Amdt_0004_attch.pdf

SECTION 01 30 00 ATTACHMENTS

INSTALLATION REQUIREMENTS

INDEX

Attachment A

Attachment B

Attachment C

Attachment D

Attachment E

Attachment F

Attachment G

Attachment H

Attachment I

Attachment J

Attachment K

Attachment L

Attachment M

Attachment N

Attachment O

Attachment P

Attachment Q

Attachment R

FLW Electric Service Request Form

FLW Gas Service Request Form

FLW MS4 Permit

Permit Termination Form

Not Used

FLW Excavation (Dig) Permit

FLW Spill Guide and Report Form

FLW Asbestos Compliance - Completion Certificate

FLW Construction and Demolition Waste Management Report Form

FLW Daily Pesticide Report Form

As-Built Instructions

Storm Water Pollution Prevention Plan

FLW iWATCH Army Brochure

Installation Control for Unescorted Access of Uncleared Contractors

DPW Water Construction Requirements

Water and Sewer Permit Application Process

New Source Review Permit - MDNR Permit to Construct

Laclede Electric Interconnect Study

Attachment R

LACLEDE ELECTRIC COOPERATIVE

LEBANON, MISSOURI

FLW Boiler Plant ‐ Building 2369 Impact Study

This page was intentionally left blank for duplex printing.

MISSOURI‐43‐LACLEDE

October 4, 2018

‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐Prepared By‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐‐

Laclede Electric Cooperative

Engineering Department

MISSOURI‐43‐LACLEDE

Table of Contents

Page

I. Introduction and Executive Summary………………………….………………………..……..…… I‐1

II. Application for Interconnection…………………………………………………………………………. II‐1

III. Operation of Interconnected Generation……………….……………………………..…..……… III‐1

IV. Impact on Electric Power System Equipment Loading Under Steady State

Conditions……………………………………………………………………………………………..…..……… IV‐1

V. Impacts on Voltage Regulation within the Electric Power System Under Steady

State……….……………………………………………………………………………………………..…..……… V‐1

VI. Calculations – Case Studies…………………….………………..………………….………..…..……… VI‐1

VII. Impacts on System Protection, Fault Conditions and Arc Flash Rating……….……… VII‐1

VIII. Impacts on Electric Power System Power Quality……..…………………………..…..……… VIII‐1

IX. CHP Interconnection Cost Proposal…………………………..…………………………..…..……… IX‐1

X. FLW #2 Substation One Line Diagram…………………………….……...............……………… X‐1

I‐1

I. Introduction and Executive Summary

A. Introduction

The purpose of this report is to evaluate the impact of the proposed Fort Leonard Wood (FLW)

Boiler Plant Generator on the Laclede Electric Cooperative (LEC) electric system. The evaluation will follow the guidelines of IEEE Standard 1547.7.2013 “IEEE Guide to Conducting Distribution Impact

Studies for Distributed Resource Interconnection.” For the interconnection to be beneficial to both the generating entity desiring interconnection and to the existing electrical power system (EPS), continued safe and reliable operation of the electrical power system should be sought as a primary goal.

The main purpose of the evaluation is to determine potential impacts to the EPS and the power quality of services located on the same substation and feeder as the FLW Boiler Plant. Any potential negative impacts should be reviewed and corrected so that LEC service quality is maintained at it’s current level.

The Boiler Plant generator will be located at Fort Leonard Wood in the area of FLW Substation

#2 (also sometimes referred to as LEC Substation #29). This substation is owned by Sho‐Me Power

Electric Cooperative. The proposed generator will be located on Feeder #2 (operating at 7.2/12.47 kV), but will also have a (normally open) tie to Feeder #3. Feeder #2 has several other ties to Feeder #3 as well as a tie to Feeder #1. Feeder #2 and #3 run southeast of the substation along Oklahoma Avenue.

Feeder #2 is considered the more ideal feeder for the generator because it is more heavily loaded and it is shorter length (feeder #3 extends far to the southeast down to the golf course and other FLW classrooms and training facilities).

The proposed Boiler Plant Generator site will be located at building 2369 and will use a combined heat and power system (CHP) to generate electricity. At present the EPS serves three transformers at the plant. A generator step up transformer (GSU) will be installed to convert power from the 4.16kV generated by the plant to the 12.47kV of the EPS. When running, the 2.5 MW generator will feed the three existing transformers as well as the rest of the feeder. Any power generated in excess of the feeder demand will flow in reverse mode back to the substation to serve some or the rest of the feeder load. Maps 1 and 2 below show the general area.

Additional sections of the report will detail the review process for this generator site. FLW will supply the generator and additional gas compressors, generator auxiliaries and pumps it requires. LEC’s point of common coupling (PCC) will be the low side of the step‐up transformer. LEC equipment necessary to accept this load and protect the LEC system will be supplied by LEC and is detailed elsewhere in this report.

