Cheyenne Light, Fuel and Power Transmission System Impact ... · Cheyenne Light, Fuel and Power Transmission System Impact Study CLPT-G7 102 MW Wind Plant near the Corlett 115 kV

Cheyenne Light, Fuel and Power Transmission System Impact Study CLPT-G7 102 MW Wind Plant near the Corlett 115 kV Substation

Agreement No. 35983

Laramie County, Wyoming October 25, 2016


October 25, 2016 | i

Contents

1 Executive Summary ............................................................................................................................ 1

2 Background ......................................................................................................................................... 3

3 Definitions ............................................................................................................................................ 3 3.1 Interconnection Customer’s Interconnection Facilities .............................................................. 3 3.2 Transmission Provider’s Interconnection Facilities ................................................................... 3 3.3 Network Upgrades ..................................................................................................................... 3 3.4 Point of Change of Ownership .................................................................................................. 4 3.5 Point of Interconnection............................................................................................................. 4 3.6 Transmission Provider’s Interconnection Facilities ................................................................... 4

4 Study Inputs and Assumptions ............................................................................................................ 4 4.1 Facility Ratings .......................................................................................................................... 4 4.2 Facility Status or Changes ........................................................................................................ 4

5 Project Approach ................................................................................................................................. 5 5.1 Studies to be Performed............................................................................................................ 5 5.2 Assumptions and Modeling ....................................................................................................... 5 5.3 Requested Project Assumptions ............................................................................................... 0 5.4 Load Assumptions ..................................................................................................................... 0 5.5 Generation and Intertie Flow Assumptions ............................................................................... 1

5.5.1 2018HS Scenario ......................................................................................................... 1 5.5.2 2023HS Scenario ......................................................................................................... 1

5.6 Facility Ratings .......................................................................................................................... 3 5.7 Shunt Elements ......................................................................................................................... 3 5.8 Facility Assumptions .................................................................................................................. 3 5.9 Monitored Study Area ................................................................................................................ 4 5.10 Power Flow Contingencies ........................................................................................................ 4 5.11 Short Circuit Analysis ................................................................................................................ 4

6 Criteria ................................................................................................................................................. 5

7 Methodology ........................................................................................................................................ 5 7.1 Power Flow Analysis ................................................................................................................. 5 7.2 Transient Stability Analysis ....................................................................................................... 6

8 Examination of Results ........................................................................................................................ 8 8.1 Voltage Issues ........................................................................................................................... 8 8.2 2018 Summer Peak Thermal Results ....................................................................................... 8 8.3 2023 Summer Peak Thermal Results ....................................................................................... 8 8.4 Unsolved Contingencies in Steady State Analysis ................................................................... 9 8.5 Reactive Power Requirement ................................................................................................... 9 8.6 Transient Stability Analysis Results ........................................................................................ 10

9 Conclusions ....................................................................................................................................... 11 9.1 Interconnection Customer Interconnection Facilities .............................................................. 12


9.2 Transmission Provider Interconnection Facilities .................................................................... 12 9.3 Network Upgrades ................................................................................................................... 12

Appendix A: Thermal Results...................................................................................................................... 15

Appendix B: Simulated Contingencies ........................................................................................................ 19

Appendix C: Transient Stability Results ...................................................................................................... 32

Tables

Table 1: TOT3 MW Flow (North-to-South Flow) ........................................................................................... 0 Table 2: Generation for Modeled Cases (MW) ............................................................................................. 2 Table 3: Simulated Transient Stability Disturbances .................................................................................... 7 Table 4: Overloads in 2023 Summer Peak Sensitivity Cases ...................................................................... 9 Table 5: Network Upgrades ........................................................................................................................ 13


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1 Executive Summary Black Hills Corporation tasked HDR with analyzing the system impact on the Cheyenne Light, Fuel and Power (CLFP) electric transmission system from the interconnection of a wind powered generation facility with a maximum output of 102 MW, at a requested Point of Interconnection (POI) bisecting the Swan Ranch-King Ranch 115 kV line near the CLFP Corlett 115 kV substation. This analysis evaluates the new wind generation as both a network resource and an energy only resource.

This study evaluated a valid request from an Interconnection Customer (IC) to provide interconnection service for a proposed generation facility under the guidance of the Cheyenne Light Power Transmission (CLPT) OATT Large Generator Interconnection Procedures (LGIP). This interconnection, CLPT-G7, is located in the CLFP service territory near Cheyenne, WY. The requested commercial operation date is December 31, 2017. A 2020 high-summer load Colorado Coordinated Planning Group (CCPG) case, which originated from the WECC 2020HS2 series model, was modified to create the 2018 and the 2023 cases for the summer peak evaluation. The CLFP system load for the 2018 and the 2023 study scenarios were adjusted per 2016 Load Forecast. Facility assumptions in the CLFP’s 10-Year Transmission Plan were included in the 2018 and 2023 study scenarios. Figure 1 below shows the 2018 CLPT-G7 plant and interconnection details superimposed upon maps of the area.

ARCHER

WARREN AFB

CHEYENNECROW CREEK

HILLTOP

SKYLINE

HAPPY JACK

CORLETT

TO SNOWY RANGE

TO PONNEQUINN

TO GEM CITY

TO MYERS

TAP

TO PINE BLUFFS

TO STEGALL

TO AULT

NORTH RANGE

SWAN RANCH

EAST BUSINESS

PARK SUB

TO NORTHPARK

SOUTH CHEYENNE

CHEYENNE PRAIRIE

GENERATION

MICROSOFT

TERRY RANCH

KING RANCH

OWNERSHIP LEGEND

CLF&P 115 kVWAPA 230 kVWAPA 115 kVPLANNED, IN BASE CASEPLANNED, NOT IN BASE CASE

FACILITIES ASSOCIATED W/

CLPT-G7

Line rebuild

Line rebuild

New T-lines

W.CHEY

CLPT-G7

Figure 1: 2018HS CLPT-G7 Project Layout Relative to the POI


The 2023 heavy summer peak model was run to evaluate the impact of a prior queued generation interconnection and the Tri-State Wayne Child Phase II project. That interconnection is the CLPT-G6, located at the Cheyenne Prairie Generation bus. Figure 2 below shows the 2023 CLPT-G7 plant and interconnection details superimposed upon maps of the area.

ARCHER

WARREN AFB

CHEYENNECROW CREEK

HILLTOP

SKYLINE

HAPPY JACK

CORLETT

TO SNOWY RANGE

TO PONNEQUINN

TO GEM CITY

TO MYERS

TAP

TO PINE BLUFFS

TO STEGALL

TO AULT

NORTH RANGE

SWAN RANCH

EAST BUSINESS

PARK SUB

TO NORTHPARK

SOUTH CHEYENNE

CHEYENNE PRAIRIE

GENERATION

MICROSOFT

TERRY RANCH

KING RANCH

OWNERSHIP LEGEND

CLF&P 115 kVWAPA 230 kVWAPA 115 kVPLANNED, IN BASE CASEPLANNED, NOT IN BASE CASE

FACILITIES ASSOCIATED W/

CLPT-G7

W.CHEY

CLPT-G7

Figure 2: 2023HS CLPT-G7 Project Layout Relative to the POI

System intact loading, with the new generation at 102 MW, produced no branch overloads in the power flow models examined. The sensitivity case, which includes the CLPT-G6 generation, Tri-State Wayne Child Phase II project, as well as the CLPT-G7 generation, also produced no branch overloads.

This analysis includes a review of the reactive power requirement to maintain a composite power delivery within a power factor range of 0.95 leading to 0.95 lagging across the entire range of continuous real power output levels at the high-side of the generator substation. The results show no additional reactive power support will be needed for interconnection of CLPT-G7.

Appendix B lists the contingencies performed on all the cases. Post contingent overloads with > 2% distribution factor were encountered and are included as Appendix A. Changes in voltage drops of more than 1% were not encountered in the post contingent base case voltages verses the post contingent change cases.


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The CLPT-G7 generation project can be interconnected following network upgrades at an estimated cost of $4,087,000. The lead time for implementing the required upgrades is 18 to 24 months.

2 Background The CLPT-G7 interconnection represents a moderate increase in the generation capacity in the area. The proposed project consists of a wind turbine facility with a maximum output of 102 MW at a POI bisecting the Swan Ranch-King Ranch 115 kV line near the Corlett 115 kV substation.

3 Definitions This section includes definitions from the Transmission Provider’s Open Access Transmission Tariff (OATT) and pertains to terms used in this report.

3.1 Interconnection Customer’s Interconnection Facilities Interconnection Customer’s Interconnection Facilities shall mean all facilities and equipment, as identified in Appendix A of the Standard Large Generator Interconnection Agreement, that are located between the Generating Facility and the Point of Change of Ownership, including any modification, addition, or upgrades to such facilities and equipment necessary to physically and electrically interconnect the Generating Facility to the Transmission Provider’s Transmission System. Interconnection Customer’s Interconnection Facilities are sole use facilities.

3.2 Transmission Provider’s Interconnection Facilities Transmission Provider’s Interconnection Facilities shall mean all facilities and equipment owned, controlled or operated by the Transmission Provider from the Point of Change of Ownership to the Point of Interconnection as identified in Appendix A to the Standard Large Generator Interconnection Agreement, including any modifications, additions or upgrades to such facilities and equipment. Transmission Provider’s Interconnection Facilities are sole use facilities.

3.3 Network Upgrades Network Upgrades shall mean the additions, modifications, and upgrades to the Transmission Provider’s Transmission System required at or beyond the point at which the Interconnection Facilities connect to the Transmission Provider’s Transmission System to accommodate the interconnection of the Large Generating Facility to the Transmission Provider’s Transmission System.


3.4 Point of Change of Ownership Point of Change of Ownership shall mean the point, as set forth in Appendix A to the Standard Large Generator Interconnection Agreement, where the Interconnection Customer’s Interconnection Facilities connect to the Transmission Provider’s Interconnection Facilities.

3.5 Point of Interconnection Point of Interconnection shall mean the point, as set forth in Appendix A to the Standard Large Generator Interconnection Agreement, where the Interconnection Facilities connect to the Transmission Provider’s Transmission System.

3.6 Transmission Provider’s Interconnection Facilities Transmission Provider’s Interconnection Facilities shall mean all facilities and equipment owned, controlled or operated by the Transmission Provider from the Point of Change of Ownership to the Point of Interconnection as identified in Appendix A to the Standard Large Generator Interconnection Agreement, including any modifications, additions or upgrades to such facilities and equipment. Transmission Provider’s Interconnection Facilities are sole use facilities and shall not include Distribution Upgrades, Stand Alone Network Upgrades or Network Upgrades.

4 Study Inputs and Assumptions 4.1 Facility Ratings

For new transmission facilities needed, the assumed design parameters are:

• 115 kV lines are constructed using conductor type 795 45/7 ACSR (Tern) with a summer rating of 213 MVA at 100° C and 267 MVA winter rating, and

• 230 kV lines are constructed using conductor type 1272 45/7 ACSR (Bittern) with a summer rating of 573 MVA at 100° C and 637 MVA winter rating.

Note: the CLPT-G7 115 kV generator tie line to the POI was assumed to be 795 ACSR conductor. The point of interconnection into the existing transmission line back to the new Cheyenne West substation, a double circuit 115 kV line was assumed to be 795 ACSR conductor.

4.2 Facility Status or Changes • Power-flow simulations were performed with a base case that had CLPT-G7 in the

model, but not in service. Comparisons were made by turning CLPT-G7 on, and dispatching the 102 MW as a Network Resource (NR1) against the Wygen units.

• Power-flow simulations were performed with a base case that had CLPT-G7 in the model, but not in service. Comparisons were made by turning CLPT-G7 on, and


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dispatching the 102 MW as a Network Resource (NR2) against the Cheyenne Prairie units and Wygen 1 unit.

• A case was created to dispatch CLPT-G7 as an Energy Resource (ER). For this case, off-system resources at Dave Johnston #4, in central Wyoming, were used to offset the new CLPT-G7 102 MW generation.

• An additional set of cases were created to test sensitivity to other proposed projects in the area, such as the prior queued project CLPT-G6, located at the Cheyenne Prairie Generating Station and the Tri-State Wayne Child Phase II project. These cases were modeled with projects at full output, creating a new base case, and then testing that against the change case with the proposed CLPT-G7 in service as both a NR and ER.

5 Project Approach 5.1 Studies to be Performed

The analysis performed to evaluate the proposed project is:

• Power Flow Analysis (Category P0, P1, P4, P6, and P7).

o Includes verification that reactive power requirements are met.

• Transient stability analysis (Category P0, P1, P4, P6, and P7).

The analysis excluded the following for the proposed project:

• Power flow (Category D) is not a deciding factor in this selection process.

• Voltage stability (PV) analysis.

• Short circuit analysis was performed as part of the Feasibility Study.

5.2 Assumptions and Modeling The study timeframe for the CLPT-G7 interconnection is the summer of 2018. The 2020 CCPG high-summer-load case that originated from the WECC 2020HS2 case, was used for the summer peak evaluation, and was modified as listed in Section 5.3 to reflect the appropriate scenarios.

The WECC TOT3 (Path 36) was considered relevant to this study. Table 1 below, shows the flow of the TOT3 facilities for the cases studied.


Table 1: TOT3 MW Flow (North-to-South Flow)

Facility

2018HS

(Without C

LPT-G7)

2018HS

(With C

LPT-G7 as N

R1)

2018HS

(With C

LPT-G7 as N

R2)

2018HS

(With C

LPT-G7 as ER

)

2023HS

(Without C

LPT-G7)

2023HS

(With C

LPT-G7 as N

R1)

2023HS

(With C

LPT-G7 as N

R2)

2023HS

(With C

LPT-G7 as ER

)

Archer - Ault 230kV 108.1 120 107 120.5 186 192 186 192

LRS - Ault 345kV 641.5 623.2 637.3 621 617.3 606 614.4 604 LRS - WL Child - ArcherTS 345kV 456 449.6 454.6 448 404.5 409 405 408.4

Terry Ranch - Ault 230kV 132.6 158.5 140.7 158.7 229 247.5 233 247.2

Cheyenne - Ponnequin 115kV 52.7 59.7 54.7 59.7 68.7 74.6 71 74.5

Sidney - Peetz 115kV 66.1 65.8 66 65.9 76 75.2 76 75.2

Sidney - Spring Canyon 230kV 143 141.3 142.2 141.5 168.5 165.7 168 165.8

TOT3 Flow (N-S) 1600 1618 1603 1615 1750 1770 1753 1767

Power flow simulations were solved without area interchange.

5.3 Requested Project Assumptions The scope of work prepared by Black Hills Corporation provided the following project assumptions:

• The project consists of GE 2.0 MW Wind Turbine Generators (WTGs) including WindFREE Reactive Power technology.

• The station transformer high side tap is set to 117.875 kV.

• The facility is set to regulate the 115 kV system voltage at the collector substation to 1.01 per unit.

• The 115 kV generator tie line is assumed to be 795 ACSR conductor, resulting in a continuous and emergency rating of 213 MVA from the point of interconnection back to the collector substation.

• The point of interconnection into the existing transmission line back to the new Cheyenne West substation will be a double circuit 115 kV line assuming 795 ACSR, resulting in a continuous and emergency rating of 213 MVA per circuit.

5.4 Load Assumptions The CLFP system load for the 2018 study scenario was scaled to 2018 peak summer levels (258 MW per 2016 Load Forecast).

The CLFP system load for the 2023 study scenario was scaled to 2023 peak summer levels (356 MW per 2016 Load Forecast).


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5.5 Generation and Intertie Flow Assumptions Generation in the base cases was dispatched using a typical value for the area generators. Refer to Table 2 below for specific generation dispatch levels for each study scenario.

The following assumptions were used in modeling the CLFP generation dispatch for each scenario:

5.5.1 2018HS Scenario The Cheyenne Prairie Generating Station (CPGS) is represented as a 40 MW simple cycle CT and a 100 MW combined cycle plant consisting of 2-40 MW CTs and 1-24.8 MW steam unit (gross). Net output is 140 MW, 81 MW of which is owned by CLFP. Other CLFP resources include 60 MW at Wygen1, 95 MW at Wygen2, and wind resources which include 10 MW at Silver Sage and 15 MW at Happy Jack.

The wind output at Happy Jack and Silver Sage was assumed to be 100%. The total CLFP resource mix for the 2018HS scenario is 261 MW.

• For the project as an NR1: Assuming the 258 MW CLFP system load and the proposed project at 102 MW output, CLFP’s portion of the Wygen1 and Wygen2 will be reduced to offset the addition of CLPT-G7.

• For the project as an NR2: Assuming the 258 MW CLFP system load and the proposed project at 102 MW output, CLFP’s portion of the Cheyenne Prairie and Wygen1 will be reduced to offset the addition of CLPT-G7.

• For the project as an ER: Off-system resources at the Dave Johnston #4 plant (65445) in central WY will be used to offset the addition of CLPT-G7.

TOT3 should be modeled at 1600 MW for the 2018 scenarios, prior to the addition of the CLPT-G7 project. Generation should not be re-dispatched to maintain TOT3 at 1600 MW following the addition of CLPT-G7.

