-115 kV Transformer
 Knoll – Axtell 345 kV Line
 Estimated Cost: $186M
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Kansas Electric Transmission Authority (KETA) Study
Summit – Concordia – Pauline 345 kV
 Summit – Concordia 345 kV Line
 Concordia 345-230 kV Transformer
 Concordia – Pauline 345 kV Line
 Estimated Cost: $119M
Mooreland – Wichita 345 kV (shown with Spearville – Mooreland 345 kV in 2010)
 Mooreland – Wichita 345 kV Line
 Estimated Incremental Cost: $116M
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Kansas Electric Transmission Authority (KETA) Study
Figure 1 – Spearville – Reno Co. 345 kV
115-161kV Transmission
230kV Transmission
345kV Transmission
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Kansas Electric Transmission Authority (KETA) Study
Figure 2 – Spearville – Knoll – Axtell 345 kV
115-161kV Transmission
230kV Transmission
345kV Transmission
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Kansas Electric Transmission Authority (KETA) Study
Figure 3 – Summit – Concordia – Pauline 345 kV
115-161kV Transmission
230kV Transmission
345kV Transmission
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Kansas Electric Transmission Authority (KETA) Study
Figure 4 – Mooreland - Wichita 345 kV
115-161kV Transmission
230kV Transmission
345kV Transmission
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Kansas Electric Transmission Authority (KETA) Study
3. STUDY METHODOLOGY
The SPP economic models were used for this study. These models are based upon SPP’s 2006
Market Development Working Group (MDWG) model set. From this model set, SPP developed
a 2010 and 2020 series of models. Each model consisted of four seasonal models – spring,
summer, fall and winter. The 2006-2016 SPP Transmission Expansion Plan (STEP) identified
reliability upgrades were added to the models, as appropriate.
Notable topology additions beyond the 2006-2016 STEP include Spearville – Mooreland – Tuco
as well as Mooreland – Northwest 345 kV. This is part of what is commonly referred to as the
“X-Plan”. These upgrades are in-service during the Study for 2020 scenarios. The Wichita –
Reno Co. – Summit 345 kV upgrade in Central Kansas was included with an in-service date of
2010. The Rose Hill – Sooner 345 kV line from Kansas to Oklahoma was also included starting
in 2010. Additionally, the generating units of Holcomb East and Iatan 2 were added to the 2010
case, and the generating unit Red Rock was added as in-service for the 2020 cases.
SPP added the KETA approved wind assumptions to the models. As part of the base case, 1,500
MW of nameplate wind capacity was added in the Texas Panhandle for the 2020 cases with the
build out of the Mooreland – Northwest 345 kV line which is part of the X-Plan. This wind
energy would be delivered to ERCOT via an HVDC tie at Sunnyside with transactions based on
the wind profiles listed in the Appendix. SPP continues to work with Public Utilities
Commission of Texas, ERCOT staff and Texas stakeholders to develop transmission expansion
plans to deliver wind associated with Competitive Renewable Energy Zones (CREZs) being
proposed as a result of Senate Bill 20 in Texas.
In the state of Kansas, wind was assumed to be such that by 2010 the total installed nameplate
wind capacity in the state would be 10% of the peak load. The Study assumed by 2020 installed
nameplate wind capacity would be 20% of peak load. The wind was aggregated into wind
injection nodes on the 345 kV system to represent likely wind development from the surrounding
area. The wind assumptions used in the Study are shown in the table below.
KETA Study – Wind Assumptions
Future Wind
Capacity Basis
2010
2020
Capacity Capacity
(MW)
(MW)
Zone:
Western
450
1,110
Northwestern
165
330
Eastern
70
Central
165
330
Total New (MW) Wind:
780
1,840
State Total (MW) Wind:
1,140
2,200
Percent of
Total New
Wind
Location
of Wind
Injection
60%
15%
10%
15%
Spearville
Mingo
Elk River
Summit
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Kansas Electric Transmission Authority (KETA) Study
SPP staff applied an economic screening process involving the following:
 Global Energy Decisions (GED) MarketSYMtm package was used for unit commitment.
 PowerWorldtm’s OPF package (Version 11.0, April 5, 2006) was used for the Security
Constrained Economic Dispatch (SCED). Solution settings for PowerWorld are shown in
Appendix C-5.
Economic Modeling & Methods Task Force (EMMTF) assumptions were added to the economic
models (see EMMTF report for details). All generator operating directives and unit “must-run”
statuses affecting generators in SPP were modeled as appropriate. Additionally, flowgate
definitions were updated to match the current posting on the SPP OASIS.
A contingency analysis was performed to determine new potential transmission constraints. The
base case and each of the options were evaluated on an ‘as is’ basis through MarketSYM and
PowerWorld. From these runs, sample hours were used for an (n-1) contingency analysis in
PowerWorld to determine new potential constraints for the respective seasons. Additionally, the
wind generation was analyzed to determine that enough transmission was in place to adequately
deliver the wind output.
For area interchange assumptions, the interfaces and new export limits were derived using Power
Technologies, Inc (PTI) Managing & Utilizing System Transmission tm (MUST). The First
Contingency Total Transfer Capability (FCITC) was used to determine the total transfer limits
between areas. A 3% or 1 MVA cut-off was used to eliminate solution error and any potential
adverse impact to the analyses. All 100 kV and above facilities were monitored in the Study.
Specified multi-terminal outages, generator outages, and single line 100 kV and above
contingencies were simulated. This information was imported into PROSYM to be used in the
unit commitment logic.
The next step was to simulate a full year, using three typical week months per seasons, in order
to determine production cost savings (violation costs + dispatch cost savings) for the respective
upgrade options. A typical week screening involved using a one week sample to represent an
entire month. In this analysis every other hour is modeled. This type of analysis is done to cut
down on computer time in order to get results in a reasonable amount of time and to control
Study costs. SPP has found, through experience, that such results provide a reasonable
representation for the purpose of economic analysis to capture the expected outcome of a full
year run, where every hour is analyzed.
Dispatch cost savings are a representation of the value of fuel cost expected to be saved for the
more efficient dispatch after the upgrade cost has been incurred. During the simulation, if the
economic study program cannot unload a monitored element below the facility’s rating via
redispatch, the program will apply a penalty to that overload. This penalty represents a violation
cost and captures the cost of overloaded flowgates. Generator benefits are a proxy to represent
how much an area will be expected to save supplying its own load, purchasing and selling in
light of the modeled transmission after an upgrade takes place. The equation used to calculate
these values can be found in Appendix C of this report.
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Kansas Electric Transmission Authority (KETA) Study
The economic runs were made on Spring 2010, Summer 2010, Fall 2010 and Winter 2010/2011
models. This full run consisted of an Optimal Power Flow (OPF) for the area of SPP and the 1st
tier neighboring utilities. For the 2010 case, the models were solved using an AC solution
method. The nature of forecasting any long term simulation such as a 2020 transmission
planning model is difficult. The model assumed that no generation units would be retired after
2012. Additionally, the model was solved using a DC solution method to eliminate problems
seen outside of the modeling area due to inadequate transmission upgrades (i.e. only certain 345
kV and above additions have been added). This is a common solution technique utilized to
concentrate on areas of interest in planning studies.
The production cost savings (defined as dispatch cost savings + violation savings) were then
used to calculate an estimated 10-year, 20-year and 40-year benefit using an 8% discount rate.
Additionally, estimated generator benefits were calculated for the same time periods. These
results can be seen in the next section of this report. Note: Generator benefits do not consider
violation cost savings, which can be significant due to congestion.
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Kansas Electric Transmission Authority (KETA) Study
4. RESULTS OF ANALYSIS
A. Primary Analysis
The tables in the Appendix detail the dispatch cost savings, violation savings, and net generator
benefits (described in the previous section of this report) by zone for each of the options detailed
previously. The tables demonstrate estimated savings by season. The numbers are
representative of the change between two cases; therefore, the appropriate base case values are
subtracted from the respective change case.
These tables demonstrate the savings seen in one year only, for 2010 and 2020 respectively.
Subsequent tables list 10-year and 20-year projected benefits. It is significant that the majority
of the benefits for each of the upgrade solutions are primarily assigned to the state of Kansas. It
is also noteworthy that violation savings shown in the tables below are not included in the area
totals and is a stand alone savings.
SPP believes the results of this analysis to be very conservative. The analysis did not attempt to
capture the benefit to load in Kansas. Additionally, wind is given the highest priority in dispatch
due to its zero cost basis. Economic models consider wind as a zero cost energy source. In
reality, wind would often be curtained due to its non-firm nature impacting existing congestion
on the system. The benefits of enabling more economic wind transactions are not entirely
captured in this study.