I‐2

Map 1

I‐3

Map 2

I‐4

B. Executive Summary

When the Boiler Plant Generator is operating, the most significant impact will be the expected voltage rise near the generator location and extending out towards other parts of the feeder. When feeder #2 is heavily loaded (which will rarely occur), the voltage rise will be less significant since the generator production is being used up locally. However, under normal circumstances the generator will produce more power than feeder #2 can use and the excess power will flow back towards the substation to supply demand on the other FLW Sub #2 feeders. The greater the difference between the generator production and the feeder #2 demand, the greater the voltage rise will be.

During this time of reverse power flow when the generator has excess power that has not been used by feeder #2, the power will flow from the generator towards the substation, but it will be limited by the substation voltage regulator. The substation voltage regulator is owned and operated by Sho Me

Power and is controlled with a Beckwith Load Tap Changer (LTC). It is currently set for 125 volts with a 2 volt bandwidth and a 30 second time delay which allows the voltage to vary from 124 volts to 126 volts.

While the substation load tap changer is able to be adjusted (raised/lowered, bandwidth and time delay), adequate voltage must still be supplied to all of feeder #2 as well as all other feeders of FLW Sub

2, regardless of the operational status of the boiler plant generator. It is recommended to reduce the substation voltage setting to 123 volts. Leaving the 2 volt bandwidth and 30 second time delay in place will allow the voltage output to fluctuate between 122 volts and 124 volts which should be enough to provide acceptable voltage throughout the existing Substation #2 feeders.

The overhead conductor immediately leaving the substation on feeder #2 consists of .17 miles of three phase 4/0 ACSR which has a current carrying capacity of 350 amps per phase. This is connected to .37 miles of three phase 1/0 CU HD which has a current carrying capacity of 310 amps per phase. The three phase overhead conductor then changes to several hundred feet of three phase underground conductor to feed the boiler plant. This conductor is #2 CU UG with a current carrying capacity of 155 amps.

The boiler generator itself is a 2.5 MW unit, which at full capacity (and at 100% efficiency) could produce approximately 116 amps per phase. None of the three phase conductors between the boiler plant and the substation would be over the rated capacity of the conductor, so no conductor changes will be considered in this study. An upgrade to the boiler generator, for instance to a 3.5 MW unit, would necessitate upgrading the #2 CU UG to accommodate the additional generation. In this instance a new GSU would also be required.

The existing three phase substation recloser for feeder #2 will be replaced with a solid‐dielectric vacuum recloser and SEL 651R relay. A similar recloser (29203) and relay will be installed just past the generator location to protect Building 2369 and all upline services and conductor. A third device, circuit breaker 29202, will be installed at Building 2369 before the three existing transformers. This device will serve as the tie breaker and synchronizing breaker from islanding operation.

FLW will install their own circuit breaker (CB1) between the generator and GSU. This breaker will be connected to circuit breaker 29202 via fiber optic cable. Utilizing the SEL relays and a properly designed coordination scheme, the two breakers will work together and will coordinate with reclosers

29201 and 29203.

I‐5

There are no downline reclosers on feeder #2 at this time so there is no concern for issues with excessive fault current due to the addition of the generator. Future downline reclosers will be sized appropriately taking the generator into account.

In summary, the voltage concerns can be alleviated by changes to the LTC controller, there are no current capacity issues with the existing EPS system, and the additional generator will not adversely impact the fault current coordination of the EPS system protection devices. In order to establish the interconnection of the distributed generation unit, the EPS operator will need to install the GSU transformer, upgrade the substation recloser, install an additional downline recloser as well as the tie breaker and synchronizing controller. The cost estimate to provide these facilities is estimated at a not to exceed price of $256,123.98.

II‐1

II. Application for Interconnection

A copy of the application for interconnection is included in this section. Calculations performed and tabulated in other sections of this report shall be based on data in this application. As FLW intends to issue a design/build contract for this project, the specific generator make and model are yet to be determined. Therefore, if there are any deviations from the technical data submitted in this application, additional reviews will be required.

III‐1

III. Operation of Interconnected Generation

A. Background

When connecting distributed generation (DG) to the EPS it is typically intended that when the

EPS has an interruption of power that the DG stops generating as well. This is usually referred to as the anti‐islanding provision. The most widely accepted approach to anti‐islanding can be found in the IEEE

Standard 1547 governing distributed generation interconnection. However, FLW has requested that this project be designed so that if the EPS has interruption of power that the DG unit will continue to supply service locally to Building 2369 in island mode which also could be termed a microgrid.

In order to design the DG unit to function in a microgrid the EPS will have to disconnect the DG during faults on the EPS quick enough that the DG protection system does not disconnect the generator from the local microgrid. In order to establish the desired microgrid, a direct transfer trip method will be used. Fiber optic communications between the substation feeder recloser and the local EPS tie breaker at building 2369 will be utilized for the direct transfer trip settings.

Settings for the EPS installed tie breaker will include elements for under‐voltage, over‐voltage, under‐frequency, over‐frequency, and both forward and reverse power flow current settings.