5.5.2 2023HS Scenario Cheyenne Prairie Generating Station is represented as a 40 MW simple cycle CT and a 100 MW combined cycle plant consisting of 2-40 MW CTs and 1-24.8 MW steam unit (gross). Net output is 140 MW, 81 MW of which is owned by CLFP. Also included at CPGS is the CLPT-G6 interconnection project consisting of a 125 MW combined cycle plant consisting of 2-50 MW CTs and 1-24.8 MW steam unit (gross). Other CLFP resources include 60 MW at Wygen1, 95 MW at Wygen2, and wind resources which includes 10 MW at Silver Sage and 15 MW at Happy Jack.

The wind output at Happy Jack and Silver Sage was assumed to be 100%. The total CLFP resource mix for the 2023HS scenario is 386 MW.

• For the project as an NR1: Assuming the 356 MW CLFP system load and the proposed project at 102 MW output, CLFP’s portion of the Wygen1 and Wygen2 output will be reduced to offset the addition of CLPT-G7.


• For the project as an NR2: Assuming the 258 MW CLFP system load and the proposed project at 102 MW output, CLFP’s portion of the Cheyenne Prairie and Wygen1 will be reduced to offset the addition of CLPT-G7.

• For the project as an ER: Off-system resources at the Dave Johnston #4 plant (65445) in central WY will be used to offset the addition of CLPT-G7.

TOT3 should be modeled at 1750 MW for the 2023 scenarios, prior to the addition of the CLPT-G7 project. Generation should not be re-dispatched to maintain TOT3 at 1750 MW following the addition of CLPT-G7.

The Sidney and Stegall DC Ties can influence the results of the analysis, as can other regional generation dispatch conditions by way of TOT3 flow levels.

Table 2: Generation for Modeled Cases (MW)

2018HS

(Without C

LPT-G7)

2018HS

(With C

LPT-G7 as N

R1)

2018HS

(With C

LPT-G7 as N

R2)

2018HS

(With C

LPT-G7 as ER

)

2023HS

(Without C

LPT-G7)

2023HS

(With C

LPT-G7 as N

R1)

2023HS

(With C

LPT-G7 as N

R2)

2023HS

(With C

LPT-G7 as ER

)

CPGS Block 1 104.8 104.8 23.8 104.8 104.8 104.8 23.8 104.8

CPGS Block 2 40 40 40 40 40 40 40 40

CLPT-G6 0 0 0 0 124.8 124.8 124.8 124.8

CLPT-G7 0 102 102 102 0 102 102 102

Happy Jack Wind 28 28 28 28 28 28 28 28

Silver Sage Wind 40 40 40 40 40 40 40 40

LRS Unit #1 605 605 605 605 605 605 605 605

LRS Unit #2 605 605 605 605 605 605 605 605

Dave Johnston Unit #1 104 104 104 104 104 104 104 104




CPP (Brush) 69 69 69 69 69 69 69 69

Rawhide 478 478 478 478 493 493 493 493

Ponnequin Wind 6.3 6.3 6.3 6.3 6.3 6.3 6.3 6.3

Pawnee (net) 530 530 530 530 530 530 530 530

Manchief 200 200 200 200 140 140 140 140

RMEC 400 400 400 400 300 300 300 300

Craig 1366 1366 1366 1366 1366 1366 1366 1366

Hayden 463.5 463.5 463.5 463.5 463.5 463.5 463.5 463.5


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2018HS

(Without C

LPT-G7)

2018HS

(With C

LPT-G7 as N

R1)

2018HS

(With C

LPT-G7 as N

R2)

2018HS

(With C

LPT-G7 as ER

)

2023HS

(Without C

LPT-G7)

2023HS

(With C

LPT-G7 as N

R1)

2023HS

(With C

LPT-G7 as N

R2)

2023HS

(With C

LPT-G7 as ER

)

Spring Canyon Wind 12.6 12.6 12.6 12.6 12.6 12.6 12.6 12.6

Ridgecrest Wind 6.3 6.3 6.3 6.3 6.3 6.3 6.3 6.3

Peetz-Logan Wind 120.9 120.9 120.9 120.9 120.9 120.9 120.9 120.9

St. Vrain Unit #1 208 208 208 208 182 182 182 182

St. Vrain Unit #2 108 108 108 108 82 82 82 82

St. Vrain Unit #3 108 108 108 108 82 82 82 82

St. Vrain Unit #4 108 108 108 108 82 82 82 82

St. Vrain Unit #5 108 108 108 108 83 83 83 83

St. Vrain Unit #6 108 108 108 108 83 83 83 83

Wygen1 57 55 36 57 93 91 72 93

Wygen2 100 0 100 100 100 0 100 100

Rapid City DC Tie -130 -130 -130 -130 -130 -130 -130 -130

Stegall DC Tie 100 100 100 100 100 100 100 100

Sidney DC Tie 200 200 200 200 200 200 200 200

5.6 Facility Ratings Continuous and short-term facility ratings were observed as requested by the affected transmission owners throughout the analysis. CLFP observes Rate A for all events, with the exception of transformers, which have a 30-min rating of 125% of the continuous rating following contingencies. Delta-V changes of less than 1% from base-model to CLPT-G7 model were neglected. Distribution factors (DF) of less than 2% of CLPT-G7 output on any given branch were also neglected.

5.7 Shunt Elements All in-service and planned switched shunt elements were modeled in the case. Shunt devices that are automatically switched were be modeled as such and allowed to operate following contingencies. All manually switched shunt devices were allowed to switch prior to a disturbance and fixed at that pre-disturbance level following contingencies.

5.8 Facility Assumptions The following project assumptions in CLFP’s 10-Year Transmission Plan were applied to the 2018 scenario assessment:


• Archer-Cheyenne Prairie-East Business Park reconductor project is not complete,

• Cheyenne Prairie-South Cheyenne double circuit 115 kV line is not complete,

• King Ranch 115 kV substation is in-service,

• Swan Ranch 115 kV substation is in-service (all SR load fed from North Range),

• Happy Jack-North Range 115 kV rating upgrade is not complete, and

• 636 ACSR conductor on South Cheyenne-King Ranch line replaced with 795 ACSR.

The following project assumptions in CLFP’s 10-Year Transmission Plan were applied to the 2023 scenario assessment:

• Archer-Cheyenne Prairie-East Business Park reconductor project is complete,

• Cheyenne Prairie-South Cheyenne double circuit 115 kV line is complete,

• King Ranch 115 kV substation is in-service,

• Swan Ranch 115 kV substation is in-service, and

• Happy Jack-North Range 115 kV rating upgrade is complete.

• 636 ACSR conductor on South Cheyenne-King Ranch line replaced with 795 ACSR.

The Tri-State Wayne Child Phase II project was not modeled in the 2018 base case but was modeled online in the 2023 sensitivity cases to review the impacts of that system change planned for 2019.

5.9 Monitored Study Area The subsystem of interest for the analyses consists of all 115 kV and above buses in an area bound by Miracle Mile to the west, Dave Johnston to the north, Sidney to the east, and Ault to the south. All TOT3 elements will also be monitored.

5.10 Power Flow Contingencies The NERC Category P0, P1, P4, P6, and P7 events to be simulated, as part of the power flow analysis, were provided by Black Hills Engineering:

• Category P0 is system intact, so there are no required files, and

• Category P1, P4, P6, and P7 events were defined and provided.

The contingencies are listed in Appendix B: Simulated Contingencies.

5.11 Short Circuit Analysis Short circuit analysis was performed in the CLPT-G7 Feasibility Study, therefore, no short circuit analysis was performed for the System Impact Study.


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6 Criteria The "NERC TPL" Standards criteria regarding loss of load and system instability were observed in all cases. Additionally, the criteria specified in the “System Performance TPL-001- WECC-CRT-2.1 Regional Criterion” were observed. The minimum first-swing voltage for transient stability simulations in the study area is 0.70 per unit.

Relative steady state voltage change is limited to 3 percent, of the nominal voltage, for system intact condition simulations and 5 percent under outage conditions. The relative steady state voltage change is the difference in voltage before and after an event, such as capacitor switching, load switching, transmission line tripping or large motor starting.

For determination of the effect CLPT-G7 will have on voltage change (delta V), only degradation of the delta V was listed as a violation. For example, the delta V in some base case simulations was greater than 5%; so no remedy would be called out in the case of delta V being less than 7% in the base case and less than 6% in the change case. In this analysis, and for this example contingency, only a delta V greater than 7% with CLPT-G7 would be considered a violation.

The disturbances to be evaluated in the transient stability analysis are listed in section 7.2. The transient stability simulations will run to 10 seconds to ensure a sufficient damping response. All events assume a 3-phase fault with normal clearing. In the event that acceptable performance is not achieved, the reduced impedance single line – to – ground (SLG) fault should be applied as required in TPL-001-4.

The proposed project shall maintain a composite reactive power delivery at continuous rated power output at the generator substation high side at a power factor within the range of 0.95 leading to 0.95 lagging, across the range of near 0% to 100% of facility MW rating, with the magnitude of reactive power calculated on the basis of nominal POI voltage (1.0 p.u. V). The design shall consider the effects of step-up transformer reactance and voltage taps/turns ratios, and bus-fed auxiliary load. Based on the plant data supplied by the Interconnection Customer (IC), and the results of this analysis, the proposed project may need supplemental reactive voltage support equipment to meet these requirements.

If the TP requires additional reactive power support or voltage regulation to mitigate known system weaknesses, the TP will negotiate with the generator owner for any additional capability beyond the minimum requirements stated above.

7 Methodology 7.1 Power Flow Analysis

Examination of Table 2 above details how the area generation was dispatched for each case. The base case was built with the proposed CLPT-G7 project modeled, but off-line. Three additional cases were created with CLPT-G7 on line at 102 MW and dispatched against both Wygen units, when modeled as an NR1-, Cheyenne Prairie units and Wygen 1 unit, when modeled as an NR2, and Dave Johnson #4, when modeled as an ER. All the cases were subjected to outages as defined in the contingency file. The


results were compared between the base case and the cases where CLPT-G7 is in service for analysis. The results of the steady state analysis for this scenario are described in Section 8.

A set of 2023 summer peak cases were created to test system sensitivity with the prior queued project CLPT-G6, located at the Cheyenne Prairie Generating Station on line, and the Tri-State Wayne Child Phase II project. These sensitivity cases were created in the same manner as described above, and the results of the steady state analysis for this scenario are described in Section 8.

7.2 Transient Stability Analysis Transient stability is the ability of generators to remain in synchronism with one another by surviving the first swing of a disturbance such as a three phase fault or single line to ground (SLG) fault. Transient stability also simulates the ability of the power system to return to a steady-state equilibrium under small signal or large signal transient disturbances.

The purpose of this report is to present the results of the stability analysis performed to evaluate the impact of the proposed CLPT-G7 project on Black Hill’s transmission system dynamic performance.

Any stability modeling changes were coordinated with Black Hills. The following changes were made to the stability models:

• Changed CLPT-G7 generator model from REGCAU1 to GEWT. • Updated CLPT-G7 voltage regulated bus to the 115 kV bus at the collector

system. • Updated CLPT-G7 number of turbines from 50 to 51. • Updated Cheyenne Prairie (CLPT-G6) governor turbine MW rating from 46 MW

to 65.5 MW. • Turned off Belle Creek DVAR model per Black Hills Planning Engineers

recommendation because it was deemed as far enough away from the project area not to affect the results

The disturbances to be evaluated in the transient stability analysis are identified in Table 3. These disturbances were simulated out to 10 seconds to ensure a sufficient damping response from the system. All events, unless specifically identified, assume a 3-phase fault with normal clearing. In the event that acceptable performance is not achieved, the reduced impedance single line-to-ground (SLG) fault should be applied as required in NERC Reliability Standard TPL-001-4.

Parameters to be plotted for transient stability simulations include rotor angles and bus voltage and frequency for a representative set of buses in the study area. Additional parameters to monitor for later plotting as necessary include generator field and terminal voltages, rotor speed, and real and reactive output. The transient stability results are examined in section 8.6.


October 25, 2016 | 7

Table 3: Simulated Transient Stability Disturbances

Disturbance Description 3Ф Faulted Bus Cleared Element Fault

Duration (cy)

Archer-Cheyenne 115 Archer 115 Archer-Cheyenne 115 kV line 5

CPGS-Archer 115 CPGS 115 CPGS-Archer 115 kV line 5

CPGS-Archer 115 1&2 CPGS 115 CPGS-Archer + CPGS-EBP 115 kV lines 5

CPGS-East Business Park 115 CPGS 115 CPGS-East Business Park 115 kV line 5

CPGS-South Cheyenne1 115 CPGS 115 CPGS-South Cheyenne #1 115kV line 5

CPGS-South Cheyenne1&2 115 CPGS 115 CPGS-South Cheyenne #1 & 2 115kV line 5

Happy Jack-Cheyenne 115 Happy Jack 115 Happy Jack-Cheyenne 115 kV line 5

Happy Jack-Happy Jack Wind 115 Happy Jack 115 Happy Jack-Happy Jack Wind 115 kV line 5

Happy Jack-North Range 115 Happy Jack 115 Happy Jack-NCAR 115 kV line 5

HJK-NRG 115 PO + SCH 230/115 XFMR #1 South Cheyenne 115 South Cheyenne 230/115 kV XFMR #1 5

South Cheyenne-Swan Ranch 115 South Cheyenne 115 South Cheyenne-Swan Ranch 115 kV line 5

SCH-COR 115 PO + SCH-SWR 115 South Cheyenne 115 South Cheyenne-Swan Ranch 115 kV line 5

South Cheyenne-Corlett-North Range South Cheyenne 115 South Cheyenne-Corlett-North Range 115kV line 5

Archer-Ault 230 Archer 230 Archer-Ault 230 kV line 5

Archer-Terry Ranch 230 Archer 230 Archer-Terry Ranch 230 kV line 5

ACH-TR 230 PO + ARH 230/115 XFMR #1 Archer 230 Archer 230/115 kV XFMR #1 5

ACH-TR 230 PO + ARH-CHY 115 Line Archer 230 Archer-Cheyenne 115 kV line 5

ACH-TR 230 PO + ARH-CPGS 115 Line Archer 230 Archer-CPGS 115 kV line 5

Archer-Stegall 230 Archer 230 Archer-Stegall 230 kV line 5

Cheyenne-Terry Ranch 230 Cheyenne 230 Cheyenne-Terry Ranch 230 kV line 5

Cheyenne-Snowy Range 230 Cheyenne 230 Cheyenne-Snowy Range 230 kV line 5

Snowy Range-Miracle Mile 230 Snowy Range 230 Snowy Range-Miracle Mile 230 kV line 5

Terry Ranch-Ault 230 Terry Ranch 230 Terry Ranch-Ault 230 kV line 5

Terry Ranch-North Park 230 Terry Ranch 230 Terry Ranch-North Park 230 kV line 5

Laramie River Station-Ault 345 Laramie River Stn. 345 Laramie River Station-Ault 345 kV line 4

Archer-Wayne Child 230 Archer 230 Archer-W. Child 230 kV line 5

Wayne Child-Keota 345 Wayne Child 345 W. Child-Keota 345 kV line 4

LRS-Keota 345 (No WC PH2) LRS LRS-W. Child-Keota 345 kV 4

LRS-Wayne Child 345 Laramie River Stn. 345 Laramie River Station- W. Child 345 kV line 4

Cheyenne 230/115 XFMR #1 Cheyenne 230 Cheyenne 230/115 XFMR #1 25

Archer 230/115 XFMR #1 Archer 230 Archer 230/115 XFMR #1 25

SLG Cheyenne 230/115 XFMR #1 Cheyenne 230 Cheyenne 230/115 XFMR #1 25

SLG Archer 230/115 XFMR #1 Archer 230 Archer 230/115 XFMR #1 25


8 Examination of Results 8.1 Voltage Issues

No pre- or post-contingent voltage impacts, where the change in voltage between the base case and change case was greater than 1%, were found in this study.

8.2 2018 Summer Peak Thermal Results There were no thermal loading issues identified for system intact and N-1 conditions in either of the evaluated scenarios.

Detailed tables are shown in the Appendix A for each case comparison. Please note that for the same facility with multiple contingencies, only the highest Distribution Factor was retained as shown in Appendix A.

8.3 2023 Summer Peak Thermal Results For the 2023 summer peak sensitivity cases, where CLPT-G6 is in service, the Tri-State Wayne Child Phase II project is in service, and with CLPT-G7 project modeled as NR1 or an ER resulted in overloads on the Owl Creek – Rockport Tap 115 kV line. The overload occurred with the loss of both the Archer – Ault 230 kV line and the Ault - Terry Ranch 230 kV lines. Although the flow on the line exceeds the Rate A in the model, the limiting facilities are at the TSG&T Rockport Substation and has a 4 hour continuous overload rating of 145 MVA. Therefore, no mitigation is required.

This same outage also resulted in the Rockport-Nunn 115 kV line limit of 120 MVA to be reached but not exceed its normal or emergency rating as defined in the model. Any required changes to the facility rating of the Rockport-Nunn 115 kV line should be coordinated between the customer, Western Area Power Administration and Tri-State as affected parties.

An additional overload is seen on the Ault – Weld LM 230 kV line when the first or the second circuit is lost. Please note that this facility was already overloaded in the base cases before the proposed CPLT-G7 project was modeled in-service. Although the flow on this line exceeds RATEA, for this outage, loading on the line is within the 30 minute emergency rating of 621 MVA, therefore no mitigation is required.

No line overloads were found for the NR2 scenario where CLPT-G7 project was dispatched to the Cheyenne Prairie and Wygen 1 generators.