Additionally, the analysis ignores incremental impacts of unit recommitment which may be
possible after an upgrade. In reality, units would be recommitted based on a large increase in
transfer capability across the system. Expensive units needed for security would be displaced by
lower cost resources, if available. This benefit is not captured in this analysis. Because of these
reasons, the true benefits across the entire study region would be significantly greater than are
stated in this Study.
For the analysis of the Mooreland – Wichita 345 kV upgrade in 2010, SPP also included
Spearville – Mooreland 345 kV in the models. The objective of this scenario is to provide
results which can be compared to the 2020 case for trending analyses. The additional cost of
Spearville – Mooreland 345 kV is not included in the cost estimates as this project is already a
part of the current 2006-2016 STEP.
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Kansas Electric Transmission Authority (KETA) Study
B. Study Results Summary
To determine total societal benefit of a project, one must consider the value of the production
cost savings (dispatch + violation savings) versus total incremental project cost for each project.
Note that the production cost is the sum of the dispatch cost reduction and the violation reduction
shown over a ten, twenty or forty year period, assuming a discount rate of 8% per year.
The tables below demonstrate these values for the projects studied in both 2010 and 2020 given
the appropriate study assumptions. These tables serve to compare the present worth of the ten,
twenty and forty year production cost savings versus the total engineering and construction
(E&C) installed costs of the respective projects. The first table demonstrates the projected
production cost savings based solely on the 2010 study results alone. The second table
demonstrates this same assumption, with an estimated interpolation between the 2010 and 2020
results, and extrapolation beyond 2020. This was done by assuming the reduced benefit from the
2020 results occurs in 2016 when the major 2006-2016 STEP upgrades occur, then discounting
projecting that benefit from that point onward.
Projections Based on 2010 Results
Project Name
Spearville - Reno Co 345 kV
Spearville - Knoll - Axtell 345 kV
Summit - Concordia - Pauline 345 kV
Mooreland - Wichita 345 kV*
Project Cost
($M)
$
82
$
186
$
119
$
116
Yearly Production
Cost Savings ($M)
$
18.79
$
15.54
$
5.09
$
18.07
10 Year Projection @
8% Discount Rate
Production Cost
Savings ($M)
$
75.0
$
62.1
$
20.3
$
72.2
* Note: Spearville - Mooreland 345 kV not included in cost estimate
2020 Results
Project Cost
($M)
$
82
$
186
$
119
$
116
Project Name
Spearville - Reno Co 345 kV
Spearville - Knoll - Axtell 345 kV
Summit - Concordia - Pauline 345 kV
Mooreland - Wichita 345 kV
Combined Estimated Projections
(Starting in 2010)
Project Name
Spearville - Reno Co 345 kV
Spearville - Knoll - Axtell 345 kV
Summit - Concordia - Pauline 345 kV
Mooreland - Wichita 345 kV
Project Cost
($M)
$
82
$
186
$
119
$
116
Yearly Production
Cost Savings ($M)
$
5.09
$
13.87
$
5.76
$
4.67
10 Year Projection @
8% Discount Rate
Production Cost
Savings ($M)
$
29.7
$
56.5
$
22.5
$
27.8
20 Year Projection @
8% Discount Rate
Production Cost
Savings ($M)
$
53.2
$
120.5
$
49.1
$
49.3
40 Year Projection @
8% Discount Rate
Production Cost
Savings ($M)
$
63.9
$
149.7
$
61.2
$
59.1
These snap shots demonstrate the lumpy nature of transmission, that major 345 kV upgrades like
the western half of the X-Plan have drastic impacts on the economic value of additional
transmission upgrades. As expected, generation expansion assumptions have a significant
impact on any economic analysis for potential transmission expansion projects.
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Kansas Electric Transmission Authority (KETA) Study
Based on the Study results, SPP recommends that the Summit – Concordia – Pauline 345 kV
project be eliminated from future consideration at this time. The benefits of Spearville – Reno
Co. 345 kV project do not seem to be large enough to alter prior study results which supported
the X-Plan, which includes the Mooreland – Wichita 345 kV projects. The largest benefits
appear to result from the Spearville – Knoll – Axtell 345 kV project. This project offers the best
benefits based on the approved SPP Transmission Expansion Plan. Sensitivities indicate that the
Spearville – Knoll portion of this project provide stand alone savings to the state of Kansas. As
such, SPP recommends discussion with the Nebraska Public Power District (NPPD) about the
possibility of jointly funding the Knoll – Axtell portion of this project. It would be also
recommended that additional analyses be performed in conjunction with Nebraska and other
affected parties to assess the benefits of the Spearville – Knoll – Axtell 345 kV project and any
impacts of other generation and other transmission projects from the surrounding area on this
project.
The X-Plan and the CREZ assumptions play a large role in this analysis. Therefore, SPP ran
some summer sensitivities to determine the relative impact of these assumptions on this analysis.
These results are shown later in this report.
The KETA requested SPP demonstrate the portion of benefits from each upgrade that are
realized in the state of Kansas. The table below shows the portion of the benefits projected for
the state of Kansas for the respective projects and years. The benefits in Kansas are defined by
the benefits to areas that primarily reside in the state, and are based on generator benefits, not
load benefits of these projects. The following are the areas analyzed:






Sunflower Electric Cooperative
Westar Energy
Kansas City Power and Light
Board of Public Utilities (Kansas City, KS)
Midwest Energy
Mid-Kansas Electric Company, formally West Plains, Kansas (Aquila)
The following table shows which portion of the benefits in SPP are expected in Kansas as well as
the portion of benefits across SPP and tier 1 that are projected in Kansas. It should be noted that
for most projects, the majority of the benefits reside in Kansas.
Benefits to Kansas Project Name
Spearville - Reno Co 345 kV
Spearville - Knoll - Axtell 345 kV
Summit - Concordia - Pauline 345 kV
Mooreland - Wichita 345 kV
Spearville - Mooreland - Wichita 345 kV
2010
2020
Percent of SPP
Percent of Total
Percent of SPP
Percent of Total
Benefits in Kansas Benefits in Kansas Benefits in Kansas Benefits in Kansas
66.7%
59.0%
82.5%
66.3%
59.8%
51.6%
40.0%
59.9%
15
53.4%
42.8%
48.0%
44.6%
-
50.5%
37.9%
29.4%
40.8%
-
Kansas Electric Transmission Authority (KETA) Study
Upon further inspection, it appears that the majority of the violation cost savings for any
transmission project in this analysis are attributed to relieved flowgates in southwest Kansas.
Therefore, these results are a conservative estimate of the projected benefit to the state due to the
fact that these benefits do not consider violation cost savings.
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Kansas Electric Transmission Authority (KETA) Study
C. High Fuel Sensitivity Analysis
SPP performed a sensitivity run using the 2010 summer models to determine the impact of a
higher fuel cost on project benefit. This run was used as a representation of expected value over
the lifetime of the projects.
$1.50/MMBtu was added to the price of gas and distillate fuel oil within SPP and 1st tier zones.
This increased the average natural gas price from $6.88 per million BTU to $8.38 per million
BTU (See Appendix A for exact fuel prices used in the analysis).
2010 Summer Base
Production Cost
Savings ($M)
Project Name
Spearville - Reno Co 345 kV
Spearville - Knoll - Axtell 345 kV
Summit - Concordia - Pauline 345 kV
Spearville - Mooreland - Wichita 345 kV
$
$
$
$
8.5
8.0
2.2
8.1
2010 Summer
High Fuel
Production Cost
Savings ($M)
$
13.6
$
13.1
$
3.5
$
14.0
Percent
Increase
60%
63%
59%
72%
An increase of 22% in the price of premium fuels results in a 60-70% increase in the economic
value of any of these projects. This increase in benefit is significant in that any project except
Summit – Concordia – Pauline 345 kV would be economically viable.
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Kansas Electric Transmission Authority (KETA) Study
D. Other Sensitivities
SPP performed additional sensitivities to determine the impact of the CREZ wind assumptions
and the X-Plan on the analysis. These sensitivities were conducted on the 2010 Summer case
only.
The first sensitivity involved 2010 with the inclusion of the X-Plan, but forgoing the Mooreland
– Northwest 345 kV upgrade in Oklahoma. This run did not include the CREZ zones as before.