B. Safety During Microgrid Operation

In order to protect both the EPS and the microgrid the direct transfer trip tie breaker will be designed to establish the islanded microgrid as well as return the island back to the EPS. This tie breaker will be completely under the control of the utility. In addition, a visible, lockable disconnect will be available at the microgrid site both on the primary feeder as well as the backup feeder. During islanding operation, the EPS operator will not initiate the DG tie back to the EPS until confirmation is obtained from the DG operator that it is safe to do so. Should the EPS operated tie breaker open not from a direct transfer trip initiated event then the EPS operator will also require confirmation from the DG operator that it is safe to close the tie breaker before doing so.

C. Sequence of Operations

A one line diagram of the site as well as a summary of the sequence of operations for various events on the EPS or DG unit is as follows:

Normal Operation without generator running:

In normal operating mode Building 2369 will be served by the preferred feeder (feeder 2). The Laclede feeder recloser (29201) will protect the feeder from faults by operating through 3 reclose attempts and locking out on the 4th trip if necessary. When the recloser 29201 advances to lockout all services at Building 2369 will also be de‐energized.

III‐2

Normal Operation with generator running:

While being supplied through normal utility service, the generator will be started and synchronized to Laclede’s utility service by the generator control equipment and connected once synchronized by breaker CB1 which is owned and operated by Fort Leonard Wood. If generator needs to be shut down, local generator control shall initiate a shut down and breaker CB1 shall be opened returning all transformer back to traditional utility service.

Temporary or Permanent Fault past Recloser 29203 with Generator Running:

After generator has been synchronized to Laclede’s distribution system and is running if a temporary or permanent fault occurs on the distribution system downstream of Recloser 29302 then Recloser 29301 and CB1 shall be able to ride through up to 3 reclose attempts by Recloser 29303 before it locks out on the 4th reclose attempt. If Recloser 29303 does advance to lock out, then the generator and Laclede’s utility system shall remain connected to provide service to Building 2369 as well as the portion of Laclede’s feeder 2 between the substation and Building 2369. Depending on the load requirements at Building 2369 and the remaining load on Laclede’s feeder 2, power flow may be in reverse mode at Laclede’s feeder 2 but will flow back out on other substation feeders only lowering power flow in from the 69 kV supply.

Temporary Fault between Recloser 29201 and 29203 with Generator Running:

After generator has been synchronized to Laclede’s distribution system and is running if a temporary fault occurs on the distribution system between reclosers 29201 and 29203 then recloser 29201 will operate under its normal protection settings. Once recloser 29201 opens on its first trip a direct transfer trip setting will open breaker 29202. This will leave the generator supplying service to the three transformers at Bld 2369. The generator controls will have to be capable of ramping down quick enough to the lower load level before its settings take the generator offline on the sudden reduction of load.

Recloser 29201 will then continue through the rest of its normal reclose attempts and if the fault is temporary remain closed on a subsequent attempt prior to reaching lockout. After a determined amount of time with voltage from both generator and utility at breaker 29202, synchronization shall occur at breaker 29202 and a close shall be initiated to connect the generator back to the utility system.April 26, 2018 2 of 2

Permanent Fault between Recloser 29201 and 29203 with Generator Running:

After generator has been synchronized to Laclede’s distribution system and is running if a permanent fault occurs on the distribution system between reclosers 29201 and 29203 then recloser 29201 will operate under its normal protection settings. Once recloser 29201 opens on its first trip a direct transfer trip setting will open breaker 29202. This will leave the generator supplying service to the three transformers at Bld 2369. The generator controls will have to be capable of ramping down quick enough to the lower load level before its settings take the generator offline on the sudden reduction of load.

Recloser 29201 will then continue through the rest of its normal reclose attempts and if the fault is permanent will lockout. Laclede crews will be dispatched to investigate, troubleshoot, and eventually repair the permanent fault condition. When they have corrected the fault condition recloser 29201 will be closed thereby restoring service to the utility feeder. After a determined amount of time with voltage from both generator and utility at breaker 29202, synchronization shall occur at breaker 29202 and a closer shall be initiated to connect the generator back to the utility system.

IV‐1

IV. Impact on Electric Power System Equipment Loading Under Steady State Conditions

The proposed Fort Leonard Wood (FLW) Boiler Plant Generator is served from Laclede Electric

Cooperative’s substation #29 (Fort Leonard Wood Substation #2). This substation is owned by Sho‐Me

Power Electric Cooperative.

The proposed Boiler Plant Generator is located on feeder #2 (operating at 7.2/12.47 kV) out of substation #29. There is a normally open alternate feeder, feeder #3 available as well. The control on the feeder #2 recloser at the substation (OCR 29201) will need to be replaced and upgraded as a result of this project, changing it from an Eaton Form 6 to a Schweitzer 651R control. Another new recloser, OCR 29203 will be installed just past the Boiler Plant. Additionally, a new circuit breaker, 29202, will be installed at the Boiler Plant. A 2500 KVA step up transformer will be installed at the Boiler Plant. This equipment will all be installed and owned by Laclede Electric.