The following table shows thermal overloads associated with the 2023 summer peak sensitivity cases, with the addition of 102 MW of at CLPT-G7, 124.8 MW from CLPT-G6, and the Tri-State Wayne Child Phase II project. These results as shown on Table 3 are grouped by the contingency listed. More complete tables are in Appendix A for each case comparison. Please note that for the same facility with multiple contingencies, only the highest Distribution Factor was retained as shown in Appendix A.


October 25, 2016 | 9

Table 4: Archer - Ault - Terry Ranch 230 kV Outage OPEN BRANCH FROM BUS 73009 [ARCHER 230.00] TO BUS 73011 [AULT 230.00] CKT 1 OPEN BRANCH FROM BUS 73011 [AULT 230.00] TO BUS 73488 [TERRY_RANCH 230.00] CKT 1

TRR-AULT+ARH-AULT DBLCKT Case Rating Post Contingent Loading

Base Load Pre CLPT-G7

Change Load Post CLPT-G7

73597 OWL_CRK 115.00 73172 ROCKPRTP 115.00 1 2023HS NR1 119 110.5 119.7

2023HS ER 119 110.5 119.5

OPEN BRANCH FROM BUS 73011 [AULT 230.00] TO BUS 73212 [WELD LM 230.00] CKT 1

1_AULT 230.00-WELD LM 230.00 Case Rating Post Contingent Loading



73011 AULT 230.00 73212 WELD LM 230.00 CKT 2 2023HS NR1 512.7 522.1 526.0

2023HS ER 512.7 522.1 525.6

OPEN BRANCH FROM BUS 73011 [AULT 230.00] TO BUS 73212 [WELD LM 230.00] CKT 2

2_AULT 230.00-WELD LM 230.00 Case Rating Post Contingent Loading



73011 AULT 230.00 73212 WELD LM 230.00 CKT 1 2023HS NR1 512.7 522.1 526.0

2023HS ER 512.7 522.1 525.6

8.4 Unsolved Contingencies in Steady State Analysis There were no unsolved valid contingencies.

8.5 Reactive Power Requirement CLFP requires that the proposed project should maintain a composite reactive power delivery at continuous rated power output at the high-side of the generator substation at a power factor within the range of 0.95 leading to 0.95 lagging at all levels of real power output, with the magnitude of reactive power calculated on the basis of nominal POI voltage (1.0 p.u.).

To analyze this requirement, a voltage set point of 0.98 p.u. was considered at the POI, in this case the new West Cheyenne 115 kV substation, to determine the CLPT-G7’s maximum capacity to provide reactive power since the supply of the reactive power to the system is most needed when voltages are low. In a similar manner, the absorption of reactive power from the system is most needed when voltages are high and thus a POI voltage of 1.05 p.u. was tested for maximum leading capacity.

The results show no additional reactive power support will be needed for interconnection of CLPT-G7.


8.6 Transient Stability Analysis Results Disturbances listed on Table 3 were simulated with and without the CLPT-G7 project for the 2018 summer peak and the 2023 summer peak sensitivity scenarios. Parameters were plotted for transient stability simulations include rotor angles and bus voltage and frequency for a representative set of buses in the study area. Additional parameters were monitored for later plotting as necessary including generator field and terminal voltages, rotor speed, and real and reactive output.

For various disturbances, the plot trace labeled SPRNGCAN and PTZLOGN4 on the dynamic plots ANGLES5 panel. The Peetz-Logan and Spring Canyon wind farms rotor angles were observed to be unstable independent of the proposed CLPT-G7 project. There may be an issue with the wind farm dynamic models, therefore, as discussed with Black Hills Planning Engineers, no action is required for this pre-existing condition.

In the 2018 time frame, for the three phase faults at the Archer or the Cheyenne 230/115/13.8 kV transformers, with delayed clearing of 25 cycles, the Cheyenne Prairie Generating Station (CPSG) units tripped independent of the addition of the proposed CLPT-G7 project. The simulation shows during these faults, the voltages at the Cheyenne Prairie substation drop below 0.65 p.u. When the fault is cleared at 25 cycles, the voltages do not fully recover and drops below 0.65 p.u. again, resulting in the out-of-step (OOS) relays trip the CPSG units. The OOS protection is designed to keep a system from losing synchronism. It detects stable power swings and out-of-step conditions by using the fact that the voltage/current variation during a power swing is gradual while it is virtually a step change during a fault. A power swing is a result of a fluctuation in voltage and current. The OOS relays is set up to detect certain OOS conditions such as when there are low voltages and current, and when those are outside of a normal operating range, in this case the CPSG units are tripped.

This condition was also observed for many fault scenarios in the 2023 summer peak sensitivity scenarios. This action is not in violation of the WECC Performance Criteria (WR1 1.3 and 1.4), therefore, no additional action is required.

The Archer 230/115/13.8 kV transformer disturbance with delayed clearing did not converge in the pre or post project cases for the 2023 summer peak sensitivity scenarios. As required, in the event that acceptable performance is not achieved, the reduced impedance single line-to-ground (SLG) fault should be applied as required in TPL-001-4. The results of a SLG fault with delayed clearing was simulated and shown to be stable for this fault. The issue was discussed with Black Hills Planning Engineers, and no additional action is proposed.

Rotor angle stability issues were found for Happy Jack and Sage wind farms for all faults with and without the proposed CLPT-G7 project. Small oscillations in the Happy Jack and Silver Sage rotor angles have been determined to be related to the dynamic models used for these wind plants. The oscillations damped out without Happy Jack and Sage online. After discussions with Black Hills, it was determined that because this is a result of dynamic modeling issues, no action is required.

The proposed CLPT-G7 project also experienced rotor angle stability issues for the three phase faults at the Archer or the Cheyenne 230/115/13.8 kV transformers, with delayed clearing, but it does not appear that there are any reliability issues to mitigate. Based on


October 25, 2016 | 11

discussions with Black Hills Planning Engineers, they will coordinate with the project sponsor regarding the event as it relates to wind turbine control settings. Therefore, no action is required.

The stability simulations for the three phase fault at the Archer or the Cheyenne 230/115/13.8 kV transformers, with delayed clearing did not converged for the 2023 summer peak cases. Further discussion between WAPA, CLF&P, and the customer for potential long term mitigation may be warranted, but no additional mitigation is required at this time.

9 Conclusions The CLPT-G7 wind project can be operated at the requested capacity of 102 MW as a Network Resource or Energy Resource. Any overloaded facilities that were present as a result of adding the new wind project can be mitigated by utilizing the emergency ratings determined by the transmission owner.

To better coincide with the TP’s future transmission expansion plans, the CLPT-G7 POI is a new 115 kV substation between the generation facility location and the existing 115 kV line corridor between Swan Ranch and King Ranch. The Point of Change of Ownership will be at the dead end structure in the Cheyenne West 115 kV substation.

Results of the power flow analysis do not show any overloaded facilities in the 2018 time frame. In the 2023 scenarios, for the loss of both the Archer – Ault 230 kV line and the Ault - Terry Ranch 230 kV line, the Rockport-Nunn 115 kV line 120 MVA of Rate A limit is reached but not exceeded. Any required changes to the facility rating of the Rockport-Nunn 115 kV line should be coordinated between the customer, Western Area Power Administration and Tri-State as affected parties.

The results of the reactive power requirement analysis show that no additional reactive power support will be needed for interconnection of CLPT-G7.

In the transient stability analysis, for the 2018 scenario, a three phase faults at the Archer or the Cheyenne 230/115/13.8 kV transformers, with delayed clearing, resulted in the tripping of the Cheyenne Prairie Generating Station independent of the proposed CLPT-G7 project. This condition was also observed for many fault scenarios in the 2023 summer peak sensitivity scenarios. This action is not in violation WECC Performance Criteria (WR1 1.3 and 1.4), and therefore no additional action is required.

The proposed CLPT-G7 project experiences rotor angle stability issues for these outages. Black Hills Planning Engineers will coordinate with the project sponsor regarding the event as it relates to wind turbine control settings. No additional mitigation is required to address these issues.

It should be noted that the results described in this report do not guarantee transmission service for the customer. Transmission service should be requested through the CLPT OASIS. Requests will be granted on a first-come, first serve basis.


9.1 Interconnection Customer Interconnection Facilities The IC collector substation shall be designed to include one breakered line position to accommodate the 115 kV generator tie line between the collector substation and a new 115 kV substation designated as the POI. The generation tie line was assumed to be 0.5 miles long and constructed using 795 ACSR on single circuit structures. Figure 3 below shows the CLPT-G7 interconnection diagram.

Table 5: IC Interconnection Facility Upgrades

9.2 Transmission Provider Interconnection Facilities The Cheyenne West substation shall be designed to include one breakered line position to accommodate the 115 kV generator tie line from the collector substation. Figure 3 below shows the CLPT-G7 interconnection diagram.

Table 6: IC Interconnection Facility Upgrades

9.3 Network Upgrades Network Upgrades shall mean the additions, modifications, and upgrades to the Transmission Provider’s Transmission System required at or beyond the point at which the Interconnection Facilities connect to the Transmission Provider’s Transmission System to accommodate the interconnection of the Generating Facility to the Transmission Provider’s Transmission System. The estimated cost of this requirement is shown in Table 5 below.

Facility Upgrade Description Cost Estimate Implementation Timeframe

Gen tie line from the POI at the new Cheyenne West substation to the CLPT-G7 collector substation

Construct 0.5 miles of single circuit 115 kV transmission using 795 ACSR. $150,000 12-18 Months

Total: $150,000 12-18 Months


New ‘Cheyenne West’ 115 kV substation terminal

New 115 kV, 2000 amp line terminal to accommodate the new 115 kV transmission line to the proposed Corriedale Wind facility collector substation; includes necessary substation A-frame steel, 115 kV metering instruments, line protection, and typical associated conductors

$430,000 12-18 Months

Total: $430,000 12-18 Months


October 25, 2016 | 13

Table 7: Network Upgrades

1-Cost of property to locate and develop these facilities is not included in the estimated price. The location of this proposed substation facility is currently being negotiated/acquired under a separate proposal. Any cost allocation related to the use of the substation site to support this proposed wind interconnection facility is not included in the estimate. The proposed project costs, schedules, and construction timelines may be impacted by the availability and/or suitability of the site acquired. -The scope of this estimate assumes the Point of Interconnection is at the substation main bus and the Point of Change of Ownership is at the interface to the transmission line facilities is at the line jumper at the top of the Wind Farm line terminal A-Frame. No facility or construction costs are included beyond the Point of Change of Ownership. -The scope of this estimate does not include any transmission line construction costs outside of the substation facility or provisions for right of way or easements to the transmission line facilities. -Cost estimate does not include any special permitting for the proposed substation site or any special environmental considerations that may be required due to the nature or impact of the interconnecting facilities or project. -Cost estimate does not include any special metering systems beyond standard Black Hills Energy interface metering, and does not account for third party (Generation Boundary, Control Area Boundary, etc.) requirements or equipment. -Cost estimate does not include any special protection or Control (Generation Interconnect, Load Shedding, Frequency Control, Automatic Generation Control, etc.) systems that may be required due to the nature or impact of the interconnecting project. -Cost estimate is based upon standard BHE utility substation design and construction practices and does not factor in any special requirements of the interconnecting customer or any joint facility owners.


Transmission line from the intersection on the Swan Ranch-King Ranch 115 kV line to the Cheyenne West substation

Construct 0.3 miles of double circuit 115 kV transmission utilizing 795 ACSR on double circuit monopole structures.

$207,000 12-18 Months

New ‘Cheyenne West’ 115 kV substation

Construct a new 115 kV, 2000 Amp, 3-position ring bus substation to provide 3 115 kV transmission line terminals; includes breakers, switches, instrument transformers, bus, conductors, protection and control systems, foundation and support systems, control building, and associated common equipment.

$3,300,0001 18-24 Months

Total: $3,507,000 18-24 Months


Figure 3: CLPT-G7 Interconnection Diagram


October 25, 2016 | 15

Appendix A: Thermal Results 2018HS Base Case compared to Change Case with CLPT-G7 in-service at 102 MW dispatched as NR1 to Wygen.

TOT3 flows at 1600 MW (N-S).

Facility Rate A Without CLPT-G7

MVA Loading With CLPT-G7 MVA Loading Contingency

102 MW Distribution

Factor

CLPT-G7 Project

Loading %

73008 ARCHER 115.00 74060 CPGSTN 115.00 1 158.0 74.076 97.932 CHEYENNE 115.00-HAPPYJCK 115.00 #1 23.39% 61.98%

73011 AULT 230.00 73488 TERRY_RANCH 230.00 1 457.0 258.013 278.099 AULT 345.00-LAR.RIVR 345.00 #1 19.69% 60.85%

73145 NUNN 115.00 73552 AULT 115.00 1 120.0 90.498 105.909 TRR-AULT+ARH-AULT DBLCKT 15.11% 88.26%

73172 ROCKPRTP 115.00 73597 OWL_CRK 115.00 1 119.0 93.284 108.607 TRR-AULT+ARH-AULT DBLCKT 15.02% 91.30%

73597 OWL_CRK 115.00 73172 ROCKPRTP 115.00 1 119.0 93.284 108.607 TRR-AULT+ARH-AULT DBLCKT 15.02% 91.30%

73145 NUNN 115.00 73172 ROCKPRTP 115.00 1 120.0 92.047 107.359 TRR-AULT+ARH-AULT DBLCKT 15.01% 89.50%

73145 NUNN 115.00 73172 ROCKPRTP 115.00 1 120.0 52.975 63.036 AULT 230.00-TERRY_RANCH 230.00 #1 9.86% 52.50%

73172 ROCKPRTP 115.00 73597 OWL_CRK 115.00 1 119.0 54.471 64.509 AULT 230.00-TERRY_RANCH 230.00 #1 9.84% 53.75%

73597 OWL_CRK 115.00 73172 ROCKPRTP 115.00 1 119.0 54.471 64.509 AULT 230.00-TERRY_RANCH 230.00 #1 9.84% 53.75%

73011 AULT 230.00 73212 WELD LM 230.00 1 512.7 444.165 450.936 AULT 230.00-WELD LM 230.00 #2 6.64% 87.95%


2018HS Base Case compared to Change Case with CLPT-G7 in-service at 102 MW dispatched as NR2 to Cheyenne Prairie and Wygen.

TOT3 flows at 1600 MW (N-S).


MVA Loading

With CLPT-G7

MVA Loading Contingency

102 MW Distribution

Factor

CLPT-G7 Project

Loading % 73077 HAPPYJCK 115.00 74039 NORTHRNG 115.00 1 133.00 82.13 89.13 W.CHEY 115.00-G7WNDHI #1 6.86% 67.01% 73172 ROCKPRTP 115.00 73597 OWL_CRK 115.00 1 119.00 93.28 96.82 TRR-AULT+ARH-AULT DBLCKT 3.46% 81.36% 73597 OWL_CRK 115.00 73172 ROCKPRTP 115.00 1 119.00 93.28 96.82 TRR-AULT+ARH-AULT DBLCKT 3.46% 81.36% 73145 NUNN 115.00 73172 ROCKPRTP 115.00 1 120.00 92.05 95.52 TRR-AULT+ARH-AULT DBLCKT 3.40% 79.60%



MVA Loading

With CLPT-G7


102 MW Distribution

Factor

CLPT-G7 Project

Loading % 73145 NUNN 115.00 73552 AULT 115.00 1 120.00 90.50 93.94 TRR-AULT+ARH-AULT DBLCKT 3.37% 78.28%

2018HS Base Case compared to Change Case with CLPT-G7 in-service at 102 MW dispatched as ER to Dave Johnson #4. TOT3 flows at 1600 MW (N-S).



102 MW Distribution

Factor

CLPT-G7 Project

Loading % 73008 ARCHER 115.00 74060 CPGSTN 115.00 1 158.0 74.076 97.859 CHEYENNE 115.00-HAPPYJCK 115.00 #1 23.32% 61.94% 73011 AULT 230.00 73488 TERRY_RANCH 230.00 1 457.0 258.013 277.831 AULT 345.00-LAR.RIVR 345.00 #1 19.43% 60.79% 73145 NUNN 115.00 73552 AULT 115.00 1 120.0 90.498 105.995 TRR-AULT+ARH-AULT DBLCKT 15.19% 88.33% 73172 ROCKPRTP 115.00 73597 OWL_CRK 115.00 1 119.0 93.284 108.690 TRR-AULT+ARH-AULT DBLCKT 15.10% 91.34% 73597 OWL_CRK 115.00 73172 ROCKPRTP 115.00 1 119.0 93.284 108.690 TRR-AULT+ARH-AULT DBLCKT 15.10% 91.34% 73145 NUNN 115.00 73172 ROCKPRTP 115.00 1 120.0 92.047 107.442 TRR-AULT+ARH-AULT DBLCKT 15.09% 89.54% 73597 OWL_CRK 115.00 73172 ROCKPRTP 115.00 1 119.0 54.471 64.540 AULT 230.00-TERRY_RANCH 230.00 #1 9.87% 54.24% 73011 AULT 230.00 73212 WELD LM 230.00 1 512.7 444.165 450.694 AULT 230.00-WELD LM 230.00 #2 6.40% 87.91%

2023HS Base Case compared to Change Case with CLPT-G7 in-service at 102 MW dispatched as NR1 to Wygen. CLPT-G6 in-service at 124 MW. TOT3 flows at 1750 MW (N-S).