One objective of this sensitivity was to determine the impact of Mooreland – Northwest 345 kV
upgrade on the Mooreland – Wichita 345 kV upgrade. Secondly, additional sensitivities were
ran to gauge the impact of building Spearville – Knoll 345 kV in Kansas as an incremental step
to building Spearville – Knoll – Axtell 345 kV.
The next sensitivity was run using the 2010 Summer case, but including not only the X-Plan (as
detailed above) but also the CREZ wind zones. The purpose of this sensitivity was to gauge the
impact of the CREZ assumptions on the Mooreland – Northwest 345 kV upgrade.
The results of these sensitivities are seen in the table below.
Sensitivities
Project Cost
($M)
Project Name
2010 without CREZ, with XPlan
Spearville - Knoll 345 kV
Spearville - Knoll - Axtell 345 kV
Mooreland - Wichita 345 kV
2010 with CREZ, with XPlan
Mooreland - Wichita 345 kV
2010 Summer Only
Yearly Production
Cost Savings ($M)
$
$
$
87
186
116
$
$
$
1.7
3.0
1.4
$
116
$
1.6
As can be shown from the table above, the X-Plan does impact the Spearville – Knoll – Axtell
345 kV project. The summer benefit in the 2010 case that did not include the X-Plan was $8M
(shown in the Appendix), whereas after this upgrade takes place the benefit is $3M.
The Spearville – Knoll 345 kV project appears to be the most economically beneficial KETA
project based on the summer sensitivity analyses. This project is less than half the cost of the
Spearville – Knoll – Axtell 345 kV project, yet returns more than half the benefit. It should be
suggested that the possibility of Kansas funding the Spearville – Knoll 345 kV portion of the
Spearville – Knoll – Axtell 345 kV project, with significant contribution from Nebraska towards
the final leg of Knoll – Axtell 345 kV should be considered.
The Mooreland – Wichita 345 kV project shows a slightly higher return of $1.6M in 2010 with
the western half of the X-Plan and CREZ and $1.4M with the western half of the X-Plan but
without the CREZ in these summer sensitivity analyses.
The Mooreland – Wichita 345 kV project is extremely sensitive as to whether or not the
Mooreland – Northwest 345 kV upgrade is constructed before or after this project, since the
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Kansas Electric Transmission Authority (KETA) Study
incremental economic impact of the 4th leg of the X-Plan is minimal as expected. The last leg of
the X-Plan can not be expected to be justified on economic efficiency gains alone.
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Kansas Electric Transmission Authority (KETA) Study
5. CONCLUSIONS AND RECOMMENDATIONS
The benefits of a 345 kV tie from Kansas to Nebraska are significantly larger for an
interconnection into Western Kansas, versus and interconnection into Central Kansas.
Therefore, Summit – Concordia – Pauline 345 kV needs to be eliminated from consideration by
KETA in lieu of the superior alternative of Spearville – Knoll – Axtell 345 kV based on this
analysis.
The benefits of Spearville – Reno Co 345 kV are inadequate to justify consideration of that
project by KETA. The Spearville – Mooreland – Wichita 345 kV project is superior to a
Spearville – Reno Co 345 kV project, despite a minor reduction in economic benefits, given how
it coincides with regional planning studies which have consistently concluded the superiority of
the implementation of the X plan over other alternatives. The Mooreland – Wichita 345 kV
project benefits are related to the status of CREZ developments in Texas and the timing of the
Mooreland – Northwest 345 kV expansion to deliver CREZ energy via Oklahoma to ERCOT
North and other markets. The sensitivity analysis supports these findings. As expected, the
benefits of Mooreland – Wichita 345 kV project increase slightly if that project is built prior to
Mooreland – Northwest expansion.
The Spearville – Knoll – Axtell 345 kV project warrants more analysis to evaluate benefits of
individual segments to Kansas, Nebraska and other affected entities in and around SPP. It
should be noted that while this project is impacted by the development of the X-Plan, this impact
is minimal. A sensitivity evaluating Spearville – Knoll 345 kV line segment in 2010 indicates
that this project has a good rate of return for the state of Kansas even without the final leg of
Knoll – Axtell 345 kV project. Additional discussions with Nebraska Public Power District
(NPPD) and others are warranted to share these KETA Study results and determine the interest
by NPPD and others to pursue an interconnection between Nebraska and Kansas.
It is significant that most projects in this Study had a majority of the benefits in the state of
Kansas. This coincides with the fact that the majority of transmission miles also are constructed
in the state of Kansas.
It is worth noting that this analysis does not attempt to capture benefits to load serving entities.
The analysis focuses on capital expenditure versus production cost savings (dispatch + violation
savings) for a project. There are benefits to loads across the entire SPP footprint, and
specifically in Kansas, that this analysis does not attempt to capture.
Additionally, since wind resources are considered a price taker (the models price wind at
$0/MW), the entire benefit to wind generators is not captured by these models. The addition of
transmission upgrades in Kansas will enable the state to realize greater amounts of the abundant
wind resources in Kansas. This benefit would be realized as a reduction in the cost to serve load
across the state and the entire SPP footprint and is only partially captured by the “Generator
Benefit” representation.
Lastly, the analyses did not capture the potentially large benefits associated with changes to unit
commitment between zones. Significant transmission upgrades would impact these existing
20
Kansas Electric Transmission Authority (KETA) Study
operating constraints. This Study does not attempt to capture the benefit of relaxing those limits.
The Study does not consider unit recommitment between the base case and respective upgrade
cases. The results only demonstrate the cost of the lower cost unit dispatch anticipated for a set
unit commitment profile. As such, the true benefits across the entire study region would be
significantly greater than are stated in this Study. For these reasons, SPP believes these results to
be a very conservative.
On a final note, as part of this study, SPP did not consider any deferred cost of projects needed to
meet reliability toward the benefit calculations in this study. In reality, this deferred portion of
the reliability plan would be considered as part of the benefit to an economic project in SPP.
Results of this Study would necessarily change as assumptions are modified.
21
Kansas Electric Transmission Authority (KETA) Study
6. APPENDICES
A. Detailed Results
The tables below detail the dispatch cost savings, violation savings, and net generator benefits
(described in the previous section of this report) by zone for each of the options detailed
previously. The tables demonstrate estimated savings by season. The numbers are
representative of the change between two cases; therefore, the appropriate base case values are
subtracted from the respective change case.
These tables demonstrate the savings seen in one year only, for 2010 and 2020 respectively. It is
significant that the majority of the benefits for each of the upgrade solutions demonstrate benefits
primarily assigned to the state of Kansas. It is noteworthy that violation savings shown in the
tables below is not included in the area totals and is a stand alone savings.