Feeder #2 typically has a slightly larger load than feeder #3 and has therefore been selected as the optimal feeder to serve the FLW Boiler Plant. Feeder #3 will remain as a normally open, alternate feeder. Loading will vary throughout the year and at times there will not be enough load on feeder #2 to use all the power supplied by the Boiler Plant. At these times power will flow back to the substation where it will partially supply the other ten feeders on substation #29.

When generating at full capacity, the 2500 KVA Generator Step Up Transformer can supply approximately 115 amps per phase. SCADA data from July 25, 2017 is shown in the table below to display near peak data for substation #29. This snapshot was taken with the temperature at 93 degrees.

Sub 29 Amps Amps Amps Amps KW

93 degree Temp

A Phase

B Phase

C Phase

Total

Feeder 1 54 74 73 201 1,447

Feeder 2 126 128 91 345 2,484

Feeder 3 51 60 60 171 1,231

Feeder 4 38 44 36 118 850

Feeder 5 80 80 81 241 1,735

Feeder 6 49 52 54 155 1,116

Feeder 7 16 16 16 48 346

Feeder 8 13 14 13 40 288

Feeder 9 111 102 102 315 2,268

Feeder 10 58 61 57 176 1,267

Feeder 11 5 6 6 17 122

Total 601 637 589 1,827 13,154

IV‐2

SCADA data from June 14, 2018 is shown in the table below to display typical non peak data for substation #29. This snapshot was taken at a more ordinary 80 degree temperature.

80 degree Temp

A Phase

B Phase

C Phase

Total

Feeder 1 45 59 63 167 1,202

Feeder 2 70 74 57 201 1,447

Feeder 3 43 54 54 151 1,087

Feeder 4 34 40 32 106 763

Feeder 5 66 66 65 197 1,418

Feeder 6 54 53 56 163 1,174

Feeder 7 12 11 12 35 252

Feeder 8 14 14 13 41 295

Feeder 9 93 93 93 279 2,009

Feeder 10 49 51 48 148 1,066

Feeder 11 2 3 4 9 65

Total 482 518 497 1,497 10,778

SCADA data from April 5, 2018 is shown in the table below to display low non peak data for substation #29. This snapshot was taken at a 60 degree temperature.

60 degree Temp

A Phase

B Phase

C Phase

Total

Feeder 1 28 35 33 96 691

Feeder 2 27 32 19 78 562

Feeder 3 35 42 42 119 857

Feeder 4 34 35 31 100 720

Feeder 5 45 45 43 133 958

Feeder 6 36 39 41 116 835

Feeder 7 9 9 10 28 202

Feeder 8 14 15 14 43 310

Feeder 9 73 68 68 209 1,505

Feeder 10 42 44 43 129 929

Feeder 11 2 2 2 6 43

Total 345 366 346 1,057 7,610

IV‐3

As can be seen from the feeder loading information shown on the previous pages, on very hot days the power produced by the Boiler Plant will probably be used entirely by feeder #2. However, during non peak days or during evening hours power will be flowing back into substation #29 and out onto the other substation feeders. However, even at very mild temperature times like April 5, 2018 there should be enough load on substation #29 to use the power that the Boiler Plant Generator produces.

With power flowing in both directions from the substation to and from the Boiler Plant, that stretch of conductor is critical. As has been previously discussed, this line is adequate to handle the approximate 115 amps per phase that the Boiler Plant Generator can produce at full load. The conductor currently consists of 4/0 ACSR (current carrying capacity of 350 amps per phase), 1/0 CU

(current carrying capacity of 310 amps per phase) and #2 CU UG (current carrying capacity of 155 amps per phase).

While there is a capacitor bank along this stretch of conductor, there are no downline regulators or reclosers on this feeder. The numerous underground cabinets, line fuses and inline switches on this feeder will have no bearing on this project.

Sho‐Me Power metering data for the last 12 months was collected to assess the potential effect of the Boiler Plant Generator on the Sho‐Me Power substation transformer and transmission system.

The five highest load days for substation #29 over the last 12 months are shown below.

Date Sub 29 KW

6/28/2018 13,777

6/29/2018 13,257

7/21/2017 13,191

7/20/2017 13,149

7/26/2017 13,136

Similarly, the load data was studied to find the least loaded days in the last 12 months for substation #29. This data is shown below and suggests that substation #29 has enough demand that regardless of time of year or time of day, the Boiler Plant Generator cannot supply the entire substation load. The Sho‐Me Power substation must supply a portion of the power and there is little possibility of the generator backfeeding power onto the Sho‐Me Power transmission system.