102 MW Distribution

Factor

CLPT-G7 Project

Loading %

73011 AULT 230.00 73488 TERRY_RANCH 230.00 1 457.0 260.501 281.007 PONNEQUI 115.00-OWL_CRK 115.00 #1 20.10% 61.49%

73008 ARCHER 115.00 74060 CPGSTN 115.00 1 213.0 154.415 167.404 CPGSTN-SCHEY 115 DBLCKT 12.73% 78.59%

73172 ROCKPRTP 115.00 73597 OWL_CRK 115.00 1 119.0 110.507 119.657 TRR-AULT+ARH-AULT DBLCKT 8.97% 100.6%

73597 OWL_CRK 115.00 73172 ROCKPRTP 115.00 1 119.0 110.507 119.657 TRR-AULT+ARH-AULT DBLCKT 8.97% 100.6%

73145 NUNN 115.00 73552 AULT 115.00 1 120.0 108.148 117.201 TRR-AULT+ARH-AULT DBLCKT 8.88% 97.67%

73145 NUNN 115.00 73172 ROCKPRTP 115.00 1 120.0 109.434 118.468 TRR-AULT+ARH-AULT DBLCKT 8.86% 98.72%

73172 ROCKPRTP 115.00 73597 OWL_CRK 115.00 1 119.0 76.640 84.137 AULT 230.00-TERRY_RANCH 230.00 #1 7.35% 70.70%

73597 OWL_CRK 115.00 73172 ROCKPRTP 115.00 1 119.0 76.640 84.137 AULT 230.00-TERRY_RANCH 230.00 #1 7.35% 70.70%


October 25, 2016 | 17



102 MW Distribution

Factor

CLPT-G7 Project

Loading %

73145 NUNN 115.00 73172 ROCKPRTP 115.00 1 120.0 75.290 82.760 AULT 230.00-TERRY_RANCH 230.00 #1 7.32% 69.00%

73009 ARCHER 230.00 73011 AULT 230.00 1 462.0 276.124 283.258 WCHILD 345.00-KEOTA 345.00 #1 6.99% 61.31%

70471 WELD_PS 230.00 73212 WELD LM 230.00 1 797.0 570.790 576.011 WINDSOR 230.00-AULT 230.00 #1 5.12% 72.27%

73212 WELD LM 230.00 70471 WELD_PS 230.00 1 797.0 570.790 576.011 WINDSOR 230.00-AULT 230.00 #1 5.12% 72.27%

73011 AULT 230.00 73212 WELD LM 230.00 1 512.7 303.993 308.175 ARCHER 230.00-WAYNECHILD 230.00 #1 4.10% 60.11%

73011 AULT 230.00 73212 WELD LM 230.00 2 512.7 303.993 308.175 ARCHER 230.00-WAYNECHILD 230.00 #1 4.10% 60.11%



70474 WINDSOR 230.00 73011 AULT 230.00 1 574.0 386.929 390.601 WELD_PS 230.00-WELD LM 230.00 #1 3.60% 68.05%

73011 AULT 230.00 70474 WINDSOR 230.00 1 574.0 386.929 390.601 WELD_PS 230.00-WELD LM 230.00 #1 3.60% 68.05%

73024 BLKHLWTP 115.00 73552 AULT 115.00 1 196.0 114.316 117.682 TRR-AULT+ARH-AULT DBLCKT 3.30% 60.04%

73552 AULT 115.00 73024 BLKHLWTP 115.00 1 196.0 114.316 117.682 TRR-AULT+ARH-AULT DBLCKT 3.30% 60.04%

73604 PORTNER 230.00 73078 HARMONY 230.00 1 472.0 286.711 289.440 WELD_PS 230.00-WELD LM 230.00 #1 2.68% 61.32%

2023HS Base Case compared to Change Case with CLPT-G7 in-service at 102 MW dispatched as NR2 to Cheyenne Prairie and Wygen. CLPT-G6 in-service at 124 MW. TOT3 flows at 1750 MW (N-S).


MVA Loading

With CLPT-G7


102 MW Distribution

Factor

CLPT-G7 Project

Loading % 65420 DAVEJOHN 230.00 72906 SAWMILLC 230.00 1 319.0 237.020 247.160 LGIR-G7 115.00-W.CHEY 115.00 #1 9.94% 77.48% 72906 SAWMILLC 230.00 73107 LAR.RIVR 230.00 1 319.0 216.879 226.926 LGIR-G7 115.00-W.CHEY 115.00 #1 9.85% 71.14% 73107 LAR.RIVR 230.00 72906 SAWMILLC 230.00 1 319.0 216.879 226.926 LGIR-G7 115.00-W.CHEY 115.00 #1 9.85% 71.14% 73077 HAPPYJCK 115.00 74039 NORTHRNG 115.00 1 213.0 136.402 145.734 KINGRNCH-LGIRG7 115 DBLCKT 9.15% 68.42% 73011 AULT 230.00 73488 TERRY_RANCH 230.00 1 457.0 323.887 328.444 WCHILD 345.00-KEOTA 345.00 #1 4.47% 71.87% 73011 AULT 230.00 73212 WELD LM 230.00 1 512.7 306.558 310.341 CPGSTN TIES 115 3.71% 60.53% 73011 AULT 230.00 73212 WELD LM 230.00 2 512.7 306.558 310.341 CPGSTN TIES 115 3.71% 60.53% 73172 ROCKPRTP 115.00 73597 OWL_CRK 115.00 1 119.0 110.507 113.255 TRR-AULT+ARH-AULT DBLCKT 2.69% 95.17% 73597 OWL_CRK 115.00 73172 ROCKPRTP 115.00 1 119.0 110.507 113.255 TRR-AULT+ARH-AULT DBLCKT 2.69% 95.17% 73145 NUNN 115.00 73172 ROCKPRTP 115.00 1 120.0 109.434 112.079 TRR-AULT+ARH-AULT DBLCKT 2.59% 93.40% 73145 NUNN 115.00 73552 AULT 115.00 1 120.0 108.148 110.735 TRR-AULT+ARH-AULT DBLCKT 2.54% 92.30%


2023HS Base Case compared to Change Case with CLPT-G7 in-service at 102 MW dispatched as ER to Dave Johnson #4. CLPT-G6 in-service at 124 MW. TOT3 flows at 1750 MW (N-S).



102 MW Distribution

Factor

CLPT-G7 Project

Loading % 73011 AULT 230.00 73488 TERRY_RANCH 230.00 1 457.0 260.501 280.749 PONNEQUI 115.00-OWL_CRK 115.00 #1 19.85% 61.43% 73008 ARCHER 115.00 74060 CPGSTN 115.00 1 213.0 154.415 167.382 CPGSTN-SCHEY 115 DBLCKT 12.71% 78.58% 73597 OWL_CRK 115.00 73172 ROCKPRTP 115.00 1 119.0 110.507 119.542 TRR-AULT+ARH-AULT DBLCKT 8.86% 100.45% 73172 ROCKPRTP 115.00 73597 OWL_CRK 115.00 1 119.0 110.507 119.542 TRR-AULT+ARH-AULT DBLCKT 8.86% 100.45% 73145 NUNN 115.00 73552 AULT 115.00 1 120.0 108.148 117.086 TRR-AULT+ARH-AULT DBLCKT 8.76% 98.39% 73145 NUNN 115.00 73172 ROCKPRTP 115.00 1 120.0 109.434 118.354 TRR-AULT+ARH-AULT DBLCKT 8.75% 98.63% 73172 ROCKPRTP 115.00 73597 OWL_CRK 115.00 1 119.0 76.640 84.057 AULT 230.00-TERRY_RANCH 230.00 #1 7.27% 70.64% 73597 OWL_CRK 115.00 73172 ROCKPRTP 115.00 1 119.0 76.640 84.057 AULT 230.00-TERRY_RANCH 230.00 #1 7.27% 70.64% 73145 NUNN 115.00 73172 ROCKPRTP 115.00 1 120.0 75.290 82.679 AULT 230.00-TERRY_RANCH 230.00 #1 7.24% 69.00% 73009 ARCHER 230.00 73011 AULT 230.00 1 462.0 276.124 282.931 WCHILD 345.00-KEOTA 345.00 #1 6.67% 61.24% 70471 WELD_PS 230.00 73212 WELD LM 230.00 1 797.0 570.790 575.435 WINDSOR 230.00-AULT 230.00 #1 4.55% 72.20% 73212 WELD LM 230.00 70471 WELD_PS 230.00 1 797.0 570.790 575.435 WINDSOR 230.00-AULT 230.00 #1 4.55% 72.20% 73145 NUNN 115.00 73552 AULT 115.00 1 120.0 80.264 84.815 AULT 345.00-LAR.RIVR 345.00 #1 4.46% 70.68% 73011 AULT 230.00 73212 WELD LM 230.00 1 512.7 303.993 308.017 ARCHER 230.00-WAYNECHILD 230.00 #1 3.95% 60.08% 73011 AULT 230.00 73212 WELD LM 230.00 2 512.7 303.993 308.017 ARCHER 230.00-WAYNECHILD 230.00 #1 3.95% 60.08% 73011 AULT 230.00 73212 WELD LM 230.00 2 512.7 522.113 525.589 AULT 230.00-WELD LM 230.00 #1 3.41% 102.51% 73011 AULT 230.00 73212 WELD LM 230.00 1 512.7 522.113 525.589 AULT 230.00-WELD LM 230.00 #2 3.41% 102.51% 73024 BLKHLWTP 115.00 73552 AULT 115.00 1 196.0 114.316 117.613 TRR-AULT+ARH-AULT DBLCKT 3.23% 60.01% 73552 AULT 115.00 73024 BLKHLWTP 115.00 1 196.0 114.316 117.613 TRR-AULT+ARH-AULT DBLCKT 3.23% 60.01% 70474 WINDSOR 230.00 73011 AULT 230.00 1 574.0 386.929 390.182 WELD_PS 230.00-WELD LM 230.00 #1 3.19% 67.98% 73011 AULT 230.00 70474 WINDSOR 230.00 1 574.0 386.929 390.182 WELD_PS 230.00-WELD LM 230.00 #1 3.19% 67.98% 73172 ROCKPRTP 115.00 73597 OWL_CRK 115.00 1 119.0 57.751 60.861 HAPPYJCK 115.00-NORTH RANGE 115.00 #1 3.05% 51.14% 73145 NUNN 115.00 73172 ROCKPRTP 115.00 1 120.0 56.304 59.415 HAPPYJCK 115.00-NORTH RANGE 115.00 #1 3.05% 49.51% 73604 PORTNER 230.00 73078 HARMONY 230.00 1 472.0 286.711 289.178 WELD_PS 230.00-WELD LM 230.00 #1 2.42% 61.27% 73024 BLKHLWTP 115.00 73552 AULT 115.00 1 196.0 120.386 122.670 DIXON CK 230.00-COLLEGLK 230.00 #1 2.24% 62.59% 73552 AULT 115.00 73024 BLKHLWTP 115.00 1 196.0 120.386 122.670 DIXON CK 230.00-COLLEGLK 230.00 #1 2.24% 62.59% 70474 WINDSOR 230.00 73011 AULT 230.00 1 574.0 358.381 360.632 LRS-WCHILD-KEOTA 345 2.21% 62.83% 73011 AULT 230.00 70474 WINDSOR 230.00 1 574.0 358.381 360.632 LRS-WCHILD-KEOTA 345 2.21% 62.83%

73011 AULT 230.00 73212 WELD LM 230.00 1 512.7 317.008 319.079 BASE CASE 2.03% 62.24%

73011 AULT 230.00 73212 WELD LM 230.00 2 512.7 317.008 319.079 BASE CASE 2.03% 62.24% 73011 AULT 230.00 73212 WELD LM 230.00 1 512.7 318.546 320.583 KERSEYTP 115.00-WILLOBY 115.00 #1 2.00% 62.53% 73011 AULT 230.00 73212 WELD LM 230.00 2 512.7 318.546 320.583 KERSEYTP 115.00-WILLOBY 115.00 #1 2.00% 62.53%


October 25, 2016 | 19

Appendix B: Simulated Contingencies CONTINGENCY EVENTS

LAR.RIVR 345.00-WCHILD 345.00 #1 OPEN BRANCH FROM BUS 73108 [LAR.RIVR 345.00] TO BUS 72811 [WL_CHILD 345.00] CKT 1

WCHILD 345.00-KEOTA 345.00 #1 OPEN BRANCH FROM BUS 72811 [WL_CHILD 345.00] TO BUS 72140 [KEOTA 345.00] CKT 1 KEOTA 345.00-STORY 345.00 #1 OPEN BRANCH FROM BUS 72140 [KEOTA 345.00] TO BUS 73193 [STORY 345.00] CKT 1

CARR DRA 230.00-BARBERCK 230.00 #1 OPEN BRANCH FROM BUS 65293 [CARR DRA 230.00] TO BUS 76401 [BARBERCK 230.00] CKT 1

CASPERPP 115.00-REDBUTTETAP 115.00 #1 OPEN BRANCH FROM BUS 65305 [CASPERPP 115.00] TO BUS 900015 [REDBUTTETAP 115.00] CKT 1 REDBUTTETAP 115.00-CASPERLM 115.00 #1 OPEN BRANCH FROM BUS 900015 [REDBUTTETAP 115.00] TO BUS 73042 [CASPERLM 115.00] CKT 1

CASPERPP 115.00-REFNRYTP 115.00 #1 OPEN BRANCH FROM BUS 65305 [CASPERPP 115.00] TO BUS 73167 [REFNRYTP 115.00] CKT 1

DAVEJOHN 230.00-SAWMILLC 230.00 #1 OPEN BRANCH FROM BUS 65420 [DAVEJOHN 230.00] TO BUS 72906 [SAWMILLC 230.00] CKT 1 DAVEJOHN 230.00-GOSH_COUNTY 230.00 #1 OPEN BRANCH FROM BUS 65420 [DAVEJOHN 230.00] TO BUS 73548 [GOSH_COUNTY 230.00] CKT 1

SAWMILLC 230.00-LAR.RIVR 230.00 #1 OPEN BRANCH FROM BUS 72906 [SAWMILLC 230.00] TO BUS 73107 [LAR.RIVR 230.00] CKT 1

DAVEJOHN 115.00-DAVEJTPN 115.00 #1 OPEN BRANCH FROM BUS 65425 [DAVEJOHN 115.00] TO BUS 73070 [DAVEJTPN 115.00] CKT 1 DAVEJOHN 115.00-BIXBY 115.00 #1 OPEN BRANCH FROM BUS 65425 [DAVEJOHN 115.00] TO BUS 69155 [BIXBY 115.00] CKT 1

BIXBY 115.00-DAVEJTPS 115.00 #1 OPEN BRANCH FROM BUS 69155 [BIXBY 115.00] TO BUS 73071 [DAVEJTPS 115.00] CKT 1

WINDSTAR 230.00-PUMPKIN 230.00 #1 OPEN BRANCH FROM BUS 67814 [WINDSTAR 230.00] TO BUS 76400 [PUMPKIN_BTS 230.00] CKT 1 KELIM 115.00-AIRPORT 115.00 #1 OPEN BRANCH FROM BUS 70008 [KELIM 115.00] TO BUS 73002 [AIRPORT 115.00] CKT 1

ST.VRAIN 230.00-LONGPEAK 230.00 #1 OPEN BRANCH FROM BUS 70410 [ST.VRAIN 230.00] TO BUS 73116 [LONGPEAK 230.00] CKT 1

ST.VRAIN 230.00-FORDHAM 230.00 #1 OPEN BRANCH FROM BUS 70410 [ST.VRAIN 230.00] TO BUS 73562 [FORDHAM 230.00] CKT 1 WELD_PS 115.00-WELD LM 115.00 #1 OPEN BRANCH FROM BUS 70470 [WELD_PS 115.00] TO BUS 73211 [WELD LM 115.00] CKT 1

WELD_PS 230.00-WELD LM 230.00 #1 OPEN BRANCH FROM BUS 70471 [WELD_PS 230.00] TO BUS 73212 [WELD LM 230.00] CKT 1

WINDSOR 230.00-AULT 230.00 #1 OPEN BRANCH FROM BUS 70474 [WINDSOR 230.00] TO BUS 73011 [AULT 230.00] CKT 1 BERTHOUD 115.00-LONETREE 115.00 #1 OPEN BRANCH FROM BUS 70534 [BERTHOUD 115.00] TO BUS 73114 [LONETREE 115.00] CKT 1

BERTHOUD 115.00-LONTRETP 115.00 #1 OPEN BRANCH FROM BUS 70534 [BERTHOUD 115.00] TO BUS 73561 [LONTRETP 115.00] CKT 1

SLATERTS 115.00-DEL CTAP 115.00 #1 OPEN BRANCH FROM BUS 72107 [SLATER_TS 115.00] TO BUS 73048 [DEL CTAP 115.00] CKT 1 SLATERTS 115.00-DELCAMIN 115.00 #1 OPEN BRANCH FROM BUS 72107 [SLATER_TS 115.00] TO BUS 73049 [DELCAMIN 115.00] CKT 1

AIRPORT 115.00-BOYD 115.00 #1 OPEN BRANCH FROM BUS 73002 [AIRPORT 115.00] TO BUS 73026 [BOYD 115.00] CKT 1

AIRPORT 115.00-WINDSORT 115.00 #1 OPEN BRANCH FROM BUS 73002 [AIRPORT 115.00] TO BUS 73433 [WINDSORT 115.00] CKT 1 ALCOVA 115.00-CASPERLM 115.00 #1 OPEN BRANCH FROM BUS 73004 [ALCOVA 115.00] TO BUS 73042 [CASPERLM 115.00] CKT 1