22
Kansas Electric Transmission Authority (KETA) Study
2010 - Spearville - Reno Co. 345 kV
Area
CELE
EMDE
GRDA
INDN
KACP
KACY
LAFA
LEPA
MIDW
MIPU
OKGE
OMPA
AEPW
SPPIPP
SPRM
SUNC
SWPA
SPS
WEPL
WERE
WFEC
WINDSPP
Spring
Summer
Fall
Winter
Totals
Dispatch
Generator
Dispatch
Generator
Dispatch
Generator
Dispatch
Generator
Dispatch
Generator
Savings
Benefit
Savings
Benefit
Savings
Benefit
Savings
Benefit
Savings
Benefit
$56,857
$2,721
$778,218
($9,462)
($95,116)
$2,425
$374,158
($3,763)
$1,114,116
($8,079)
$2,359
$41
$357,083
$3,337
$262,460
$10,955
$122,436
$976
$744,339
$15,309
($7,922)
$27
$45,171
$430
$36,404
$517
($3,820)
$0
$69,833
$974
$0
$0
$15,478
$200
$0
$0
$1,206
$42
$16,684
$242
$863
$0
$227,353
$1,329
$255,578
$4,478
$57,629
$1,068
$541,422
$6,875
$1,156
$1
$137,680
$3,400
$121,225
$2,453
$21,511
$291
$281,572
$6,145
$152,645
($1,362)
$664,266
$6,723
$166,805
$1,066
$156,427
$60
$1,140,142
$6,487
$1,205
($0)
$35,506
$682
$11,140
$155
$11,682
$226
$59,533
$1,063
$0
$0
$3,363
$3,363
$3,761
$3,761
$0
$0
$7,124
$7,124
($8,435)
$252
$934,475
$18,532
$303,880
$6,367
$528,495
$13,667
$1,758,415
$38,818
$75,262
$19,588
$2,500,768
$323,676
$1,971,715
$256,781
$221,816
($22,281)
$4,769,560
$577,764
($14)
($0)
$182,150
$6,664
$43,434
$1,397
$33,293
$939
$258,863
$9,000
($100,077)
($32,756) $1,480,267
$47,619
$215,030
($48,732)
$53,491
($16,453)
$1,648,711
($50,321)
$5,790
$0
$897,621
$21,698
$148,275
$2,030
$3
$3
$1,051,689
$23,732
$32,598
($18)
$434,640
$7,095
$214,699
$4,724
$52,886
$383
$734,822
$12,184
($44,957)
$14,419 ($3,455,380)
$1,370,120
($2,687,063)
$1,010,714
($595,145)
$155,905
($6,782,545)
$2,551,159
($11,352)
$71
$9,808
$632
$37,063
$427
$6,212
($625)
$41,732
$504
$93,708
$36,439 ($10,808,731)
$579,190
($4,327,601)
$346,774
($1,877,494)
$137,465 ($16,920,119)
$1,099,868
($57,443)
($3,729) ($1,490,131)
$129,367
$164,847
$90,901
($367,583)
$122,678
($1,750,310)
$339,218
$204,525
$15,594
$5,947,511
$360,230
$1,666,034
$94,040
$740,288
$80,274
$8,558,357
$550,138
($28,212)
$1,421
$334,310
$7,980
$60,931
$13,530
($33,051)
$4,925
$333,978
$27,857
$0
$8,577
$0
$92,297
$0
$38,524
$0
$35,056
0
$174,454
Subtotals
$368,555
$61,285
AECI
IOWA
MAINS
NEBR
EES
EESIPP
$2,082
($17,825)
$69,413
$45,874
$191,850
($5,202)
Subtotals
Totals
Violation
Savings
($768,577)
$2,975,106
($1,426,501)
($11,543)
($107)
$6,899
$45,874
($26,677)
$2,127
$384,408
($198,316)
$1,036,539
($1,042,291)
$4,319,533
$1,148,616
$52,442
$67,447
$35,491
$307,634
$6,620
$3,214
$744,186
($75,914)
$337,929
($369,915)
$3,541,048
$812,876
$286,193
$16,573
$5,648,488
$472,847
$4,990,210
$654,748
$77,859
$4,879,912
$3,447,953
$3,563,709
($74,072)
$3,623,516
$1,843,287
$11,554
$14,988
$983
$15,973
($74,674)
$31,445
$510,838
($2,322,083)
$5,390,516
$236,263
$18,271
$88,297
($48,045)
$1,258,990
$290,451
($4,694)
$17,157
$7,166
$22,221
$7,771
$2,081
$1,366,939
($273,784)
$1,532,177
($1,414,377)
$9,311,422
$2,246,741
$47,758
$99,485
$50,539
$391,702
($86,961)
$38,867
$269
$1,844,227
$51,702
$12,769,118
$541,391
$1,843,556
$1,348,666
$562,539
$10,447,035
$5,931,907
$3,807,543
23
($495,561)
$989,406
$8,346,392
Kansas Electric Transmission Authority (KETA) Study
2010 - Spearville - Knoll - Axtell 345 kV
Area
CELE
EMDE
GRDA
INDN
KACP
KACY
LAFA
LEPA
MIDW
MIPU
OKGE
OMPA
AEPW
SPPIPP
SPRM
SUNC
SWPA
SPS
WEPL
WERE
WFEC
WINDSPP
Spring
Summer
Fall
Winter
Totals
Dispatch
Generator
Dispatch
Generator
Dispatch
Generator
Dispatch
Generator
Dispatch
Generator
Savings
Benefit
Savings
Benefit
Savings
Benefit
Savings
Benefit
Savings
Benefit
($8,340)
($4,362) $1,020,612
($13,161)
$58,218
$60
$403,764
($5,738)
$1,474,253
($23,202)
$977
($61)
$221,479
$3,370
$236,801
$6,331
$114,220
$287
$573,477
$9,926
$1,659
$61
$29,044
$66
$35,370
$426
($885)
$0
$65,188
$553
$0
$0
$37,894
$651
$0
$0
$1,196
$42
$39,089
$693
($1,856)
($5)
$247,374
$28,000
$218,018
$628
$52,660
$1,257
$516,196
$29,880
$587
$3
$128,699
$2,600
$115,243
$3,420
$20,644
$547
$265,173
$6,569
$186,802
($1,346)
$511,800
$6,154
$67,894
$697
$153,878
$26
$920,374
$5,532
$631
($4)
$36,536
$544
$11,556
$138
$12,202
$223
$60,924
$901
$0
$0
($10,672)
($10,672)
($3,727)
($3,727)
($3,620)
($3,620)
($18,019)
($18,019)
$2,966
$35
$1,016,137
$29,311
$283,472
$4,935
$518,899
$12,969
$1,821,474
$47,250
$91,628
$1,173
$2,107,804
$270,944
$1,308,698
$297,636
$247,978
$51,486
$3,756,108
$621,238
$154
$0
$176,764
$3,105
$37,820
$417
$23,531
$1,222
$238,269
$4,743
$48,479
($24,204) $1,578,183
$70,577
$634,225
($187)
$126,596
$9,495
$2,387,482
$55,681
($2,817)
$0
$902,401
$21,762
$96,465
$1,830
$0
$0
$996,049
$23,592
$44,127
($6)
$430,055
$5,234
$118,331
$2,420
$68,374
$783
$660,888
$8,431
($27,141)
$9,385 ($2,996,149)
$746,012
($2,162,622)
$421,947
($569,238)
$145,663
($5,755,149)
$1,323,007
($4,898)
$6
$7,047
$447
$11,450
$164
($1,790)
($4,164)
$11,809
($3,547)
($419,331)
$8,433 ($12,331,054)
$453,168
($6,125,394)
$105,953
($2,228,945)
$59,292 ($21,104,723)
$626,846
($58,567)
($4,762) ($1,886,969)
($240,010)
($431,189)
($370,539)
($443,021)
$60,530
($2,819,745)
($554,781)
$197,877
$41,575
$5,099,101
$357,329
$1,211,174
$124,317
$638,510
$53,884
$7,146,662
$577,105
$95,120
$780
$325,968
$14,456
$151,784
$14,353
$32,134
$2,682
$605,006
$32,270
$0
$6,177
$0
$44,346
$0
$25,903
$0
$53,055
0
$129,481
Subtotals
$148,055
$32,878
($3,347,945)
AECI
IOWA
MAINS
NEBR
EES
EESIPP
$54,970
$33,339
$50,069
($18,161)
$172,339
$138,689
$24,413
$655
$8,757
($18,161)
($48,342)
$410
$595,719
$465,198
$1,025,193
($604,281)
$4,559,053
$1,533,472
Subtotals
$431,245
($32,269)
Totals
$579,300
Violation
Savings
$609
($86,209)
$1,794,232
($4,126,415)
$637,119
($832,912)
$439,921
($8,159,216)
$114,807
$33,944
$48,328
$178,646
($29,954)
$4,143
$721,561
$246,907
$355,391
($135,615)
$3,630,626
$1,042,609
$29,865
$12,196
$16,994
$3,225
($38,042)
$12,579
$187,742
($1,334)
$125,253
($24,478)
$1,173,504
$354,540
$5,582
$384
$11,321
$13,608
$30,873
$1,792
$1,559,992
$744,111
$1,555,906
($782,536)