Date Sub 29 KW

11/13/2017 7,454

11/21/2017 7,454

11/02/2017 7,460

11/17/2017 7,464

11/20/2017 7,472

V‐1

V. Impacts on Voltage Regulation within the Electric Power System under Steady State

The LEC substation #29 transformer is equipped with a Load Tap Changer (LTC) for voltage regulation and uses a Beckwith controller that is capable of reverse power flow. The substation is owned by Sho‐Me Power Electric Cooperative. The LTC is currently set for a 125 volt output with a 2 volt bandwidth and a 30 second time delay. With the current LTC settings, power will not be able to flow from the Boiler Plant Generator back towards the substation without a possible voltage rise to areas near the generator, especially under light feeder loading.

An adjustment of 2 volts (lowering the LTC to 123 volts) should create an environment in which power can flow without the adverse voltage rise at the Boiler Plant Generator site. Additionally, regardless of the weather and loading, a 123 volt setting should allow all of the feeders of substation

#29 to maintain voltages between 114 volts and 126 volts (on a 120 volt base) per the requirements of

ANSI C84.1, Range A. Adjustments to the LTC control will be made based on the data gathered during project implementation and with the assistance of Sho‐Me Power.

Neither feeder #2 nor the alternate feeder #3 has any downline regulator units to consider for this project. Any future regulator additions will need to take this project into account.

Additional voltage case studies follow in the next section of this report.

VI‐1

VI. Calculations – Case Studies

Assumptions

Where variables are unknown (like underground conductor), selections are made to result in a

“worst case scenario”. In instances where substation #29 is heavily loaded, the worst case scenario is one in which voltages are low. In instances where substation #29 is lightly loaded, the worst case scenario is one where voltages are high. The primary goal per ANSI C84.1 Range A is to maintain a voltage range of between 114.0 and 126.0 volts for all points on substation #29 regardless of weather or loading. This is a +/‐ 5% range (6 volts) on a 120 volt base.

Voltage Calculations – Case Studies

Case 1: Base Case with 126 Volt Substation Setting, Capacitor Bank and No Generator

The Windmil model used in this analysis is created from the LEC Geographic Information System

(GIS). Load data for FLW is not easily importable into Windmil because LEC does not have meters on all services nor does LEC collect readings on all meters that are installed. However, load readings have been recorded per feeder via the LEC Supervisory Control and Data Acquisition (SCADA) system, though these readings cannot easily be allocated throughout the feeder using Windmil. Using feeder data from

SCADA from 7/25/2017, load was manually placed at locations on substation #29 feeders as shown in table 1 below. This data can be considered “near peak” data for FLW because FLW typically reaches it’s peak loading during summer months.

VI‐2

Load Point Load

(KW)

Voltage (Volts)

Distance from Sub (miles)

Map Nearby Location on Feeder

Feeder 2 Outside Sub 0 125.993 ‐ ‐

Feeder 2 Cap Bank 0 125.839 .4 3029 14 4815

Feeder 2 Boiler Load 1,000 125.654 .6 3029 14 4813

Feeder 2 Load 1 750 123.448 2.6 3029 14 4802 end of feeder

Feeder 2 Load 2 750 124.486 2.4 3028 24 4203 end of feeder

Load on 29‐1 Point 1 1,089 123.496 1.4 3035 12 8401 mid‐feeder

Load on 29‐1 Point 2 361 121.080 4.9 3050 20 5400 end of feeder

Load on 29‐3 Point 1 924 125.127 2.0 3032 24 6613 mid‐feeder

Load on 29‐3 Point 2 308 123.831 4.9 3028 36 4200 end of feeder

Load on 29‐4 850 125.365 1.8 3034 23 7805 end of feeder

Load on 29‐5 1,735 125.072 1.6 3036 15 9000 end of feeder

Load on 29‐6 1,116 125.629 1.1 3034 11 7802 end of feeder

Load on 29‐7 346 125.926 1.1 3026 11 3001 end of feeder

Load on 29‐8 288 125.981 .4 3023 14 1202 end of feeder

Load on 29‐9 2,268 122.231 2.1 3034 14 7800 end of feeder

Load on 29‐10 1,267 125.640 1.0 3028 15 4200 end of feeder

Load on 29‐11 122 125.990 .2 3027 14 3602 end of feeder

Table 1

For most of these feeders the load data was placed at one location at the end of feeder. This is to simulate peak feeder load though it is not allocated evenly throughout the feeder when using this method. In the case of feeder #2, the Boiler Plant Feeder, the load was broken into three pieces and placed at the boiler plant and at two different feeder endpoints. Load on feeder #1 and #3 was placed at mid‐feeder and at the end of feeder to better simulate those feeders.

The boiler plant itself is served by two 1,000 KVA transformers and a 1,500 KVA transformer.

During peak periods (in summer months) these three transformers are loaded at roughly 1.0 MW to serve the plant. This boiler plant data was retrieved via the Advanced Metering Infrastructure (AMI) system and is summarized in table 2 below. The rest of feeder #2 is approximately 1.5 MW total.