ALCOVA 115.00-CASPERLM 115.00 #2 OPEN BRANCH FROM BUS 73004 [ALCOVA 115.00] TO BUS 73042 [CASPERLM 115.00] CKT 2

ALCOVA 115.00-FREMONT 115.00 #1 OPEN BRANCH FROM BUS 73004 [ALCOVA 115.00] TO BUS 73062 [FREMONT 115.00] CKT 1


CONTINGENCY EVENTS

ALCOVA 115.00-MIRACLEM 115.00 #1 OPEN BRANCH FROM BUS 73004 [ALCOVA 115.00] TO BUS 73137 [MIRACLEM 115.00] CKT 1

ALCOVA 115.00-MIRACLEM 115.00 #2 OPEN BRANCH FROM BUS 73004 [ALCOVA 115.00] TO BUS 73137 [MIRACLEM 115.00] CKT 2 ALCOVA 115.00-RADERVIL 115.00 #1 OPEN BRANCH FROM BUS 73004 [ALCOVA 115.00] TO BUS 73162 [RADERVIL 115.00] CKT 1

ARCHER 115.00-CHEYENNE 115.00 #1 OPEN BRANCH FROM BUS 73008 [ARCHER 115.00] TO BUS 73043 [CHEYENNE 115.00] CKT 1

ARCHER 115.00-CROWCRK 115.00 #1 OPEN BRANCH FROM BUS 73008 [ARCHER 115.00] TO BUS 73480 [CROWCRK 115.00] CKT 1 ARCHER 115.00-MYERS TP 115.00 #1 OPEN BRANCH FROM BUS 73008 [ARCHER 115.00] TO BUS 73140 [MYERS TP 115.00] CKT 1

ARCHER 115.00-PINEBLUF 115.00 #1 OPEN BRANCH FROM BUS 73008 [ARCHER 115.00] TO BUS 73152 [PINEBLUF 115.00] CKT 1

ARCHER 115.00-CPGSTN 115.00 #1 OPEN BRANCH FROM BUS 73008 [ARCHER 115.00] TO BUS 74060 [CPGSTN 115.00] CKT 1 CPGSTN 115.00-EB PARK 115.00 #1 OPEN BRANCH FROM BUS 74060 [CPGSTN 115.00] TO BUS 74041 [EB PARK 115.00] CKT 1

ARCHER 230.00-AULT 230.00 #1 OPEN BRANCH FROM BUS 73009 [ARCHER 230.00] TO BUS 73011 [AULT 230.00] CKT 1

ARCHER 230.00-STEGALL 230.00 #1 OPEN BRANCH FROM BUS 73009 [ARCHER 230.00] TO BUS 73190 [STEGALL 230.00] CKT 1 ARCHER 230.00-TERRY_RANCH 230.00 #1 OPEN BRANCH FROM BUS 73009 [ARCHER 230.00] TO BUS 73488 [TERRY_RANCH 230.00] CKT 1

ARCHER 230.00-WAYNECHILD 230.00 #1 OPEN BRANCH FROM BUS 73009 [ARCHER 230.00] TO BUS 72818 [WL_CHILD 230.00] CKT 1

TERRY_RANCH 230.00-NORTH PARK 230.00 #1 OPEN BRANCH FROM BUS 73488 [TERRY_RANCH 230.00] TO BUS 73616 [NORTH PARK 230.00] CKT 1 AULT 230.00-RAWHIDE 230.00 #1 OPEN BRANCH FROM BUS 73011 [AULT 230.00] TO BUS 73165 [RAWHIDE 230.00] CKT 1

RAWHIDE 230.00-TIMBERLN 230.00 #1 OPEN BRANCH FROM BUS 73165 [RAWHIDE 230.00] TO BUS 73199 [TIMBERLN 230.00] CKT 1

AULT 230.00-WELD LM 230.00 #1 OPEN BRANCH FROM BUS 73011 [AULT 230.00] TO BUS 73212 [WELD LM 230.00] CKT 1 AULT 230.00-WELD LM 230.00 #2 OPEN BRANCH FROM BUS 73011 [AULT 230.00] TO BUS 73212 [WELD LM 230.00] CKT 2

AULT 230.00-TERRY_RANCH 230.00 #1 OPEN BRANCH FROM BUS 73011 [AULT 230.00] TO BUS 73488 [TERRY_RANCH 230.00] CKT 1

AULT 345.00-LAR.RIVR 345.00 #1 OPEN BRANCH FROM BUS 73012 [AULT 345.00] TO BUS 73108 [LAR.RIVR 345.00] CKT 1 AULT 345.00-CRAIG 345.00 #1 OPEN BRANCH FROM BUS 73012 [AULT 345.00] TO BUS 79014 [CRAIG 345.00] CKT 1

BLKHLWTP 115.00-COBBLKTP 115.00 #1 OPEN BRANCH FROM BUS 73024 [BLKHLWTP 115.00] TO BUS 73044 [COBBLKTP 115.00] CKT 1

BLKHLWTP 115.00-AULT 115.00 #1 OPEN BRANCH FROM BUS 73024 [BLKHLWTP 115.00] TO BUS 73552 [AULT 115.00] CKT 1 BOYD 115.00-LOVE E 115.00 #1 OPEN BRANCH FROM BUS 73026 [BOYD 115.00] TO BUS 73118 [LOVE E 115.00] CKT 1

BOYD 115.00-VALLEYLM 115.00 #1 OPEN BRANCH FROM BUS 73026 [BOYD 115.00] TO BUS 73373 [VALLEYLM 115.00] CKT 1

BOYD 115.00-LONTRETP 115.00 #1 OPEN BRANCH FROM BUS 73026 [BOYD 115.00] TO BUS 73561 [LONTRETP 115.00] CKT 1 BOYD 115.00-DERBHILT 115.00 #1 OPEN BRANCH FROM BUS 73026 [BOYD 115.00] TO BUS 73595 [DERBHILT 115.00] CKT 1

BOYD 230.00-LONGPEAK 230.00 #1 OPEN BRANCH FROM BUS 73027 [BOYD 230.00] TO BUS 73116 [LONGPEAK 230.00] CKT 1

BOYD 230.00-PORTNER 230.00 #1 OPEN BRANCH FROM BUS 73027 [BOYD 230.00] TO BUS 73604 [PORTNER 230.00] CKT 1 BRIGHTNW 115.00-SANDCRK 115.00 #1 OPEN BRANCH FROM BUS 73030 [BRIGHTNW 115.00] TO BUS 73493 [SANDCRK 115.00] CKT 1

BRIGHTNW 115.00-ERIE SW 115.00 #1 OPEN BRANCH FROM BUS 73030 [BRIGHTNW 115.00] TO BUS 73503 [ERIE SW 115.00] CKT 1

BUSHNLTP 115.00-PINEBLUF 115.00 #1 OPEN BRANCH FROM BUS 73038 [BUSHNLTP 115.00] TO BUS 73152 [PINEBLUF 115.00] CKT 1


October 25, 2016 | 21

CONTINGENCY EVENTS

CARTERLK 115.00-FLATIRON 115.00 #1 OPEN BRANCH FROM BUS 73039 [CARTERLK 115.00] TO BUS 73058 [FLATIRON 115.00] CKT 1

CARTERLK 115.00-LOVEWTAP 115.00 #1 OPEN BRANCH FROM BUS 73039 [CARTERLK 115.00] TO BUS 73124 [LOVEWTAP 115.00] CKT 1 CASPERLM 115.00-DAVEJTPN 115.00 #1 OPEN BRANCH FROM BUS 73042 [CASPERLM 115.00] TO BUS 73070 [DAVEJTPN 115.00] CKT 1

CHEYENNE 115.00-HAPPYJCK 115.00 #1 OPEN BRANCH FROM BUS 73043 [CHEYENNE 115.00] TO BUS 73077 [HAPPYJCK 115.00] CKT 1

CHEYENNE 115.00-CROWCRK 115.00 #1 OPEN BRANCH FROM BUS 73043 [CHEYENNE 115.00] TO BUS 73480 [CROWCRK 115.00] CKT 1 CHEYENNE 115.00-PONNEQUI 115.00 #1 OPEN BRANCH FROM BUS 73043 [CHEYENNE 115.00] TO BUS 73504 [PONNEQUI 115.00] CKT 1

COBBLKTP 115.00-TIMNATH 115.00 #1 OPEN BRANCH FROM BUS 73044 [COBBLKTP 115.00] TO BUS 73200 [TIMNATH 115.00] CKT 1

COBBLKTP 115.00-COBBLAKE 115.00 #1 OPEN BRANCH FROM BUS 73044 [COBBLKTP 115.00] TO BUS 73600 [COBBLAKE 115.00] CKT 1 DEL CTAP 115.00-LONGPEAK 115.00 #1 OPEN BRANCH FROM BUS 73048 [DEL CTAP 115.00] TO BUS 73115 [LONGPEAK 115.00] CKT 1

DEL CTAP 115.00-MEADOW 115.00 #1 OPEN BRANCH FROM BUS 73048 [DEL CTAP 115.00] TO BUS 73133 [MEADOW 115.00] CKT 1

DELCAMIN 115.00-RINNVALL 115.00 #1 OPEN BRANCH FROM BUS 73049 [DELCAMIN 115.00] TO BUS 73501 [RINNVALL 115.00] CKT 1 DERBYHIL 115.00-DERBHILT 115.00 #1 OPEN BRANCH FROM BUS 73050 [DERBYHIL 115.00] TO BUS 73595 [DERBHILT 115.00] CKT 1

DIXON CK 115.00-DRAKE RD 115.00 #1 OPEN BRANCH FROM BUS 73051 [DIXON CK 115.00] TO BUS 73052 [DRAKE RD 115.00] CKT 1

DIXON CK 115.00-HRSTHTAP 115.00 #1 OPEN BRANCH FROM BUS 73051 [DIXON CK 115.00] TO BUS 73089 [HRSTHTAP 115.00] CKT 1 DIXON CK 115.00-POUDRE 115.00 #1 OPEN BRANCH FROM BUS 73051 [DIXON CK 115.00] TO BUS 73156 [POUDRE 115.00] CKT 1

DRAKE RD 115.00-TIMBERLN 115.00 #1 OPEN BRANCH FROM BUS 73052 [DRAKE RD 115.00] TO BUS 73198 [TIMBERLN 115.00] CKT 1

ESTES 115.00-POLEHILL 115.00 #1 OPEN BRANCH FROM BUS 73056 [ESTES 115.00] TO BUS 73155 [POLEHILL 115.00] CKT 1 ESTES 115.00-MARYLKSB 115.00 #1 OPEN BRANCH FROM BUS 73056 [ESTES 115.00] TO BUS 73232 [MARYLKSB 115.00] CKT 1

ESTES 115.00-MARYLKTP 115.00 #1 OPEN BRANCH FROM BUS 73056 [ESTES 115.00] TO BUS 73233 [MARYLKTP 115.00] CKT 1

ESTES 115.00-WAGONWHL 115.00 #1 OPEN BRANCH FROM BUS 73056 [ESTES 115.00] TO BUS 73556 [WAGONWHL 115.00] CKT 1 FLATIRON 115.00-HRSTHTAP 115.00 #1 OPEN BRANCH FROM BUS 73058 [FLATIRON 115.00] TO BUS 73089 [HRSTHTAP 115.00] CKT 1

FLATIRON 115.00-POLEHILL 115.00 #1 OPEN BRANCH FROM BUS 73058 [FLATIRON 115.00] TO BUS 73155 [POLEHILL 115.00] CKT 1

FORDHAM 115.00-TERRY 115.00 #1 OPEN BRANCH FROM BUS 73060 [FORDHAM 115.00] TO BUS 73196 [TERRY 115.00] CKT 1 FORDHAM 115.00-ROGERSRD 115.00 #1 OPEN BRANCH FROM BUS 73060 [FORDHAM 115.00] TO BUS 73437 [ROGERSRD 115.00] CKT 1

GEMCTYTP 115.00-SPRINGCK 115.00 #1 OPEN BRANCH FROM BUS 73066 [GEMCTYTP 115.00] TO BUS 73187 [SPRINGCK 115.00] CKT 1

GEMCTYTP 115.00-SNOWYRNG 115.00 #1 OPEN BRANCH FROM BUS 73066 [GEMCTYTP 115.00] TO BUS 73570 [SNOWYRNG 115.00] CKT 1 GLENDO 115.00-GUERNTAP 115.00 #1 OPEN BRANCH FROM BUS 73069 [GLENDO 115.00] TO BUS 73076 [GUERNTAP 115.00] CKT 1

GLENDO 115.00-PODOLAK 115.00 #1 OPEN BRANCH FROM BUS 73069 [GLENDO 115.00] TO BUS 73153 [PODOLAK 115.00] CKT 1

GLENDO 115.00-WHTROCK 115.00 #1 OPEN BRANCH FROM BUS 73069 [GLENDO 115.00] TO BUS 73568 [WHTROCK 115.00] CKT 1 GLENDO 115.00-WAGHN NT 115.00 #1 OPEN BRANCH FROM BUS 73069 [GLENDO 115.00] TO BUS 73607 [WAGHN NT 115.00] CKT 1

GLENDO 115.00-WAGHN ST 115.00 #1 OPEN BRANCH FROM BUS 73069 [GLENDO 115.00] TO BUS 73608 [WAGHN ST 115.00] CKT 1

DAVEJTPN 115.00-WAGHN NT 115.00 #1 OPEN BRANCH FROM BUS 73070 [DAVEJTPN 115.00] TO BUS 73607 [WAGHN NT 115.00] CKT 1


CONTINGENCY EVENTS

DAVEJTPS 115.00-REFNRYTP 115.00 #1 OPEN BRANCH FROM BUS 73071 [DAVEJTPS 115.00] TO BUS 73167 [REFNRYTP 115.00] CKT 1

DAVEJTPS 115.00-WAGHN ST 115.00 #1 OPEN BRANCH FROM BUS 73071 [DAVEJTPS 115.00] TO BUS 73608 [WAGHN ST 115.00] CKT 1 GUERNTAP 115.00-LIMESTON 115.00 #1 OPEN BRANCH FROM BUS 73076 [GUERNTAP 115.00] TO BUS 73359 [LIMESTON 115.00] CKT 1

GUERNTAP 115.00-GUERNRRL 115.00 #1 OPEN BRANCH FROM BUS 73076 [GUERNTAP 115.00] TO BUS 73368 [GUERNRRL 115.00] CKT 1

GUERNTAP 115.00-WHTROCK 115.00 #1 OPEN BRANCH FROM BUS 73076 [GUERNTAP 115.00] TO BUS 73568 [WHTROCK 115.00] CKT 1 HAPPYJCK 115.00-NORTH RANGE 115.00 #1 OPEN BRANCH FROM BUS 73077 [HAPPYJCK 115.00] TO BUS 74039 [NORTHRNG 115.00] CKT 1

HAPPYJCK 115.00-HJWIND 115.00 #1 OPEN BRANCH FROM BUS 73077 [HAPPYJCK 115.00] TO BUS 74048 [HJWIND 115.00] CKT 1

HARMONY 230.00-TIMBERLN 230.00 #1 OPEN BRANCH FROM BUS 73078 [HARMONY 230.00] TO BUS 73199 [TIMBERLN 230.00] CKT 1 HARMONY 230.00-PORTNER 230.00 #1 OPEN BRANCH FROM BUS 73078 [HARMONY 230.00] TO BUS 73604 [PORTNER 230.00] CKT 1

HARVARD 115.00-LNGMNTNW 115.00 #1 OPEN BRANCH FROM BUS 73079 [HARVARD 115.00] TO BUS 73113 [LNGMNTNW 115.00] CKT 1

HORSESHO 115.00-LOVE W 115.00 #1 OPEN BRANCH FROM BUS 73086 [HORSESHO 115.00] TO BUS 73120 [LOVE W 115.00] CKT 1 HORSESHO 115.00-CROSSRDS 115.00 #1 OPEN BRANCH FROM BUS 73086 [HORSESHO 115.00] TO BUS 73499 [CROSSRDS 115.00] CKT 1

HRSTHTAP 115.00-TRILBY 115.00 #1 OPEN BRANCH FROM BUS 73089 [HRSTHTAP 115.00] TO BUS 73203 [TRILBY 115.00] CKT 1

HRSTHTAP 115.00-MASONVIL 115.00 #1 OPEN BRANCH FROM BUS 73089 [HRSTHTAP 115.00] TO BUS 73235 [MASONVIL 115.00] CKT 1 HYGIENE 115.00-LNGMNTNW 115.00 #1 OPEN BRANCH FROM BUS 73090 [HYGIENE 115.00] TO BUS 73113 [LNGMNTNW 115.00] CKT 1

HYGIENE 115.00-LYONS 115.00 #1 OPEN BRANCH FROM BUS 73090 [HYGIENE 115.00] TO BUS 73127 [LYONS 115.00] CKT 1

KERSEYTP 115.00-BOOMERNG 115.00 #1 OPEN BRANCH FROM BUS 73055 [KERSEY_W 115.00] TO BUS 70368 [ROSEDALE 115.00] CKT 1 OPEN BRANCH FROM BUS 70368 [ROSEDALE 115.00] TO BUS 73554 [BOOMERNG 115.00] CKT 1