$9,535,523
$3,069,311
$7,574,354
$349,914
$5,861,479
$36,816
$1,815,227
$63,559
$15,682,305
$418,020
$4,226,410
$2,144,145
$1,735,064
$673,935
$982,315
$503,480
$7,523,089
$3,322,169
$3,788,041
$3,289,764
24
$1,029,202
$2,904,149
$174,666
$47,178
$85,399
$177,317
($85,465)
$18,925
$8,020,798
Kansas Electric Transmission Authority (KETA) Study
2010 - Summit - Concordia - Pauline 345 kV
Area
CELE
EMDE
GRDA
INDN
KACP
KACY
LAFA
LEPA
MIDW
MIPU
OKGE
OMPA
AEPW
SPPIPP
SPRM
SUNC
SWPA
SPS
WEPL
WERE
WFEC
WINDSPP
Spring
Summer
Fall
Winter
Totals
Dispatch
Generator
Dispatch
Generator
Dispatch
Generator
Dispatch
Generator
Dispatch
Generator
Savings
Benefit
Savings
Benefit
Savings
Benefit
Savings
Benefit
Savings
Benefit
($154,611)
($4,503)
($119,174)
$2,593
($75,320)
($3,792)
$12,929
($2,370)
($336,176)
($8,072)
($2,791)
($56)
$45,274
$1,202
$63,631
$2,789
$33,057
$402
$139,171
$4,336
($3,923)
$6
$7,815
$288
($1,871)
$57
($533)
$0
$1,488
$351
$0
$0
$5,254
$20
$0
$0
$0
$0
$5,254
$20
($4,267)
($2)
$111,513
$32,295
$41,315
($9,677)
$1,922
($68)
$150,483
$22,548
$4
$4
$27,755
$226
$12,031
$352
$10,282
$13
$50,072
$596
$113,705
($768)
$46,773
($487)
($140,313)
($392)
($165)
$8
$19,999
($1,639)
$0
$0
$727
$36
$18
($12)
$1,155
$24
$1,900
$48
$0
$0
$3,391
$3,391
$3,744
$3,744
$0
$0
$7,135
$7,135
$3,253
$37
$392,441
$13,711
$81,608
$364
$159,472
$133
$636,774
$14,245
$45,825
($21,943)
$348,227
$65,924
$189,474
($103,312)
$112,785
$20,155
$696,311
($39,176)
$50
($0)
$40,596
$1,292
$12,277
$1,107
$1,847
$820
$54,770
$3,219
($7,151)
($19,187)
($71,457)
$17,433
$57,917
($36,728)
$25,397
$16,638
$4,705
($21,843)
$809
($0)
$289,778
$1,209
$312
$24
$0
$0
$290,899
$1,233
$34,020
$123
$46,085
$659
($6)
$288
$680
$91
$80,778
$1,161
($23,568)
$966
($516,893)
$42,605
($460,742)
$17,718
($182,874)
$4,497
($1,184,077)
$65,786
($4,814)
$17
$5,579
($2,033)
($1,560)
($96)
$747
($282)
($48)
($2,394)
$94,561
$2,823
($793,056)
($16,676)
($116,963)
$18,616
($400,247)
$6,461
($1,215,705)
$11,224
($294)
$17
$82,492
($54,844)
$7,353
$2,773
$5,587
($4,982)
$95,137
($57,036)
$107,895
$20,017
$908,467
$101,694
$470,189
($20,669)
$261,848
$43,917
$1,748,400
$144,959
$64,141
$369
$165,662
$9,513
($104,368)
$5,516
($69,236)
$1,038
$56,199
$16,436
$0
$2,006
$0
$2,063
$0
$462
$0
$1,356
0
$5,887
Subtotals
$262,843
($20,073)
AECI
IOWA
MAINS
NEBR
EES
EESIPP
$3,556
($18,190)
$89,665
($19,624)
$2,038
$145,375
$10,894
($693)
$12,562
($19,624)
($4,236)
($1,124)
Subtotals
$202,820
Totals
$465,663
Violation
Savings
$222,115
$38,725
($120,868)
($25,347)
$87,851
$261,477
$128,396
($177,824)
($397,907)
$138,687
$69,212
$118,940
$13,689
$21,576
($2,906)
$4,407
$784
$277,089
$40,096
$93,016
($78,589)
($65,956)
$127,658
$23,779
($3,931)
$1,154
$1,967
($23,190)
$2,112
$228,991
$138,826
($35,489)
($33,447)
$179,717
$84,449
$41,338
$61,182
($60)
($14,120)
$39,394
$120
($2,221)
$22,041
$156,490
$393,314
$1,891
$563,047
$127,854
$1,181,221
$284,015
($22,294)
$1,049,288
$378,605
$432,039
$537,700
$215,705
$2,484,690
$453,040
$67,497
$1,027,247
$1,160,019
($118,977)
$1,154,287
25
$220,231
$1,303,468
$771,113
$289,127
($30,631)
($529,567)
$254,486
$426,693
$169,025
$194,951
$70,247
$35,233
($34,683)
$16,375
$1,893
$2,602,034
Kansas Electric Transmission Authority (KETA) Study
2010 - Spearville - Mooreland - Wichita 345 kV
Area
CELE
EMDE
GRDA
INDN
KACP
KACY
LAFA
LEPA
MIDW
MIPU
OKGE
OMPA
AEPW
SPPIPP
SPRM
SUNC
SWPA
SPS
WEPL
WERE
WFEC
WINDSPP
Spring
Summer
Fall
Winter
Totals
Dispatch
Generator
Dispatch
Generator
Dispatch
Generator
Dispatch
Generator
Dispatch
Generator
Savings
Benefit
Savings
Benefit
Savings
Benefit
Savings
Benefit
Savings
Benefit
($32,204)
($1,288)
$907,701
($7,902)
$103,553
$2,798
$427,929
($4,297)
$1,406,979
($10,689)
($2,614)
$80
$413,217
$4,309
$316,692
$11,655
$157,164
$1,143
$884,460
$17,187
($11,653)
($9)
$66,483
$452
$34,366
$413
($3,108)
$0
$86,087
$856
$0
$0
$14,656
$109
$0
$0
$1,206
$42
$15,862
$151
$1,211
$0
$238,876
$2,001
$263,448
$4,495
$44,943
$835
$548,478
$7,331
($746)
$1
$175,692
$3,121
$127,361
$3,249
$32,369
$329
$334,676
$6,699
$116,375
($852)
$484,757
$4,361
$182,376
$1,471
$157,029
$57
$940,536
$5,038
$583
$2
$31,172
$555
$9,132
$109
$11,682
$225
$52,569
$892
$0
$0
($6,977)
($6,977)
$3,761
$3,761
$0
$0
($3,215)
($3,215)
($2,480)
$210
$786,204
$14,339
$277,889
$5,836
$533,173
$13,544
$1,594,786
$33,928
$57,896
$16,416
$2,304,277
$313,948
$1,528,036
$271,114
$384,825
($17,065)
$4,275,034
$584,413
$1,719
($3)
$184,081
$6,341
$47,682
$1,491
$34,137
$988
$267,619
$8,817
($64,569)
($45,545) $1,435,464
$44,801
$582,966
($42,635)
$111,384
($15,214)
$2,065,245
($58,593)
$6,969
($0)
$890,101
$18,955
$126,871
$1,796
$1
$1
$1,023,942
$20,751
($13,664)
$259
$469,570
$8,094
$205,365
$4,477
$62,472
$395
$723,743
$13,225
($43,569)
$14,605 ($3,470,934)
$1,292,584
($2,789,893)
$1,013,593
($624,573)
$190,048
($6,928,968)
$2,510,830
($2,694)
($11)
$20,350
($1,038)
$23,344
$365
$6,082
($576)
$47,083
($1,261)
$84,094
$40,489 ($10,931,676)
$488,163
($4,713,119)
$250,415
($2,081,522)
$129,180 ($17,642,223)
$908,247
($51,274)
$785 ($1,084,663)
($92,042)
($40,322)
($40,960)
($381,735)
$101,708
($1,557,994)
($30,509)
$286,036
$34,284
$5,101,986
$314,655
$1,328,827
$86,698
$547,787
$52,501
$7,264,635
$488,137
$19,764
$1,282
$293,128
$10,428
$136,461
$16,587
($37,445)
$5,313
$411,908
$33,610
$0
$5,079
$0
$97,191
$0
$34,928
$0
$56,359
0
$193,556
Subtotals
$349,181
$65,783
($1,676,535)
$2,516,448
($2,245,204)
AECI
IOWA
MAINS
NEBR
EES
EESIPP
($28,437)
($57,320)
$81,627
$31,374
$33,262
$155,849
($141)
($181)
($18,292)
$31,374
($35,836)
($13,882)
$326,841
($257,087)
$904,561
($1,032,588)
$4,566,828
$1,199,879
$53,649
$62,634
$40,709
$229,665
$2,662
$4,019
$818,947
($93,146)
$524,755
($342,118)
$3,462,172
$868,356
Subtotals
$216,355
($36,958)
$5,708,434
$393,336
Totals
$565,536
$28,825
$4,031,898
$2,909,784
Violation
Savings
($112,668)
($616,201)
$515,517
($4,188,759)
$15,308
$16,296
$8,992
$6,245
($41,414)