VI‐3

Boiler Plant AMI Data

Month kWh Total (AMI data) kW (calculated)

July 2018 802,358 1,044

June 2018 694,997 965

May 2018 458,426 616

April 2018 59,251 82

March 2018 45,026 61

February 2018 37,145 55

January 2018 43,855 59

December 2017 42,886 58

November 2017 40,054 56

October 2017 300,362 404

September 2017 446,167 620

August 2017 530,129 713

July 2017 632,858 851

Table 2

In an attempt to allocate load throughout Feeder #2 manually, a 1.0 MW load was inserted at the Boiler Plant near map location 3029 14 4813. The other 1.5 MW was split into 2 parts of .75 MW each and was placed at long distances from the substation. These 2 loads (Load 1 and Load 2) are to simulate what voltages might look like (worst case) at the ends of the feeder. The .75 MW load for Load

1 was placed near map location 3029 14 4802 at a point 2.64 miles from the substation. The .75 MW load for Load 2 was placed near map location 3028 24 4203 at a point 2.43 miles from the substation.

The 600 KVAR capacitor bank near map 3029 14 4815 is a VAR controlled bank. For purposes of this report they will be set to “on” in the Windmil model.

The substation bus voltage was set to 126 volts and then a voltage drop calculation was performed in Windmil. This 126 volt setting in Windmil represents the substation transformer LTC being set for 125 volts with a bandwidth of +/‐1 volt and then the calculation assuming that the peak voltage of 126 is the output voltage. The resulting base case voltages are shown on the previous page in table 1.

VI‐4

Case 2: Peak Load and 126 Volt Substation Setting with Capacitor Bank and New Generator

Case 2 will add the Boiler Plant Generator downline from the “Feeder 2 Boiler Load” point where the 1.0 MW was allocated near map 3029 14 4813. The settings used in Windmil were for 2,500

KW, a power factor of 80% (as stated in the application for interconnection) and a generator model to allow “negative load” calculations as shown below.

The substation bus voltage was left at 126 volts and then a voltage drop calculation was performed in Windmil. The resulting base case voltages are shown below in table 3.

VI‐5

Voltage (Volts)

Distance from Sub (miles)

Map Nearby Location on Feeder

Feeder 2 Outside Sub 0 126.041 ‐ ‐

Capacitor Bank 0 126.617 .4 3029 14 4815

Feeder 2 Boiler Load 1,000 126.923 .6 3029 14 4813

Feeder 2 Load 1 750 124.545 2.6 3029 14 4802 end of feeder

Feeder 2 Load 2 750 125.575 2.4 3028 24 4203 end of feeder

Load on 29‐1 Point 1 1,089 124.454 1.4 3035 12 8401 mid‐feeder

Load on 29‐1 Point 2 361 121.080 4.9 3050 20 5400 end of feeder

Load on 29‐3 Point 1 924 125.404 2.0 3032 24 6613 mid‐feeder

Load on 29‐3 Point 2 308 123.831 4.9 3028 36 4200 end of feeder

Load on 29‐4 850 125.535 1.8 3034 23 7805 end of feeder

Load on 29‐5 1,735 125.102 1.6 3036 15 9000 end of feeder

Load on 29‐6 1,116 125.700 1.1 3034 11 7802 end of feeder

Load on 29‐7 346 125.926 1.1 3026 11 3001 end of feeder

Load on 29‐8 288 125.987 .4 3023 14 1202 end of feeder

Load on 29‐9 2,268 122.231 2.1 3034 14 7800 end of feeder

Load on 29‐10 1,267 125.678 1.0 3028 15 4200 end of feeder

Load on 29‐11 122 125.992 .2 3027 14 3602 end of feeder

Table 3

The voltage drop calculation results in a high voltage at the boiler generator of 126.923 volts.

With the substation being set for 125.0 volts (but calculated at 126.0 to account for it’s bandwidth), the boiler generator cannot push it’s excess generation back to the substation, resulting in a voltage rise.

This rise is more evident close to the boiler plant generator and falls off as the excess is used on the feeder. The other feeders maintain their previous voltages. In this scenario the 2.5 MW of load on feeder #2 uses most of the load generated at the Boiler Plant.

VI‐6

Case 3: Peak Load and 126 Volt Substation Setting with Capacitor Bank Removed and Generator Running

In case 3 the capacitor bank near map location 3029 14 4815 will be removed to see what kind of effect the capacitor bank has on the voltages. The substation bus voltage was left at 126 volts, the boiler plant generator remained and then a voltage drop calculation was performed in Windmil. The resulting base case voltages are shown in the abbreviated below in table 4.