KODAK 115.00-WHITNEY 115.00 #1 OPEN BRANCH FROM BUS 73098 [KODAK 115.00] TO BUS 73558 [WHITNEY 115.00] CKT 1

KODAK 115.00-WHITNEY 115.00 #2 OPEN BRANCH FROM BUS 73098 [KODAK 115.00] TO BUS 73558 [WHITNEY 115.00] CKT 2 KORTES 115.00-KORTESTP 115.00 #1 OPEN BRANCH FROM BUS 73099 [KORTES 115.00] TO BUS 73100 [KORTESTP 115.00] CKT 1

KORTES 115.00-MIRACLEM 115.00 #1 OPEN BRANCH FROM BUS 73099 [KORTES 115.00] TO BUS 73137 [MIRACLEM 115.00] CKT 1

KORTESTP 115.00-MIRACLEM 115.00 #1 OPEN BRANCH FROM BUS 73100 [KORTESTP 115.00] TO BUS 73137 [MIRACLEM 115.00] CKT 1 KORTESTP 115.00-SEMINOE 115.00 #1 OPEN BRANCH FROM BUS 73100 [KORTESTP 115.00] TO BUS 73176 [SEMINOE 115.00] CKT 1

LAGRANGE 115.00-ROUNDTOP 115.00 #1 OPEN BRANCH FROM BUS 73104 [LAGRANGE 115.00] TO BUS 73173 [ROUNDTOP 115.00] CKT 1

LAGRANGE 115.00-STEGALL 115.00 #1 OPEN BRANCH FROM BUS 73104 [LAGRANGE 115.00] TO BUS 73189 [STEGALL 115.00] CKT 1 LAPORTE 115.00-BELLVUTP 115.00 #1 OPEN BRANCH FROM BUS 73105 [LAPORTE 115.00] TO BUS 73298 [BELLVUTP 115.00] CKT 1

LAPORTE 230.00-RAWHIDE 230.00 #1 OPEN BRANCH FROM BUS 73106 [LAPORTE 230.00] TO BUS 73165 [RAWHIDE 230.00] CKT 1

LAPORTE 230.00-RAWHIDE 230.00 #2 OPEN BRANCH FROM BUS 73106 [LAPORTE 230.00] TO BUS 73165 [RAWHIDE 230.00] CKT 2 LAPORTE 230.00-TIMBERLN 230.00 #1 OPEN BRANCH FROM BUS 73106 [LAPORTE 230.00] TO BUS 73199 [TIMBERLN 230.00] CKT 1

LAPORTE 230.00-COLLEGLK 230.00 #1 OPEN BRANCH FROM BUS 73106 [LAPORTE 230.00] TO BUS 73470 [COLLEGLK 230.00] CKT 1

LAR.RIVR 230.00-STEGALL 230.00 #1 OPEN BRANCH FROM BUS 73107 [LAR.RIVR 230.00] TO BUS 73190 [STEGALL 230.00] CKT 1


October 25, 2016 | 23

CONTINGENCY EVENTS

LARAMIE 115.00-OASISTAP 115.00 #1 OPEN BRANCH FROM BUS 73109 [LARAMIE 115.00] TO BUS 73146 [OASISTAP 115.00] CKT 1

LARAMIE 115.00-SNOWYRNG 115.00 #1 OPEN BRANCH FROM BUS 73109 [LARAMIE 115.00] TO BUS 73570 [SNOWYRNG 115.00] CKT 1 LINDEN 115.00-RICHARDS 115.00 #1 OPEN BRANCH FROM BUS 73111 [LINDEN 115.00] TO BUS 73169 [RICHARDS 115.00] CKT 1

LINDEN 115.00-TIMBERLN 115.00 #1 OPEN BRANCH FROM BUS 73111 [LINDEN 115.00] TO BUS 73198 [TIMBERLN 115.00] CKT 1

LINGLE 115.00-LINGLETP 115.00 #1 OPEN BRANCH FROM BUS 73112 [LINGLE 115.00] TO BUS 73255 [LINGLETP 115.00] CKT 1 LNGMNTNW 115.00-MEADOW 115.00 #1 OPEN BRANCH FROM BUS 73113 [LNGMNTNW 115.00] TO BUS 73133 [MEADOW 115.00] CKT 1

LNGMNTNW 115.00-GLDNPNDS 115.00 #1 OPEN BRANCH FROM BUS 73113 [LNGMNTNW 115.00] TO BUS 73578 [GLDNPNDS 115.00] CKT 1

LONGPEAK 115.00-CNTYLINE 115.00 #1 OPEN BRANCH FROM BUS 73115 [LONGPEAK 115.00] TO BUS 73465 [CNTYLINE 115.00] CKT 1 LOVE E 115.00-CROSSRDS 115.00 #1 OPEN BRANCH FROM BUS 73118 [LOVE E 115.00] TO BUS 73499 [CROSSRDS 115.00] CKT 1

LOVE W 115.00-LOVEWTAP 115.00 #1 OPEN BRANCH FROM BUS 73120 [LOVE W 115.00] TO BUS 73124 [LOVEWTAP 115.00] CKT 1

LOVEWTAP 115.00-VALLEYLM 115.00 #1 OPEN BRANCH FROM BUS 73124 [LOVEWTAP 115.00] TO BUS 73373 [VALLEYLM 115.00] CKT 1 LYMAN 115.00-LYMANTP 115.00 #1 OPEN BRANCH FROM BUS 73126 [LYMAN 115.00] TO BUS 73256 [LYMANTP 115.00] CKT 1

LYONS 115.00-DOWE FLATS 115.00 #1 OPEN BRANCH FROM BUS 73127 [LYONS 115.00] TO BUS 72407 [DOWE FLATS 115.00] CKT 1

DOWE FLATS 115.00-ROCKMTCM 115.00 #1 OPEN BRANCH FROM BUS 72407 [DOWE FLATS 115.00] TO BUS 73171 [ROCKMTCM 115.00] CKT 1 LYONS 115.00-WAGONWHL 115.00 #1 OPEN BRANCH FROM BUS 73127 [LYONS 115.00] TO BUS 73556 [WAGONWHL 115.00] CKT 1

MAY 115.00-OASISTAP 115.00 #1 OPEN BRANCH FROM BUS 73128 [MAY 115.00] TO BUS 73146 [OASISTAP 115.00] CKT 1

MCKENZIE 69.000-MARYLKSB 69.000 #1 OPEN BRANCH FROM BUS 73132 [MCKENZIE 69.000] TO BUS 73436 [MARYLKSB 69.000] CKT 1 MED BOW 115.00-MEDBOWTP 115.00 #1 OPEN BRANCH FROM BUS 73134 [MED BOW 115.00] TO BUS 73362 [MEDBOWTP 115.00] CKT 1

MIRACLEM 115.00-SEMINOTP 115.00 #1 OPEN BRANCH FROM BUS 73137 [MIRACLEM 115.00] TO BUS 73177 [SEMINOTP 115.00] CKT 1

MIRACLEM 115.00-MEDBOWTP 115.00 #1 OPEN BRANCH FROM BUS 73137 [MIRACLEM 115.00] TO BUS 73362 [MEDBOWTP 115.00] CKT 1 MYERS 115.00-MYERS TP 115.00 #1 OPEN BRANCH FROM BUS 73139 [MYERS 115.00] TO BUS 73140 [MYERS TP 115.00] CKT 1

MYERS TP 115.00-POLE CK 115.00 #1 OPEN BRANCH FROM BUS 73140 [MYERS TP 115.00] TO BUS 73154 [POLE CK 115.00] CKT 1

NUNN 115.00-ROCKPRTP 115.00 #1 OPEN BRANCH FROM BUS 73145 [NUNN 115.00] TO BUS 73172 [ROCKPRTP 115.00] CKT 1 NUNN 115.00-AULT 115.00 #1 OPEN BRANCH FROM BUS 73145 [NUNN 115.00] TO BUS 73552 [AULT 115.00] CKT 1

OASISTAP 115.00-MEDBOWTP 115.00 #1 OPEN BRANCH FROM BUS 73146 [OASISTAP 115.00] TO BUS 73362 [MEDBOWTP 115.00] CKT 1

POLE CK 115.00-QUALLS 115.00 #1 OPEN BRANCH FROM BUS 73154 [POLE CK 115.00] TO BUS 73161 [QUALLS 115.00] CKT 1 POLE CK 115.00-ROUNDTOP 115.00 #1 OPEN BRANCH FROM BUS 73154 [POLE CK 115.00] TO BUS 73173 [ROUNDTOP 115.00] CKT 1

POUDRE 115.00-RICHRDTP 115.00 #1 OPEN BRANCH FROM BUS 73156 [POUDRE 115.00] TO BUS 73466 [RICHRDTP 115.00] CKT 1

RICHARDS 115.00-WAVER PV 115.00 #1 OPEN BRANCH FROM BUS 73169 [RICHARDS 115.00] TO BUS 73469 [WAVER PV 115.00] CKT 1 ROCKPRTP 115.00-OWL_CRK 115.00 #1 OPEN BRANCH FROM BUS 73172 [ROCKPRTP 115.00] TO BUS 73597 [OWL_CRK 115.00] CKT 1

ROUNDTOP 115.00-SENTINEL 115.00 #1 OPEN BRANCH FROM BUS 73173 [ROUNDTOP 115.00] TO BUS 73178 [SENTINEL 115.00] CKT 1

SEMINOE 115.00-SEMINOTP 115.00 #1 OPEN BRANCH FROM BUS 73176 [SEMINOE 115.00] TO BUS 73177 [SEMINOTP 115.00] CKT 1


CONTINGENCY EVENTS

SPRINGCK 115.00-FTSANDER 115.00 #1 OPEN BRANCH FROM BUS 73187 [SPRINGCK 115.00] TO BUS 73367 [FTSANDER 115.00] CKT 1

STEGALL 115.00-LINGLETP 115.00 #1 OPEN BRANCH FROM BUS 73189 [STEGALL 115.00] TO BUS 73255 [LINGLETP 115.00] CKT 1 STEGALL 115.00-LYMANTP 115.00 #1 OPEN BRANCH FROM BUS 73189 [STEGALL 115.00] TO BUS 73256 [LYMANTP 115.00] CKT 1

TERRY 115.00-CNTYLINE 115.00 #1 OPEN BRANCH FROM BUS 73196 [TERRY 115.00] TO BUS 73465 [CNTYLINE 115.00] CKT 1

TERRY 115.00-ERIE SW 115.00 #1 OPEN BRANCH FROM BUS 73196 [TERRY 115.00] TO BUS 73503 [ERIE SW 115.00] CKT 1 TERRY 115.00-GLDNPNDS 115.00 #1 OPEN BRANCH FROM BUS 73196 [TERRY 115.00] TO BUS 73578 [GLDNPNDS 115.00] CKT 1

TIMNATH 115.00-RICHRDTP 115.00 #1 OPEN BRANCH FROM BUS 73200 [TIMNATH 115.00] TO BUS 73466 [RICHRDTP 115.00] CKT 1

TIMNATH 115.00-BOXELDER 115.00 #1 OPEN BRANCH FROM BUS 73200 [TIMNATH 115.00] TO BUS 73553 [BOXELDER 115.00] CKT 1 WELD LM 115.00-BOOMERNG 115.00 #1 OPEN BRANCH FROM BUS 73211 [WELD LM 115.00] TO BUS 73554 [BOOMERNG 115.00] CKT 1

WELD LM 115.00-WHITNEY 115.00 #1 OPEN BRANCH FROM BUS 73211 [WELD LM 115.00] TO BUS 73558 [WHITNEY 115.00] CKT 1

WINDSOR 115.00-WINDSORT 115.00 #1 OPEN BRANCH FROM BUS 73218 [WINDSOR 115.00] TO BUS 73433 [WINDSORT 115.00] CKT 1 MARYLKPP 115.00-MARYLKTP 115.00 #1 OPEN BRANCH FROM BUS 73231 [MARYLKPP 115.00] TO BUS 73233 [MARYLKTP 115.00] CKT 1

MARYLKSB 115.00-MARYLKTP 115.00 #1 OPEN BRANCH FROM BUS 73232 [MARYLKSB 115.00] TO BUS 73233 [MARYLKTP 115.00] CKT 1

LINGLETP 115.00-WHTROCK 115.00 #1 OPEN BRANCH FROM BUS 73255 [LINGLETP 115.00] TO BUS 73568 [WHTROCK 115.00] CKT 1 LYMANTP 115.00-WHTROCK 115.00 #1 OPEN BRANCH FROM BUS 73256 [LYMANTP 115.00] TO BUS 73568 [WHTROCK 115.00] CKT 1

TEKLA 230.00-PUMPKIN 230.00 #1 OPEN BRANCH FROM BUS 73276 [TEKLA 230.00] TO BUS 76400 [PUMPKIN_BTS 230.00] CKT 1

BELLEVUE 115.00-BELLVUTP 115.00 #1 OPEN BRANCH FROM BUS 73297 [BELLEVUE 115.00] TO BUS 73298 [BELLVUTP 115.00] CKT 1 BELLVUTP 115.00-RIPPLE 115.00 #1 OPEN BRANCH FROM BUS 73298 [BELLVUTP 115.00] TO BUS 73325 [RIPPLE 115.00] CKT 1

JACKLOPE 115.00-WARMSPGS 115.00 #1 OPEN BRANCH FROM BUS 73354 [JACKLOPE 115.00] TO BUS 73364 [WARMSPGS 115.00] CKT 1

MEDBOWHS 115.00-MEDBOWTP 115.00 #1 OPEN BRANCH FROM BUS 73361 [MEDBOWHS 115.00] TO BUS 73362 [MEDBOWTP 115.00] CKT 1 WARMSPGS 115.00-EMI TAP 115.00 #1 OPEN BRANCH FROM BUS 73364 [WARMSPGS 115.00] TO BUS 73611 [EMI TAP 115.00] CKT 1

WAGNHNDS 115.00-WAGHN NT 115.00 #1 OPEN BRANCH FROM BUS 73366 [WAGNHNDS 115.00] TO BUS 73607 [WAGHN NT 115.00] CKT 1

WAGNHNDS 115.00-EMI TAP 115.00 #1 OPEN BRANCH FROM BUS 73366 [WAGNHNDS 115.00] TO BUS 73611 [EMI TAP 115.00] CKT 1 VALLEYLM 115.00-DERBHILT 115.00 #1 OPEN BRANCH FROM BUS 73373 [VALLEYLM 115.00] TO BUS 73595 [DERBHILT 115.00] CKT 1

WARRENLM 115.00-NTHRNGE 115.00 #1 OPEN BRANCH FROM BUS 73375 [WARRENLM 115.00] TO BUS 74039 [NORTHRNG 115.00] CKT 1

WINDSORT 115.00-WHITNEY 115.00 #1 OPEN BRANCH FROM BUS 73433 [WINDSORT 115.00] TO BUS 73558 [WHITNEY 115.00] CKT 1 ROGERSRD 115.00-GLDNPNDS 115.00 #1 OPEN BRANCH FROM BUS 73437 [ROGERSRD 115.00] TO BUS 73578 [GLDNPNDS 115.00] CKT 1

DIXON CK 230.00-COLLEGLK 230.00 #1 OPEN BRANCH FROM BUS 73467 [DIXON CK 230.00] TO BUS 73470 [COLLEGLK 230.00] CKT 1

DIXON CK 230.00-HORSESHO 230.00 #1 OPEN BRANCH FROM BUS 73467 [DIXON CK 230.00] TO BUS 73535 [HORSESHO 230.00] CKT 1 RINNVALL 115.00-DACONO 115.00 #1 OPEN BRANCH FROM BUS 73501 [RINNVALL 115.00] TO BUS 73502 [DACONO 115.00] CKT 1

DACONO 115.00-ERIE SW 115.00 #1 OPEN BRANCH FROM BUS 73502 [DACONO 115.00] TO BUS 73503 [ERIE SW 115.00] CKT 1

PONNEQUI 115.00-OWL_CRK 115.00 #1 OPEN BRANCH FROM BUS 73504 [PONNEQUI 115.00] TO BUS 73597 [OWL_CRK 115.00] CKT 1


October 25, 2016 | 25

CONTINGENCY EVENTS

CHEYENNE 230.00-SNOWYRNG 230.00 #1 OPEN BRANCH FROM BUS 73536 [CHEYENNE 230.00] TO BUS 73571 [SNOWYRNG 230.00] CKT 1

CHEYENNE 230.00-TERRY_RANCH 230.00 #1 OPEN BRANCH FROM BUS 73536 [CHEYENNE 230.00] TO BUS 73488 [TERRY_RANCH 230.00] CKT 1 BRACEWLL 115.00-WHITNEY 115.00 #1 OPEN BRANCH FROM BUS 73555 [BRACEWLL 115.00] TO BUS 73558 [WHITNEY 115.00] CKT 1

BRACEWLL 115.00-WHITNEY 115.00 #2 OPEN BRANCH FROM BUS 73555 [BRACEWLL 115.00] TO BUS 73558 [WHITNEY 115.00] CKT 2

SNOWYRNG 230.00-MIRACLEM 230.00 #1 OPEN BRANCH FROM BUS 73571 [SNOWYRNG 230.00] TO BUS 73572 [MIRACLEM 230.00] CKT 1 WHEATLND 69.000-LAR.RIVR 69.000 #1 OPEN BRANCH FROM BUS 73602 [WHEATLND 69.000] TO BUS 73603 [LAR.RIVR 69.000] CKT 1