$30,566
$211,841
($17,897)
$66,116
($48,823)
$1,284,735
$231,219
$2,908
$14,450
$5,341
$28,807
$10,045
$2,228
$1,329,191
($425,450)
$1,577,058
($1,392,155)
$9,346,998
$2,455,303
$71,724
$93,198
$36,749
$296,091
($64,542)
$22,930
$5,238,966
$35,993
$1,727,191
$63,779
$12,890,946
$456,150
$2,993,762
$1,667,649
$1,110,989
$579,296
$8,702,186
$5,185,554
$4,077,757
$1,631,656
$4,171,098
26
$1,234,422
$4,729,404
$9,370,608
Kansas Electric Transmission Authority (KETA) Study
2020 - Spearville - Reno Co. 345 kV
Area
CELE
EMDE
GRDA
INDN
KACP
KACY
LAFA
LEPA
MIDW
MIPU
OKGE
OMPA
AEPW
SPPIPP
SPRM
SUNC
SWPA
SPS
WEPL
WERE
WFEC
WINDSPP
Subtotals
Spring
Summer
Fall
Winter
Totals
Dispatch
Generator
Dispatch
Generator
Dispatch
Generator
Dispatch
Generator
Dispatch
Generator
Savings
Benefit
Savings
Benefit
Savings
Benefit
Savings
Benefit
Savings
Benefit
$26,816
$0
($84,285)
$1,660
$121,281
$178
($62,787)
$995
$1,026
$2,833
($50,481)
$46
($55,593)
$795
$20,157
$737
$26,469
$687
($59,448)
$2,265
$0
$0
$0
$0
$22,368
$1,162
$7,855
$19
$30,223
$1,181
$0
$0
$9,661
$153
$0
$0
$0
$0
$9,661
$153
$15,086
$14
$407,234
$5,369
$91,202
$439
$12,714
$255
$526,236
$6,078
($6,526)
$13
$219,287
$4,536
$43,032
$482
$34,834
$626
$290,626
$5,657
$61,274
$768
$350,629
$2,257
($9,832)
$144
$4,991
$227
$407,062
$3,396
$3,440
$10
$33,262
$299
($305)
($0)
$1,710
$2
$38,106
$310
$0
$0
$0
$0
$0
$0
$0
$0
$0
$0
($31,041)
$118
$1,285,885
$35,938
$153,292
$4,719
$91,133
$5,409
$1,499,270
$46,184
$6,110
$164 ($1,108,130)
$8,502
$175,993
$2,719
($184,207)
$8,841
($1,110,234)
$20,227
($4,562)
$64
$77,023
$13,313
$25,172
$4,242
$14,246
$271
$111,879
$17,890
$107,127
$416
($31,562)
$9,625
($90,836)
$2,404
($308,323)
$4,479
($323,593)
$16,925
$29,729
$14
$547,166
$14,340
$17,106
$365
$0
$0
$594,001
$14,719
$31,804
$7
$36,370
$1,931
$19,660
$111
$32,828
$1,028
$120,662
$3,077
($12,702)
$1,827
($270,480)
$29,555
($377,007)
$97,836
($20,476)
$3,634
($680,665)
$132,852
$3,900
$0
$0
$0
$25,295
$323
$45,013
$0
$74,208
$323
($587,280)
$16,654 ($8,672,747)
$172,681
($2,106,032)
$48,783
($1,412,794)
$20,211 ($12,778,853)
$258,329
$0
$0
($921,979)
$61,039
$0
$0
$0
$0
($921,979)
$61,039
$151,204
$1,614
$7,609,257
$197,211
$1,213,791
$54,723
$578,116
$36,444
$9,552,368
$289,993
($110,987)
$900 ($1,211,093)
$29,065
($332,232)
$5,751
($373,940)
$9,785
($2,028,253)
$45,502
$0
$0
$0
$0
$0
$0
$0
$0
0
$0
($367,089)
$22,632
($1,780,094)
$588,269
($987,896)
$225,120
($1,512,616)
$92,912
($4,647,695)
$928,933
AECI
IOWA
MAINS
NEBR
EES
EESIPP
$35,985
($42,664)
$75,236
$0
$384,823
$114,853
$59
$429
$319
$0
$578
$1,560
$247,653
($100,850)
$686,813
($142,538)
$1,559,087
($331,166)
$3,450
$502
$2,069
$6,235
$9,032
$2,030
$41,168
($20,154)
$26,657
($157,975)
$711,563
$466,756
$177
$1,310
$1,211
$5,764
$5,747
$1,833
$174,942
($31,769)
$263,782
($9,005)
$775,675
($62,984)
$1,146
$1,013
$603
$4,135
$2,830
$171
$499,748
($195,437)
$1,052,488
($309,518)
$3,431,148
$187,459
$4,832
$3,255
$4,202
$16,134
$18,187
$5,594
Subtotals
$568,233
$2,945
$1,918,999
$23,320
$1,068,015
$16,042
$9,898
$4,665,887
$52,205
Totals
$201,144
$25,577
$138,905
$611,589
$80,119
$241,162
$102,810
$18,192
$981,138
Violation
Savings
$67,463
$4,024,840
$622,554
27
$1,110,640
($401,976)
$360,581
$5,075,438
Kansas Electric Transmission Authority (KETA) Study
2020 - Spearville - Knoll - Axtell 345 kV
Area
CELE
EMDE
GRDA
INDN
KACP
KACY
LAFA
LEPA
MIDW
MIPU
OKGE
OMPA
AEPW
SPPIPP
SPRM
SUNC
SWPA
SPS
WEPL
WERE
WFEC
WINDSPP
Subtotals
Spring
Summer
Fall
Winter
Totals
Dispatch
Generator
Dispatch
Generator
Dispatch
Generator
Dispatch
Generator
Dispatch
Generator
Savings
Benefit
Savings
Benefit
Savings
Benefit
Savings
Benefit
Savings
Benefit
$89,702
($40)
$283,237
$1,711
$154,550
$663
$102,067
$1,159
$629,557
$3,492
($36,406)
$336
($54,356)
$3,194
$44,685
$686
$103,564
$608
$57,487
$4,824
$0
$0
$0
$0
$32,123
$1,626
$7,855
$50
$39,978
$1,676
$0
$0
$34,824
$546
$0
$0
$0
$0
$34,824
$546
$11,209
$29
$182,966
$7,199
$72,976
$585
$27,890
$794
$295,040
$8,607
$551
$3
$245,068
$4,736
$36,338
$406
$17,363
$256
$299,320
$5,401
$61,145
$654
$700,841
$3,051
($25,328)
$146
$25,481
$273
$762,139
$4,123
$4,419
$12
$65,599
$438
($305)
($0)
$6,420
$28
$76,133
$478
$0
$0
$0
$0
$0
$0
$0
$0
$0
$0
$4,475
($8) $1,671,264
$41,187
$138,950
$3,675
$352,854
$10,138
$2,167,542
$54,993
($4,011)
$80
($975,793)
$11,088
($124,711)
$1,723
($556,101)
$7,960
($1,660,616)
$20,851
$0
$0
$84,752
$5,124
$24,481
$622
($2,747)
$186
$106,486
$5,931
$61,321
$438
$14,789
$24,414
($144,551)
$2,937
($342,017)
$9,106
($410,458)
$36,895
$53,766
$125
$179,322
$20,035
($211,635)
$1,376
$0
$0
$21,452
$21,536
($20,468)
$6
$124,312
$2,524
$22,379
$230
$33,742
$900
$159,964
$3,660
($12,702)
$1,918
($297,771)
$30,630
($478,476)
$95,520
($21,317)
$3,962
($810,265)
$132,030
$0
$0
$0
$0
$30,899
$531
$0
$0
$30,899
$531
($487,332)
$10,128 ($10,332,512)
$229,318
($2,570,076)
$51,971
($2,521,250)
$28,723 ($15,911,170)
$320,141
$0
$0 ($1,416,717)
$124,665
$0
$0
($25,427)
$192
($1,442,144)
$124,857
($49,119)
$823
$4,898,958
$70,046
$1,060,476
$46,756
$544,360
$17,232
$6,454,674
$134,857
($111,896)
$540 ($1,482,506)
$41,504
($344,992)
$6,558
($683,011)
$15,031
($2,622,405)
$63,634
$0
$0
$0
$0
$0
$0
$0
$0
0
$0
($435,346)
$15,044
($6,073,725)
$621,409
($2,282,217)
AECI
IOWA
MAINS
NEBR
EES
EESIPP
$7,983
$50,396
$71,214
$0
$308,580
$145,335
$310
$412
$351
$0
$626
$1,474
$138,449
$991,166
$1,532,807
$1,239,609
$4,438,130
($107,743)
$4,733
$17,239
$11,389
$24,118
$15,682
$645
$70,634
$131,051
$26,815
$105,137
$1,905,558
$344,116
Subtotals
$583,508
$3,173
$8,232,418
$73,806
Totals
$148,163
$18,217
$2,158,693
$695,215
Violation
Savings
$534,380
($2,930,274)
$96,597
($11,721,562)
$949,062
$223
$2,503
$369
$5,988
$7,907
$2,083
$253,141
$223,996
$367,427
$336,690
$2,011,618
$100,297
$4,775
$3,262
$1,789
$7,405
$8,638
$728
$470,208
$1,396,610
$1,998,263
$1,681,436
$8,663,885
$482,005
$10,041
$23,415
$13,898
$37,510
$32,853
$4,931