Load Point Load (KW) Voltage (Volts)

Voltage Difference (Volts)

Distance from Sub (miles)

Map Nearby

Feeder 2 Outside Sub 0 126.031 .010 ‐ ‐

Capacitor Bank 0 126.472 .145 .4 3029 14 4815

Feeder 2 Boiler Load 1,000 126.779 .144 .6 3029 14 4813

Feeder 2 Load 1 750 124.398 .147 2.6 3029 14 4802

Feeder 2 Load 2 750 125.429 .146 2.4 3028 24 4203

Table 4

The removal of the capacitor bank from the model results in only a small decrease in the voltage as shown in the Voltage Difference column of the table. This small improvement does not warrant removing or relocating the capacitor bank. Future calculations will include the capacitor bank in the model.

VI‐7

Case 4A: Peak Load and 124 Volt Substation Setting with Capacitor Bank and Generator

In case 4A the substation bus voltage has been reduced to 124 volts, the capacitor bank is in place and the generator is running. The resulting voltages on the points of interest are shown below in table 5.

Voltage (Volts)

Distance from Sub (miles)

Map Nearby Location on Feeder

Feeder 2 Outside Sub 0 124.041 ‐ ‐

Capacitor Bank 0 124.620 .4 3029 14 4815

Feeder 2 Boiler Load 1,000 124.930 .6 3029 14 4813

Feeder 2 Load 1 750 122.510 2.6 3029 14 4802 end of feeder

Feeder 2 Load 2 750 123.555 2.4 3028 24 4203 end of feeder

Load on 29‐1 Point 1 1,089 122.428 1.4 3035 12 8401 mid‐feeder

Load on 29‐1 Point 2 361 118.994 4.9 3050 20 5400 end of feeder

Load on 29‐3 Point 1 924 123.387 2.0 3032 24 6613 mid‐feeder

Load on 29‐3 Point 2 308 121.787 4.9 3028 36 4200 end of feeder

Load on 29‐4 850 123.526 1.8 3034 23 7805 end of feeder

Load on 29‐5 1,735 123.061 1.6 3036 15 9000 end of feeder

Load on 29‐6 1,116 123.692 1.1 3034 11 7802 end of feeder

Load on 29‐7 346 123.925 1.1 3026 11 3001 end of feeder

Load on 29‐8 288 123.986 .4 3023 14 1202 end of feeder

Load on 29‐9 2,268 120.165 2.1 3034 14 7800 end of feeder

Load on 29‐10 1,267 123.672 1.0 3028 15 4200 end of feeder

Load on 29‐11 122 123.992 .2 3027 14 3602 end of feeder

Table 5

As can be seen in the table, the voltages all appear to be in the acceptable voltage range of 117‐

126 volts. However, the 118.994 volts on 29‐1 Point 2 is a concern because in case 4B the voltage will be dropped to 122 volts at the substation.

VI‐8

Case 4B: Peak Load and 122 Volt Substation Setting with Capacitor Bank and Generator

In case 4B the substation bus voltage is reduced to 122 volts, the capacitor bank is in place and the generator is running. The resulting voltages on the points of interest are shown below in table 6.

Voltage (Volts)

Distance from Sub (miles)

Map Nearby Location on Feeder

Feeder 2 Outside Sub 0 122.041 ‐ ‐

Capacitor Bank 0 122.623 .4 3029 14 4815

Feeder 2 Boiler Load 1,000 122.937 .6 3029 14 4813

Feeder 2 Load 1 750 120.474 2.6 3029 14 4802 end of feeder

Feeder 2 Load 2 750 121.534 2.4 3028 24 4203 end of feeder

Load on 29‐1 Point 1 1,089 119.407 1.4 3035 12 8401 mid‐feeder

Load on 29‐1 Point 2 361 116.905 4.9 3050 20 5400 end of feeder

Load on 29‐3 Point 1 924 121.082 2.0 3032 24 6613 mid‐feeder

Load on 29‐3 Point 2 308 119.741 4.9 3028 36 4200 end of feeder

Load on 29‐4 850 121.342 1.8 3034 23 7805 end of feeder

Load on 29‐5 1,735 121.025 1.6 3036 15 9000 end of feeder

Load on 29‐6 1,116 121.612 1.1 3034 11 7802 end of feeder

Load on 29‐7 346 121.924 1.1 3026 11 3001 end of feeder

Load on 29‐8 288 121.979 .4 3023 14 1202 end of feeder

Load on 29‐9 2,268 118.096 2.1 3034 14 7800 end of feeder

Load on 29‐10 1,267 121.626 1.0 3028 15 4200 end of feeder

Load on 29‐11 122 121.990 .2 3027 14 3602 end of feeder

Table 6

As can be seen in the table, some of the voltages are dropping to the lower end of the acceptable range of 117‐126 volts. Feeder #1 may need regulators at some point in the future, but at present no addition would be required. One other factor to consider is that several of these feeders are used on occasion for backfeeding purposes, sometimes gaining load from other substations.

Undoubtedly some load could be moved to Substation #29 while maintaining an acceptable voltage.

Those calculations are beyond the scope of this project and would have to be handled on a case by case basis.