EMIGRNT 115.00-EMI TAP 115.00 #1 OPEN BRANCH FROM BUS 73610 [EMIGRNT 115.00] TO BUS 73611 [EMI TAP 115.00] CKT 1

CHEY_S 115.00-SWANRNCH 115.00 #1 OPEN BRANCH FROM BUS 74037 [CHEY_S 115.00] TO BUS 74040 [SWANRNCH 115.00] CKT 1 W.CHEY 115.00-SWANRNCH 115.00 #1 OPEN BRANCH FROM BUS 74038 [W.CHEY 115.00] TO BUS 74040 [SWANRNCH 115.00] CKT 1

W.CHEY 115.00-G7WNDHI #1 OPEN BRANCH FROM BUS 74038 [W.CHEY 115.00] TO BUS 74067 [G7WNDHI 115.00] CKT 1

PUMPKIN 230.00-BARBERCK 230.00 #1 OPEN BRANCH FROM BUS 76400 [PUMPKIN_BTS 230.00] TO BUS 76401 [BARBERCK 230.00] CKT 1 CHEY_S 115.00-CORLETT 115.00 #1 OPEN BRANCH FROM BUS 74037 [CHEY_S 115.00] TO BUS 73348 [CORLETT 115.00] CKT 1

NTHRNGE 115.00-CORLETT 115.00 #1 OPEN BRANCH FROM BUS 74039 [NORTHRNG 115.00] TO BUS 73348 [CORLETT 115.00] CKT 1

TRR-AULT+ARH-AULT DBLCKT OPEN BRANCH FROM BUS 73009 [ARCHER 230.00] TO BUS 73011 [AULT 230.00] CKT 1 OPEN BRANCH FROM BUS 73011 [AULT 230.00] TO BUS 73488 [TERRY_RANCH 230.00] CKT 1

RAWHIDE 24.000-RAWHIDE 230.00 #U1 OPEN BRANCH FROM BUS 70350 [RAWHIDE 24.000] TO BUS 73165 [RAWHIDE 230.00] CKT U1

RAWHIDEA 13.800-RAWHIDE 230.00 #UA OPEN BRANCH FROM BUS 70351 [RAWHIDEA 13.800] TO BUS 73165 [RAWHIDE 230.00] CKT UA PONNEQUI 26.100-PONNEQUI 115.00 #U1 OPEN BRANCH FROM BUS 70503 [PONNEQUI 26.100] TO BUS 73504 [PONNEQUI 115.00] CKT U1

RAWHIDEF 18.000-RAWHIDE 230.00 #UF OPEN BRANCH FROM BUS 70561 [RAWHIDEF 18.000] TO BUS 73165 [RAWHIDE 230.00] CKT UF

RAWHIDED 13.800-RAWHIDE 230.00 #UD OPEN BRANCH FROM BUS 70567 [RAWHIDED 13.800] TO BUS 73165 [RAWHIDE 230.00] CKT UD RAWHIDEB 13.800-RAWHIDE 230.00 #UB OPEN BRANCH FROM BUS 70568 [RAWHIDEB 13.800] TO BUS 73165 [RAWHIDE 230.00] CKT UB

RAWHIDEC 13.800-RAWHIDE 230.00 #UC OPEN BRANCH FROM BUS 70569 [RAWHIDEC 13.800] TO BUS 73165 [RAWHIDE 230.00] CKT UC

ALCOVA 115.00-ALCOVA1 6.6000 #1 OPEN BRANCH FROM BUS 73004 [ALCOVA 115.00] TO BUS 73332 [ALCOVA1 6.9000] CKT 1 ALCOVA 115.00-ALCOVA2 6.6000 #1 OPEN BRANCH FROM BUS 73004 [ALCOVA 115.00] TO BUS 73438 [ALCOVA2 6.9000] CKT 1

AULT 230.00-AULT 345.00 #1 OPEN BRANCH FROM BUS 73011 [AULT 230.00] TO BUS 73012 [AULT 345.00] CKT 1

AULT 230.00-AULT 345.00 #2 OPEN BRANCH FROM BUS 73011 [AULT 230.00] TO BUS 73012 [AULT 345.00] CKT 2 AULT 230.00-AULT 345.00 #3 OPEN BRANCH FROM BUS 73011 [AULT 230.00] TO BUS 73012 [AULT 345.00] CKT 3

BOYD 115.00-BOYD 230.00 #1 OPEN BRANCH FROM BUS 73026 [BOYD 115.00] TO BUS 73027 [BOYD 230.00] CKT 1

BOYD 115.00-BOYD 230.00 #2 OPEN BRANCH FROM BUS 73026 [BOYD 115.00] TO BUS 73027 [BOYD 230.00] CKT 2 DIXON CK 115.00-DIXON CK 230.00 #1 OPEN BRANCH FROM BUS 73051 [DIXON CK 115.00] TO BUS 73467 [DIXON CK 230.00] CKT 1

DIXON CK 115.00-DIXON CK 230.00 #2 OPEN BRANCH FROM BUS 73051 [DIXON CK 115.00] TO BUS 73467 [DIXON CK 230.00] CKT 2

ESTES 115.00-ESTES1 6.9000 #1 OPEN BRANCH FROM BUS 73056 [ESTES 115.00] TO BUS 73306 [ESTES1 6.9000] CKT 1


CONTINGENCY EVENTS

ESTES 115.00-ESTES2 6.9000 #1 OPEN BRANCH FROM BUS 73056 [ESTES 115.00] TO BUS 73307 [ESTES2 6.9000] CKT 1

ESTES 115.00-ESTES3 6.9000 #1 OPEN BRANCH FROM BUS 73056 [ESTES 115.00] TO BUS 73308 [ESTES3 6.9000] CKT 1 FLATIRON 115.00-FLATIRN1 13.800 #1 OPEN BRANCH FROM BUS 73058 [FLATIRON 115.00] TO BUS 73448 [FLATIRN1 13.800] CKT 1

FLATIRON 115.00-FLATIRN2 13.800 #1 OPEN BRANCH FROM BUS 73058 [FLATIRON 115.00] TO BUS 73449 [FLATIRN2 13.800] CKT 1

FORDHAM 115.00-FORDHAM 230.00 #1 OPEN BRANCH FROM BUS 73060 [FORDHAM 115.00] TO BUS 73562 [FORDHAM 230.00] CKT 1 FORDHAM 115.00-FORDHAM 230.00 #2 OPEN BRANCH FROM BUS 73060 [FORDHAM 115.00] TO BUS 73562 [FORDHAM 230.00] CKT 2

FREMONT 115.00-FREMONT1 12.000 #1 OPEN BRANCH FROM BUS 73062 [FREMONT 115.00] TO BUS 73349 [FREMONT1 11.500] CKT 1

FREMONT 115.00-FREMONT2 12.000 #1 OPEN BRANCH FROM BUS 73062 [FREMONT 115.00] TO BUS 73350 [FREMONT2 11.500] CKT 1 GLENDO 115.00-GLENDO1 6.9000 #1 OPEN BRANCH FROM BUS 73069 [GLENDO 115.00] TO BUS 73351 [GLENDO1 6.9000] CKT 1

GLENDO 115.00-GLENDO2 6.9000 #1 OPEN BRANCH FROM BUS 73069 [GLENDO 115.00] TO BUS 73352 [GLENDO2 6.9000] CKT 1

HORSESHO 115.00-HORSESHO 230.00 #1 OPEN BRANCH FROM BUS 73086 [HORSESHO 115.00] TO BUS 73535 [HORSESHO 230.00] CKT 1 HORSESHO 115.00-HORSESHO 230.00 #2 OPEN BRANCH FROM BUS 73086 [HORSESHO 115.00] TO BUS 73535 [HORSESHO 230.00] CKT 2

KORTES 115.00-KORTES1 6.9000 #1 OPEN BRANCH FROM BUS 73099 [KORTES 115.00] TO BUS 73356 [KORTES1 6.9000] CKT 1

KORTES 115.00-KORTES2 6.9000 #1 OPEN BRANCH FROM BUS 73099 [KORTES 115.00] TO BUS 73357 [KORTES2 6.9000] CKT 1 KORTES 115.00-KORTES3 6.9000 #1 OPEN BRANCH FROM BUS 73099 [KORTES 115.00] TO BUS 73358 [KORTES3 6.9000] CKT 1

LAR.RIVR 230.00-LAR.RIVR 345.00 #1 OPEN BRANCH FROM BUS 73107 [LAR.RIVR 230.00] TO BUS 73108 [LAR.RIVR 345.00] CKT 1

LAR.RIVR 230.00-LAR.RIVR 345.00 #2 OPEN BRANCH FROM BUS 73107 [LAR.RIVR 230.00] TO BUS 73108 [LAR.RIVR 345.00] CKT 2 LAR.RIVR 230.00-LAR.RIVR 69.000 #1 OPEN BRANCH FROM BUS 73107 [LAR.RIVR 230.00] TO BUS 73603 [LAR.RIVR 69.000] CKT 1

LAR.RIVR 345.00-MBPP-1 24.000 #1 OPEN BRANCH FROM BUS 73108 [LAR.RIVR 345.00] TO BUS 73129 [MBPP-1 24.000] CKT 1

LAR.RIVR 345.00-MBPP-2 24.000 #1 OPEN BRANCH FROM BUS 73108 [LAR.RIVR 345.00] TO BUS 73130 [MBPP-2 24.000] CKT 1 LONGPEAK 115.00-LONGPEAK 230.00 #1 OPEN BRANCH FROM BUS 73115 [LONGPEAK 115.00] TO BUS 73116 [LONGPEAK 230.00] CKT 1

LONGPEAK 115.00-LONGPEAK 230.00 #2 OPEN BRANCH FROM BUS 73115 [LONGPEAK 115.00] TO BUS 73116 [LONGPEAK 230.00] CKT 2

POLEHILL 115.00-POLEHILL 13.800 #1 OPEN BRANCH FROM BUS 73155 [POLEHILL 115.00] TO BUS 73324 [POLEHILL 13.800] CKT 1 SEMINOE 115.00-SMNOE1-2 6.9000 #1 OPEN BRANCH FROM BUS 73176 [SEMINOE 115.00] TO BUS 73363 [SEMINOE1-2 6.9000] CKT 1

SEMINOE 115.00-SEMINOE3 6.9000 #1 OPEN BRANCH FROM BUS 73176 [SEMINOE 115.00] TO BUS 73441 [SEMINOE3 6.9000] CKT 1

TIMBERLN 115.00-TIMBERLN 230.00 #3 OPEN BRANCH FROM BUS 73198 [TIMBERLN 115.00] TO BUS 73199 [TIMBERLN 230.00] CKT 3 TIMBERLN 115.00-TIMBERLN 230.00 #4 OPEN BRANCH FROM BUS 73198 [TIMBERLN 115.00] TO BUS 73199 [TIMBERLN 230.00] CKT 4

WELD LM 115.00-WELD LM 230.00 #1 OPEN BRANCH FROM BUS 73211 [WELD LM 115.00] TO BUS 73212 [WELD LM 230.00] CKT 1

MARYLKPP 115.00-MARYLKPP 6.9000 #1 OPEN BRANCH FROM BUS 73231 [MARYLKPP 115.00] TO BUS 73319 [MARYLKPP 6.9000] CKT 1 MARYLKSB 115.00-MARYLKSB 69.000 #1 OPEN BRANCH FROM BUS 73232 [MARYLKSB 115.00] TO BUS 73436 [MARYLKSB 69.000] CKT 1

LIMESTON 115.00-LIMESTON 34.500 #1 OPEN BRANCH FROM BUS 73359 [LIMESTON 115.00] TO BUS 73360 [LIMESTON 34.500] CKT 1

WHTROCK 115.00-WHTROCK 34.500 #1 OPEN BRANCH FROM BUS 73568 [WHTROCK 115.00] TO BUS 73569 [WHTROCK 34.500] CKT 1


October 25, 2016 | 27

CONTINGENCY EVENTS

CHEY_S 115.00-TERRY_RANCH 230.00 #1 OPEN BRANCH FROM BUS 74037 [CHEY_S 115.00] TO BUS 73488 [TERRY_RANCH 230.00] CKT 1

2004-G1 34.500-HJWIND 115.00 #1 OPEN BRANCH FROM BUS 74045 [2004-G1 34.500] TO BUS 74048 [HJWIND 115.00] CKT 1 SSWIND 34.500-HJWIND 115.00 #1 OPEN BRANCH FROM BUS 74047 [SSWIND 34.500] TO BUS 74048 [HJWIND 115.00] CKT 1

ARCHER 230.00-ARCHER 115.00-ARH 13.8A 13.800 #1 OPEN BRANCH FROM BUS 73009 [ARCHER 230.00] TO BUS 73008 [ARCHER 115.00] TO BUS 73486 [ARH 13.8A 13.800] CKT 1

ARCHER 230.00-ARCHER 115.00-ARH_LVB 13.800 #2 OPEN BRANCH FROM BUS 73009 [ARCHER 230.00] TO BUS 73008 [ARCHER 115.00] TO BUS 73487 [ARH 13.8B 13.800] CKT 2 AULT 230.00-AULT 115.00 #1 OPEN BRANCH FROM BUS 73011 [AULT 230.00] TO BUS 73552 [AULT 115.00] TO BUS 73550 [AULT 13.800] CKT 1

SNOWYRNG 230.00-SNOWYRNG 115.00-SNG_LV A 13.800 #1 OPEN BRANCH FROM BUS 73571 [SNOWYRNG 230.00] TO BUS 73570 [SNOWYRNG 115.00] TO BUS 73622 [SNG_LV A 13.800] CKT 1

SNOWYRNG 230.00-SNOWYRNG 115.00-SNG_LV B 13.800 #2 OPEN BRANCH FROM BUS 73571 [SNOWYRNG 230.00] TO BUS 73570 [SNOWYRNG 115.00] TO BUS 73623 [SNG_LV B 13.800] CKT 2 MIRACLEM 230.00-MIRACLEM 115.00-MM_LV A 13.800 #1 OPEN BRANCH FROM BUS 73572 [MIRACLEM 230.00] TO BUS 73137 [MIRACLEM 115.00] TO BUS 73618 [MM_LV A 13.800] CKT 1

MIRACLEM 230.00-MIRACLEM 115.00-MM_LV B 13.800 #2 OPEN BRANCH FROM BUS 73572 [MIRACLEM 230.00] TO BUS 73137 [MIRACLEM 115.00] TO BUS 73619 [MM_LV B 13.800] CKT 2

CHEYENNE 230.00-CHEYENNE 115.00-CH 13.8A 13.800 #1 OPEN BRANCH FROM BUS 73043 [CHEYENNE 115.00] TO BUS 73536 [CHEYENNE 230.00] TO BUS 73645 [CH 13.8A 13.800] CKT 1 CHEYENNE 230.00-CHEYENNE 115.00-CH 13.8B 13.800 #2 OPEN BRANCH FROM BUS 73043 [CHEYENNE 115.00] TO BUS 73536 [CHEYENNE 230.00] TO BUS 73545 [CH 13.8B 13.800] CKT 2

PONNEQUI 26.100 W1 REMOVE UNIT W1 FROM BUS 70503 [PONNEQUI 26.100]

MBPP-1 24.000 1 REMOVE UNIT 1 FROM BUS 73129 [MBPP-1 24.000] MBPP-2 24.000 1 REMOVE UNIT 1 FROM BUS 73130 [MBPP-2 24.000]

POLEHILL 13.800 1 REMOVE UNIT 1 FROM BUS 73324 [POLEHILL 13.800]

ALCOVA1 6.6000 1 REMOVE UNIT 1 FROM BUS 73332 [ALCOVA1 6.9000] FREMONT1 12.000 1 REMOVE UNIT 1 FROM BUS 73349 [FREMONT1 11.500]

FREMONT2 12.000 1 REMOVE UNIT 1 FROM BUS 73350 [FREMONT2 11.500]

GLENDO1 6.9000 1 REMOVE UNIT 1 FROM BUS 73351 [GLENDO1 6.9000] GLENDO2 6.9000 1 REMOVE UNIT 1 FROM BUS 73352 [GLENDO2 6.9000]

GUERNSY1 2.4000 1 REMOVE UNIT 1 FROM BUS 73353 [GUERNSY1 2.4000]

KORTES1 6.9000 1 REMOVE UNIT 1 FROM BUS 73356 [KORTES1 6.9000] KORTES2 6.9000 1 REMOVE UNIT 1 FROM BUS 73357 [KORTES2 6.9000]

KORTES3 6.9000 1 REMOVE UNIT 1 FROM BUS 73358 [KORTES3 6.9000]

SMNOE1-2 6.9000 1 REMOVE UNIT 1 FROM BUS 73363 [SEMINOE1-2 6.9000] SMNOE1-2 6.9000 2 REMOVE UNIT 2 FROM BUS 73363 [SEMINOE1-2 6.9000]

ALCOVA2 6.6000 1 REMOVE UNIT 1 FROM BUS 73438 [ALCOVA2 6.9000]

SEMINOE3 6.9000 1 REMOVE UNIT 1 FROM BUS 73441 [SEMINOE3 6.9000] GUERNSY2 2.4000 2 REMOVE UNIT 2 FROM BUS 73444 [GUERNSY2 2.4000]