$2,583,312
$19,073
$3,293,169
$26,596
$14,692,407
$122,648
$301,095
$235,084
$362,895
$123,193
$2,970,845
$1,071,710
$7,249,307
$216,011
$1,661,526
28
$1,452,452
$10,897,664
Kansas Electric Transmission Authority (KETA) Study
2020 - Summit - Concordia - Pauline 345 kV
Area
CELE
EMDE
GRDA
INDN
KACP
KACY
LAFA
LEPA
MIDW
MIPU
OKGE
OMPA
AEPW
SPPIPP
SPRM
SUNC
SWPA
SPS
WEPL
WERE
WFEC
WINDSPP
Subtotals
AECI
IOWA
MAINS
NEBR
EES
EESIPP
Subtotals
Totals
Violation
Savings
Spring
Summer
Fall
Winter
Totals
Dispatch
Generator
Dispatch
Generator
Dispatch
Generator
Dispatch
Generator
Dispatch
Generator
Savings
Benefit
Savings
Benefit
Savings
Benefit
Savings
Benefit
Savings
Benefit
$125,950
$118
$289,552
$547
$104,031
$78
($78,041)
$314
$441,491
$1,056
($43,522)
$595
$16,265
$1,105
($4,065)
$33
($14,214)
$592
($45,536)
$2,325
$0
$0
$0
$0
$1,302
$0
($18,933)
$0
($17,631)
$0
$0
$0
($6,178)
$14
$0
$0
$0
$0
($6,178)
$14
$850
($0)
($281,886)
$2,843
$5,240
$99
$6,029
$251
($269,768)
$3,193
$7,843
$1
($228,375)
$2,070
($5,937)
$65
($40,773)
$832
($267,242)
$2,968
($9,154)
($72)
$262,754
$121
($34,356)
$99
($33,318)
$2
$185,925
$151
($1,441)
($0)
$46,034
$119
$0
$0
($0)
($0)
$44,593
$119
$0
$0
$0
$0
$0
$0
$0
$0
$0
$0
($41,004)
$117
($141,528)
$6,011
($13,765)
$116
($87,065)
$3,571
($283,362)
$9,815
$2,872
$0
($660,980)
$3,620
($23,135)
$425
($268,872)
$2,932
($950,115)
$6,977
$0
$0
($52,420)
$5,560
($7,227)
$254
$22,672
$2,783
($36,974)
$8,596
$12,498
$71
$16,986
$2,286
($151,732)
$582
($314,560)
$4,223
($436,809)
$7,161
$3,662
($0)
($659,199)
$3,866
($134,677)
$185
$0
$0
($790,214)
$4,051
($32,940)
$78
$19,792
$155
($36,440)
$5
$2,052
$30
($47,536)
$268
$1,758
$0
$104,472
($703)
($62,956)
$2,708
$60,436
$67
$103,711
$2,073
$0
$0
$0
$0
$0
$0
$0
$0
$0
$0
$55,967
$542
$1,102,837
$9,064
$6,011
$22
$93,601
$2,278
$1,258,416
$11,906
$0
$0
($14,219)
$158
$0
$0
($38,588)
$1,404
($52,807)
$1,562
($194,050)
$3,162 ($2,558,089)
$32,238
($173,704)
$678
($388,966)
$7,269
($3,314,808)
$43,348
$19,475
$21
($17,874)
$2,408
($48,589)
$491
$114,303
$2,155
$67,314
$5,074
$0
$0
$0
$0
$0
$0
$0
$0
0
$0
($91,237)
$4,632
($2,762,057)
$71,482
($580,000)
$5,842
($984,236)
$28,702
($4,417,530)
$110,658
$10,968
$46,045
$3,629
$0
$45,009
$69,253
$8
$460
$149
$0
($12)
$208
($110,916)
$825,563
$274,346
$979,749
$1,448,243
$78,012
$7,274
$14,643
$2,383
$16,815
$2,971
$538
$14,886
$119,464
($18,172)
$220,675
$76,247
$48,832
$159
$1,325
$545
$4,046
$346
$103
$121,001
$231,983
$141,219
$324,311
$312,149
$25,861
$8,299
$1,532
$434
$5,049
$2,447
$402
$35,939
$1,223,054
$401,022
$1,524,734
$1,881,649
$221,959
$15,739
$17,960
$3,511
$25,910
$5,751
$1,251
$174,904
$812
$3,494,997
$44,624
$461,932
$6,524
$1,156,525
$18,162
$5,288,357
$70,122
$83,666
$5,443
$732,941
$116,106
($118,068)
$12,366
$172,288
$46,864
$870,827
$180,780
$694,074
$2,637,138
$971,112
29
$582,418
$4,884,743
Kansas Electric Transmission Authority (KETA) Study
2020 - Mooreland - Wichita 345 kV
Area
CELE
EMDE
GRDA
INDN
KACP
KACY
LAFA
LEPA
MIDW
MIPU
OKGE
OMPA
AEPW
SPPIPP
SPRM
SUNC
SWPA
SPS
WEPL
WERE
WFEC
WINDSPP
Subtotals
Spring
Summer
Fall
Winter
Totals
Dispatch
Generator
Dispatch
Generator
Dispatch
Generator
Dispatch
Generator
Dispatch
Generator
Savings
Benefit
Savings
Benefit
Savings
Benefit
Savings
Benefit
Savings
Benefit
$23,242
$5
($331,370)
$1,846
$72,897
$64
$93,090
$407
($142,140)
$2,321
($48,707)
$38
$575
$204
$5,411
$43
$130,579
$331
$87,858
$616
$0
$0
$0
$0
$9,102
$0
$7,855
$16
$16,956
$17
$0
$0
$9,783
$104
$0
$0
$0
$0
$9,783
$104
$6,314
$2
$466,613
$4,450
$27,034
$20
$13,298
$299
$513,259
$4,770
($637)
($0)
$125,510
$1,010
$34,607
$114
$31,676
$342
$191,158
$1,466
$61,234
$742
($29,239)
$215
($14,227)
$6
($35,535)
$190
($17,767)
$1,153
$3,543
$12
($6,764)
$21
$1,322
($0)
$1,710
$7
($188)
$40
$0
$0
$0
$0
$0
$0
$0
$0
$0
$0
$4,117
$22
$560,959
$4,484
$25,528
$63
$92,028
$3,222
$682,633
$7,791
$7,693
$0 ($2,156,733)
$9,573
($119,858)
$553
($390,725)
$6,870
($2,659,623)
$16,996
($4,562)
$40
$40,387
$13,653
$23,028
$1,295
($22,330)
$3,572
$36,523
$18,560
$60,065
$154
($636,537)
$8,468
($32,914)
$812
($36,262)
$3,804
($645,648)
$13,237
$5,120
$14
($53,544)
$10,077
$98
$316
$0
$0
($48,325)
$10,407
($41,411)
$29
$22,088
$765
($17,237)
$55
$36,054
$1,592
($505)
$2,441
($12,702)
$1,836
($77,373)
$1,492
($141,768)
$3,067
($21,803)
$3,632
($253,646)
$10,028
$0
$0
$0
$0
$25,276
$67
$66,048
$1,202
$91,324
$1,269
($362,339)
$7,376 ($3,729,011)
$39,891
($430,900)
$12,497
($1,244,547)
$13,996
($5,766,798)
$73,760
$0
$0
$51,201
$1,671
$0
$0
$0
$0
$51,201
$1,671
$86,042
$1,020
$5,142,227
$85,189
$199,816
$4,156
$419,038
$32,281
$5,847,122
$122,646
($102,103)
$1,109
($547,263)
$14,142
($159,278)
$3,306
($183,690)
$7,072
($992,334)
$25,629
$0
$0
$0
$0
$0
$0
$0
$0
0
$0
($315,091)
$12,399
($1,148,489)
$197,256
($492,063)
AECI
IOWA
MAINS
NEBR
EES
EESIPP
$15,903
($9,250)
$57,769
$0
$370,789
$7,971
$66
$63
$177
$0
$140
$1,494
$236,723
($7,333)
$631,257
$32,227
$222,297
$28,786
$1,532
$348
$2,250
$3,648
$3,363
$1,758
$58,749
$27,448
$37,023
($65,789)
$579,412
$207,306
Subtotals
$443,182
$1,940
$12,899
$844,149
Totals
$128,091
$14,340
$210,155
$352,087
Violation
Savings
($503,059)
$1,143,956
($4,533)
$1,864,238
$26,433
$78,835
($2,999,158)
$151,478
$104,433
$293,959
$62,161
$496,116
$232,992
$1,933
$2,130
$1,161
$4,077
$3,346
$781
$462,853
$115,297
$1,020,007
$28,599
$1,668,614
$477,055
$3,633
$2,594
$3,725
$8,559
$7,233
$3,958
$1,435
$1,341,139
$13,427
$3,772,426
$29,701
$27,868
$297,623
$92,262
$773,268
$344,625
$101
$53
$137
$834
$384
($75)
$1,203,526
30
($1,043,516)
$1,327,445
$314,923
$3,892,149
Kansas Electric Transmission Authority (KETA) Study
B. High Fuel Pricing
Listed below are the fuel assumptions for the High Fuel scenario used in the KETA Study. A
$1.50/MMBtu adder was included for each hour. Additionally, since the run was for 2010
Summer, a 2.5% inflation rate was assumed by the program to create 2010 numbers per the
tables below.