FLATIRN1 13.800 2 REMOVE UNIT 2 FROM BUS 73448 [FLATIRN1 13.800]



CONTINGENCY EVENTS


CLR_1 0.6000 1 REMOVE UNIT 1 FROM BUS 74042 [CLR_1 0.6000] SS_GEN1 0.6000 1 REMOVE UNIT 1 FROM BUS 74043 [SS_GEN1 0.6000]

G7_GEN1 0.6000 G1 REMOVE UNIT G1 FROM BUS 74066 [G7WNDLO 0.7000]

CHEY-TR+CHEY-OWL DBLCKT OPEN BRANCH FROM BUS 73536 [CHEYENNE 230.00] TO BUS 73488 [TERRY_RANCH 230.00] CKT 1 OPEN LINE FROM BUS 73504 [PONNEQUI 115.00] TO BUS 73597 [OWL_CRK 115.00] CKT 1

OPEN LINE FROM BUS 73504 [PONNEQUI 115.00] TO BUS 70503 [PONNEQUI 26.100] CKT U1

OPEN LINE FROM BUS 73504 [PONNEQUI 115.00] TO BUS 73043 [CHEYENNE 115.00] CKT 1 CH-HJ+CH-SNOWY DBLCKT OPEN BRANCH FROM BUS 73536 [CHEYENNE 230.00] TO BUS 73488 [TERRY_RANCH 230.00] CKT 1

OPEN BRANCH FROM BUS 73536 [CHEYENNE 230.00] TO BUS 73571 [SNOWYRNG 230.00] CKT 1

SCHEY-LGIRG7 115 DBLCKT OPEN LINE FROM BUS 73348 [CORLETT 115.00] TO BUS 74037 [CHEY_S 115.00] CKT 1 OPEN LINE FROM BUS 73348 [CORLETT 115.00] TO BUS 74039 [NORTHRNG 115.00] CKT 1

OPEN LINE FROM BUS 74040 [SWANRNCH 115.00] TO BUS 74038 [W.CHEY 115.00] CKT 1

OPEN LINE FROM BUS 74040 [SWANRNCH 115.00] TO BUS 74037 [CHEY_S 115.00] CKT 1 LRS-WCHILD-KEOTA 345 OPEN BRANCH FROM BUS 73108 [LAR.RIVR 345.00] TO BUS 72811 [WL_CHILD 345.00] CKT 1

OPEN BRANCH FROM BUS 72811 [WL_CHILD 345.00] TO BUS 72140 [KEOTA 345.00] CKT 1

ARCH-CHEY N&S 115 OPEN BRANCH FROM BUS 73008 [ARCHER 115.00] TO BUS 73043 [CHEYENNE 115.00] CKT 1 OPEN LINE FROM BUS 73480 [CROWCRK 115.00] TO BUS 73008 [ARCHER 115.00] CKT 1

OPEN LINE FROM BUS 73480 [CROWCRK 115.00] TO BUS 73043 [CHEYENNE 115.00] CKT 1

LGIR-G7 OPEN LINE FROM BUS 74066 [G7WNDLO 0.7000] TO BUS 74069 [G7WNDMI 34.500] CKT WD OPEN LINE FROM BUS 74069 [G7WNDMI 34.500] TO BUS 74068 [G7WNDMID 34.500] CKT 1

OPEN LINE FROM BUS 74068 [G7WNDMID 34.500] TO BUS 74067 [G7WNDHI 115.00] CKT WD

OPEN LINE FROM BUS 74067 [G7WNDHI 115.00] TO BUS 74038 [W.CHEY 115.00] CKT 1 CPGSTN_1 OPEN LINE FROM BUS 74061 [CPGSTN_1 13.800] TO BUS 74060 [CPGSTN 115.00] CKT U1

CPGSTN_2 OPEN LINE FROM BUS 74062 [CPGSTN_2 13.800] TO BUS 74060 [CPGSTN 115.00] CKT U1

HJK-NRG 115 PO + SCH 230/115 XFMR #1 OPEN BRANCH FROM BUS 73077 [HAPPYJCK 115.00] TO BUS 74039 [NORTHRNG 115.00] CKT 1 OPEN BRANCH FROM BUS 74037 [CHEY_S 115.00] TO BUS 73488 [TERRY_RANCH 230.00] CKT 1

ACH-TR 230 PO + ARH 230/115 XFMR #1 OPEN BRANCH FROM BUS 73488 [TERRY_RANCH 230.00] TO BUS 73009 [ARCHER 230.00] CKT 1

OPEN BRANCH FROM BUS 73009 [ARCHER 230.00] TO BUS 73008 [ARCHER 115.00] TO BUS 73486 [ARH 13.8A 13.800] CKT 1 ACH-TR 230 PO + ARH-CHY 115 LINE OPEN BRANCH FROM BUS 73488 [TERRY_RANCH 230.00] TO BUS 73009 [ARCHER 230.00] CKT 1

OPEN BRANCH FROM BUS 73008 [ARCHER 115.00] TO BUS 73043 [CHEYENNE 115.00] CKT 1

ACH-TR 230 PO + ARH-CPGS 115 LINE OPEN BRANCH FROM BUS 73488 [TERRY_RANCH 230.00] TO BUS 73009 [ARCHER 230.00] CKT 1


October 25, 2016 | 29

CONTINGENCY EVENTS

OPEN BRANCH FROM BUS 73008 [ARCHER 115.00] TO BUS 74060 [CPGSTN 115.00] CKT 1


CLPTG7-2023 File only =============================================================================

CONTINGENCY EVENTS

DAVEJOHN 230.00-LAR.RIVR 230.00 #1 OPEN LINE FROM BUS 72906 [SAWMILLC 230.00] TO BUS 65420 [DAVEJOHN 230.00] CKT 1

OPEN LINE FROM BUS 72906 [SAWMILLC 230.00] TO BUS 73107 [LAR.RIVR 230.00] CKT 1

KERSEYTP 115.00-WILLOBY 115.00 #1 OPEN BRANCH FROM BUS 73095 [KERSEYTP 115.00] TO BUS 73543 [WILLOBY 115.00] CKT 1 W.CHEY 115.00-KINGRNCH 115.00 #1 OPEN BRANCH FROM BUS 74038 [W.CHEY 115.00] TO BUS 74056 [KING RANCH 115.00] CKT 1

LGIR-G7 115.00-W.CHEY 115.00 #1 OPEN BRANCH FROM BUS 74067 [G7WNDHI 115.00] TO BUS 74038 [W.CHEY 115.00] CKT 1

CHEY_S 115.00-CPGSTN 115.00 #1 OPEN BRANCH FROM BUS 74037 [CHEY_S 115.00] TO BUS 74060 [CPGSTN 115.00] CKT 1 CHEY_S 115.00-CPGSTN 115.00 #2 OPEN BRANCH FROM BUS 74037 [CHEY_S 115.00] TO BUS 74060 [CPGSTN 115.00] CKT 2

OPEN BRANCH FROM BUS 73011 [AULT 230.00] TO BUS 73488 [TERRY_RANCH 230.00] CKT 1

WCHILD 345.00-WCHILD 230.00 #1 OPEN BRANCH FROM BUS 72811 [WL_CHILD 345.00] TO BUS 72818 [WL_CHILD 230.00] CKT 1 CPGSTN TIES 115 OPEN BRANCH FROM BUS 74060 [CPGSTN 115.00] TO BUS 74041 [EB PARK 115.00] CKT 1

OPEN BRANCH FROM BUS 74060 [CPGSTN 115.00] TO BUS 73008 [ARCHER 115.00] CKT 1

OPEN LINE FROM BUS 74060 [CPGSTN 115.00] TO BUS 74061 [CPGSTN_1 13.800] CKT U1 OPEN LINE FROM BUS 74060 [CPGSTN 115.00] TO BUS 74062 [CPGSTN_2 13.800] CKT U1

OPEN LINE FROM BUS 74060 [CPGSTN 115.00] TO BUS 74063 [CPGSTN_3 13.800] CKT U1

OPEN LINE FROM BUS 74060 [CPGSTN 115.00] TO BUS 74037 [CHEY_S 115.00] CKT 1 OPEN LINE FROM BUS 74060 [CPGSTN 115.00] TO BUS 74037 [CHEY_S 115.00] CKT 2

CPGSTN-SCHEY 115 DBLCKT OPEN BRANCH FROM BUS 74060 [CPGSTN 115.00] TO BUS 74037 [CHEY_S 115.00] CKT 1

OPEN BRANCH FROM BUS 74060 [CPGSTN 115.00] TO BUS 74037 [CHEY_S 115.00] CKT 2 OPEN LINE FROM BUS 73504 [PONNEQUI 115.00] TO BUS 73597 [OWL_CRK 115.00] CKT 1

OPEN LINE FROM BUS 73504 [PONNEQUI 115.00] TO BUS 70503 [PONNEQUI 26.100] CKT U1

OPEN LINE FROM BUS 73504 [PONNEQUI 115.00] TO BUS 73043 [CHEYENNE 115.00] CKT 1 OPEN BRANCH FROM BUS 73536 [CHEYENNE 230.00] TO BUS 73571 [SNOWYRNG 230.00] CKT 1

OPEN LINE FROM BUS 73348 [CORLETT 115.00] TO BUS 74039 [NORTHRNG 115.00] CKT 1

OPEN LINE FROM BUS 74040 [SWANRNCH 115.00] TO BUS 74038 [W.CHEY 115.00] CKT 1 OPEN LINE FROM BUS 74040 [SWANRNCH 115.00] TO BUS 74037 [CHEY_S 115.00] CKT 1

KINGRNCH-LGIRG7 115 DBLCKT OPEN LINE FROM BUS 73348 [CORLETT 115.00] TO BUS 74037 [CHEY_S 115.00] CKT 1

OPEN LINE FROM BUS 73348 [CORLETT 115.00] TO BUS 74039 [NORTHRNG 115.00] CKT 1 OPEN LINE FROM BUS 74038 [W.CHEY 115.00] TO BUS 74040 [SWANRNCH 115.00] CKT 1

OPEN LINE FROM BUS 74038 [W.CHEY 115.00] TO BUS 74056 [KING RANCH 115.00] CKT 1

OPEN LINE FROM BUS 74038 [W.CHEY 115.00] TO BUS 74067 [G7WNDHI 115.00] CKT 1


October 25, 2016 | 31

CONTINGENCY EVENTS

KINGRNCH-NTHRNGE 115 DBLCKT OPEN BRANCH FROM BUS 74039 [NORTHRNG 115.00] TO BUS 74056 [KING RANCH 115.00] CKT 1

OPEN BRANCH FROM BUS 74039 [NORTHRNG 115.00] TO BUS 74056 [KING RANCH 115.00] CKT 2 OPEN BRANCH FROM BUS 72811 [WL_CHILD 345.00] TO BUS 72140 [KEOTA 345.00] CKT 1

OPEN LINE FROM BUS 73480 [CROWCRK 115.00] TO BUS 73008 [ARCHER 115.00] CKT 1

OPEN LINE FROM BUS 73480 [CROWCRK 115.00] TO BUS 73043 [CHEYENNE 115.00] CKT 1 OPEN LINE FROM BUS 74069 [G7WNDMI 34.500] TO BUS 74068 [G7WNDMID 34.500] CKT 1

OPEN LINE FROM BUS 74068 [G7WNDMID 34.500] TO BUS 74067 [G7WNDHI 115.00] CKT WD

OPEN LINE FROM BUS 74067 [G7WNDHI 115.00] TO BUS 74038 [W.CHEY 115.00] CKT 1 CPGSTN_3 OPEN LINE FROM BUS 74063 [CPGSTN_3 13.800] TO BUS 74060 [CPGSTN 115.00] CKT U1


Appendix C: Transient Stability Results Transient Stability plots provided as a separate document

Disturbance Description

2018HS

(Without C

LPT-G7)

2018HS

(With C

LPT-G7 as N

R1)

2018HS

(With C

LPT-G7 as N

R2)

2018HS

(With C

LPT-G7 as ER

)

2023HS

(Without C

LPT-G7)

2023HS

(With C

LPT-G7 as N

R1)

2023HS

(With C

LPT-G7 as N

R2)

2023HS

(With C

LPT-G7 as ER

)

No Fault (System Intact) Stable Stable Stable Stable Stable Stable Stable Stable

Archer-Cheyenne 115 Stable Stable Stable Stable Stable1 Stable1 Stable1 Stable1

CPGS-Archer 115 Stable Stable Stable Stable Stable1 Stable1 Stable1 Stable1

CPGS-Archer 115 1&2 Stable Stable Stable Stable Stable1 Stable1 Stable1 Stable1

CPGS-East Business Park 115 Stable Stable Stable Stable Stable1 Stable1 Stable1 Stable1

CPGS-South Cheyenne1 115 Stable Stable Stable Stable Stable1 Stable1 Stable1 Stable1

CPGS-South Cheyenne1&2 115 Stable Stable Stable Stable Stable1 Stable1 Stable1 Stable1

Happy Jack-Cheyenne 115 Stable Stable Stable Stable Stable1 Stable1 Stable1 Stable1

Happy Jack-Happy Jack Wind 115 Stable Stable Stable Stable Stable Stable Stable Stable

Happy Jack-North Range 115 Stable Stable Stable Stable Stable1 Stable1 Stable1 Stable1

HJK-NRG 115 PO + SCH 230/115 XFMR #1 Stable Stable Stable Stable Stable1 Stable1 Stable1 Stable1

South Cheyenne-Swan Ranch 115 Stable Stable Stable Stable Stable3 Stable3 Stable3 Stable3

SCH-COR 115 PO + SCH-SWR 115 Stable Stable Stable Stable Stable3 Stable3 Stable3 Stable3

South Cheyenne-Corlett-North Range Stable Stable Stable Stable Stable3 Stable3 Stable3 Stable3

Archer-Ault 230 Stable Stable Stable Stable Stable1 Stable1 Stable1 Stable3

Archer-Terry Ranch 230 Stable Stable Stable Stable Stable1 Stable1 Stable1 Stable1

ACH-TR 230 PO + ARH 230/115 XFMR #1 Stable Stable Stable Stable Stable1 Stable1 Stable1 Stable1

ACH-TR 230 PO + ARH-CHY 115 Line Stable Stable Stable Stable Stable1 Stable1 Stable1 Stable1

ACH-TR 230 PO + ARH-CPGS 115 Line Stable Stable Stable Stable Stable1 Stable1 Stable1 Stable1

Archer-Stegall 230 Stable Stable Stable Stable Stable Stable Stable Stable

Cheyenne-Terry Ranch 230 Stable Stable Stable Stable Stable1 Stable1 Stable1 Stable1

Cheyenne-Snowy Range 230 Stable Stable Stable Stable Stable Stable Stable Stable

Snowy Range-Miracle Mile 230 Stable Stable Stable Stable Stable Stable Stable Stable

Terry Ranch-Ault 230 Stable Stable Stable Stable Stable1 Stable3 Stable1 Stable3

Terry Ranch-North Park 230 Stable Stable Stable Stable Stable Stable Stable Stable


October 25, 2016 | 33

Disturbance Description

2018HS

(Without C

LPT-G7)

2018HS

(With C

LPT-G7 as N

R1)

2018HS

(With C

LPT-G7 as N

R2)

2018HS

(With C

LPT-G7 as ER

)

2023HS

(Without C

LPT-G7)

2023HS

(With C

LPT-G7 as N

R1)

2023HS

(With C

LPT-G7 as N

R2)

2023HS

(With C

LPT-G7 as ER

)

Laramie River Station-Ault 345 Stable Stable Stable Stable Stable1 Stable1 Stable1 Stable1

Archer-Wayne Child 230 Stable Stable Stable Stable Stable1 Stable1 Stable1 Stable1

Wayne Child-Keota 345 Not valid Not valid Not valid Not valid Stable Stable Stable Stable

LRS-Keota 345 (No WC PH2) Stable Stable Stable Stable Not valid Not valid Not valid Not valid

LRS-Wayne Child 345 Stable Stable Stable Stable Stable1 Stable3 Stable3 Stable3

Cheyenne 230/115 XFMR #1 with delayed clearing Stable1,2 Stable1,2 Stable1,2 Stable1,2 Stable1 Stable1 Stable1,2 Stable1

Archer 230/115 XFMR #1 with delayed clearing Stable1,2 Stable1,2 Stable1,2 Stable1,2 Non-

converge Non-

converge Non-

converge Non-

converge SLG Cheyenne 230/115 XFMR #1 with delayed clearing Stable1,2 Stable1,2 Stable1,2 Stable1,2 Stable1 Stable1 Stable1 Stable1

SLG Archer 230/115 XFMR #1 with delayed clearing Stable1,2 Stable1,2 Stable1,2 Stable1,2 Stable1 Stable1 Stable1 Stable1

Note: 1) The Cheyenne Prairie Generating Station independent of the proposed CLPT-G7 project trips off line after the fault is cleared,

due to the operation of the out-of-step relays. 2) The proposed CLPT-G7 project experiences rotor angle stability issues. Black Hills Planning Engineers will coordinate with the

project sponsor regarding the event as it relates to wind turbine control settings.

3) CPSG rotor angles are not fully damped out at 10 seconds. Fault rerun for 20 seconds results in fully dampened rotor angles

Documents

Cheyenne Light, Fuel and Power Transmission System Impact ... · Cheyenne Light, Fuel and Power Transmission System Impact Study CLPT-G7 102 MW Wind Plant near the Corlett 115 kV