Henry Hub
Distillate FO#2
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
Average
6.88
8.60
8.56
8.38
8.11
7.97
7.97
8.00
8.02
8.00
8.03
8.31
8.55
8.78
8.74
8.55
8.28
8.13
8.13
8.16
8.18
8.16
8.20
8.48
8.73
8.38
Residual FO#6
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
Average
9.55
11.36
11.31
11.05
10.69
10.49
10.49
10.52
10.56
10.52
10.58
10.96
11.29
11.61
11.55
11.29
10.92
10.71
10.71
10.75
10.79
10.75
10.80
11.20
11.54
11.05
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
Average
The follow pages show the fuel cost from the tables above in graphical format.
31
6.15
7.85
7.81
7.65
7.41
7.28
7.28
7.31
7.33
7.31
7.34
7.59
7.80
8.01
7.97
7.80
7.56
7.43
7.43
7.45
7.48
7.45
7.49
7.74
7.96
7.65
Kansas Electric Transmission Authority (KETA) Study
Distillate FO#2
$14.00
$10.00
$8.00
Base
$6.00
High
$4.00
$2.00
Date
32
De
c -0
7
No
v -0
7
Oc
t-0
7
Se
p -0
7
Au
g -0
7
J ul
-07
J un
-0 7
Ma
y -0
7
Ap
r-0
7
Ma
r-0
7
Fe
b-0
7
$J an
-0 7
Price (In Dollars)
$12.00
Kansas Electric Transmission Authority (KETA) Study
Distillate FO#2
$14.00
$10.00
$8.00
Base
$6.00
High
$4.00
$2.00
Date
33
De
c -0
7
No
v -0
7
Oc
t-0
7
Se
p -0
7
Au
g -0
7
J ul
-07
J un
-0 7
Ma
y -0
7
Ap
r-0
7
Ma
r-0
7
Fe
b-0
7
$J an
-0 7
Price (In Dollars)
$12.00
Date
34
De
c -0
7
No
v -0
7
Oc
t-0
7
Se
p -0
7
Au
g -0
7
J ul
-07
J un
-0 7
Ma
y -0
7
Ap
r-0
7
Ma
r-0
7
Fe
b-0
7
J an
-0 7
Price (In Dollars)
Kansas Electric Transmission Authority (KETA) Study
Residual FO#6
9
8
7
6
5
Series1
4
Series2
3
2
1
0
Kansas Electric Transmission Authority (KETA) Study
C. MUST Solution Settings
MUST CHOICES IN RUNNING FCITC DC ANALYSIS
CONSTRAINTS/CONTINGENCY INPUT OPTIONS
1. AC Mismatch Tolerance – 2 MW
2. Base Case Rating – Rate A
3. Base Case % of Rating – 100%
4. Contingency Case Rating – Rate B
5. Contingency Case % of Rating – 100%
6. Base Case Load Flow – PSS/E
7. Convert branch ratings to estimated MW ratings – Yes
8. Contingency ID Reporting – Labels
9. Maximum number of contingencies to process – 50000
MUST CALCULATION OPTIONS
1. Phase Shifters Model for DC Linear Analysis – Constant flow for Base Case and
Contingencies
2. Report Base Case Violations with FCITC – Yes
3. Maximum number of violations to report in FCITC table – 50000
4. Distribution Factor (OTDF and PTDF) Cutoff – 0.03
5. Maximum times to report the same elements – 1
{eliminate voluminous repeats}
6. Apply Distribution Factor to Contingency Analysis – Yes
7. Apply Distribution Factor to FCITC Reports – Yes
8. Minimum Contingency Case flow change – 1 MW
9. Minimum Contingency Case Distribution Factor change – 0.0
10. Minimum Distribution Factor for Transfer Sensitivity Analysis – 0.0
35
Kansas Electric Transmission Authority (KETA) Study
D. Economic Model Options
1. Modeling Footprint
The diagram below demonstrates the economic modeling footprint. This footprint details both
the unit commitment in PROSYM as well as the AC OPF powerflow simulation boundaries.
PROSYM
Hourly
Simulation
Boundary
1st Tier
OPF/SCED
Modeling
Boundary
SPP
OPF/SCED
Modeling
Boundary
2. Violation Cost
The table below demonstrates the violation cost assumptions in the study. For an operational
flowgate, $100 per MW hour is applied between 0-2% loading and $200 per MW hour for
anything greater. Branch or Transformer (as well as new potential constraints) are priced at $30
per MW hour for anything above normal rated capacity.
Type of Element
SPP Flowgate
Branch or Transformer
Operating Range
Penalty
0-2% Above Total Capacity
$100 per MW per Hour
>2% Above Total Capacity
$200 per MW per Hour
Above Normal Rated Capacity
$30 per MW per Hour
36
Kansas Electric Transmission Authority (KETA) Study
3. Hurdle Rates
The following table shows the modeling assumptions for hurdle rates. The model assumes
different hurdle rate values for commitment and dispatch. These are shown below.
Commitment
Hurdle Rates
$4 to $5/MWh
$6 to $8/MWh
Between Zones Authorities
SPP Zones
SPP and Non-SPP Zones
Dispatch
Hurdle Rates
$2/MWh
$2 to $5/MWh
4. Generator Benefit Equation


  MW x Nodal price    Pr oduction cost 
F
All GenUnits
Hours foreachParticipant
The equation listed above is what SPP uses to define the term “Generator Benefit.” ∆MW is the
change in MW for a generating unit between the upgrade case option and the base case. Nodal
Price is the $/MWh locational price at each generator in the upgrade case solution. ∆Production
cost in this equation is the fuel cost at each generator for that hour. This equation is being
applied for all generating units, for all hours, in cases that have successful solutions in both the
base and change case for that hour.
37
Kansas Electric Transmission Authority (KETA) Study
5. Wind Profiles
Wind Profiles (MW)
0.7
January
0.6
February
March
April
May
June
0.5
0.4
0.3
July
August
0.2
September
October
0.1
November
December
Hour
38
hr24
hr23
hr22
hr21
hr20
hr19
hr18
hr17
hr16
hr15
hr14
hr13
hr12
hr11
hr10
hr9
hr8
hr7
hr6
hr5
hr4
hr3
hr2
0
hr1
% of Max Output
0.8
Kansas Electric Transmission Authority (KETA) Study
6. PowerWorld Simulator Solution Options
1. MVA Convergence Tolerance – 2.0
2. Max Number of Iterations – 250
3. Initialize from Flat Start – No
4. Disable Power Flow Optimal Multiplier – No
5. Enforce Generator MW Limits – Yes
6. Disable Automatic Generation Control (AGC) – No
7. Include Loss Penalty Factors in ED – No
8. Enforce Convex Cost Curves in ED – No
9. Disable Checking Gen VAR Limits – No
10. Check Immediately – No
11. Disable Switched Shunt (SS) Control – No
12. Disable LTC Transformer Control – No
13. Min Sensitivity for LTC Control – 0.05
14. Disable Phase Shifter Control – No
15. Prevent Controller Oscillations – Yes
16. Maximum Number Controller Loop Iterations – 20
17. Min. pu volt. For constant power load – 0.8
18. Disable Angle Rotation Processing – No
39