Case 4A and 4B represent the possible voltages seen if the substation voltage is reduced to 123 volts with a bandwidth of +/‐ 2 volts. Case 4A would be the high end of 124 volts while case 4B would be the low end of 122 volts. As future calculations will show, it may be necessary to reduce the substation voltage from it’s current setting of 125 volts to a setting of 123 volts in order to make power generated at the Boiler plant flow back towards the substation.

VI‐9

Case 5: Load at 50% and 126 Volt Substation Setting with Capacitor Bank and Generator

In case 5 the substation is set for 126 volts, the capacitor bank is in place and the generator is running. However, for this exercise the loads on all the feeders have been halved to simulate the effects of the generator on the system during an average load day. The results of this calculation are shown below in table 7.

Voltage (Volts)

Distance from Sub (miles)

Map Nearby Location on Feeder

Feeder 2 Outside Sub 0 126.052 ‐ ‐

Capacitor Bank 0 126.805 .4 3029 14 4815

Feeder 2 Boiler Load 500 127.215 .6 3029 14 4813

Feeder 2 Load 1 375 125.983 2.6 3029 14 4802 end of feeder

Feeder 2 Load 2 375 126.532 2.4 3028 24 4203 end of feeder

Load on 29‐1 Point 1 545 125.241 1.4 3035 12 8401 mid‐feeder

Load on 29‐1 Point 2 181 124.482 4.9 3050 20 5400 end of feeder

Load on 29‐3 Point 1 462 125.823 2.0 3032 24 6613 mid‐feeder

Load on 29‐3 Point 2 154 125.315 4.9 3028 36 4200 end of feeder

Load on 29‐4 426 125.783 1.8 3034 23 7805 end of feeder

Load on 29‐5 868 125.672 1.6 3036 15 9000 end of feeder

Load on 29‐6 559 125.890 1.1 3034 11 7802 end of feeder

Load on 29‐7 174 125.963 1.1 3026 11 3001 end of feeder

Load on 29‐8 145 126.006 .4 3023 14 1202 end of feeder

Load on 29‐9 1,134 124.374 2.1 3034 14 7800 end of feeder

Load on 29‐10 634 125.857 1.0 3028 15 4200 end of feeder

Load on 29‐11 61 125.996 .2 3027 14 3602 end of feeder

Table 7

The results of the case 5 calculations show that with the generator still producing 2.5 MW but with less load on feeder #2 to serve, the voltages on feeder #2 and the other feeders rise even more than in the case 2 calculation. As expected, the less load there is to serve, the higher the resultant voltages on feeder #2, especially close to the Boiler Plant Generator.

VI‐10

Case 6A: Load at 50% and 124 Volt Substation Setting with Capacitor Bank and Generator

In case 6A the substation is set for 124 volts, the capacitor bank is in place and the generator is running. All loads are set to 50% of the near peak demand shown in case 1. The results of this calculation are shown below in table 8.

Voltage (Volts)

Distance from Sub (miles)

Map Nearby Location on Feeder

Feeder 2 Outside Sub 0 124.052 ‐ ‐

Capacitor Bank 0 124.811 .4 3029 14 4815

Feeder 2 Boiler Load 500 125.227 .6 3029 14 4813

Feeder 2 Load 1 375 123.972 2.6 3029 14 4802 end of feeder

Feeder 2 Load 2 375 124.527 2.4 3028 24 4203 end of feeder

Load on 29‐1 Point 1 545 123.229 1.4 3035 12 8401 mid‐feeder

Load on 29‐1 Point 2 181 121.550 4.9 3050 20 5400 end of feeder

Load on 29‐3 Point 1 462 123.812 2.0 3032 24 6613 mid‐feeder

Load on 29‐3 Point 2 154 123.022 4.9 3028 36 4200 end of feeder

Load on 29‐4 426 123.779 1.8 3034 23 7805 end of feeder

Load on 29‐5 868 123.660 1.6 3036 15 9000 end of feeder

Load on 29‐6 559 123.886 1.1 3034 11 7802 end of feeder

Load on 29‐7 174 123.962 1.1 3026 11 3001 end of feeder

Load on 29‐8 145 124.002 .4 3023 14 1202 end of feeder

Load on 29‐9 1,134 122.126 2.1 3034 14 7800 end of feeder

Load on 29‐10 634 123.839 1.0 3028 15 4200 end of feeder

Load on 29‐11 61 123.996 .2 3027 14 3602 end of feeder

Table 8

The results of the case 6A calculations show once again that reducing the voltage at the sub to

124 volts will maintain voltages throughout the substation feeders to between 117‐126 volts.

VI‐11

Case 6B: Load at 50% and 122 Volt Substation Setting with Capacitor Bank and Generator

In case 6B the substation is set for 122 volts, the capacitor bank is in place and the generator is running. All loads are set to 50% of the near peak demand shown in case 1. The results of this calculation are shown below in table 9.

Voltage (Volts)

Distance from Sub (miles)

Map Nearby Location on Feeder

Feeder 2 Outside Sub 0 122.052 ‐ ‐

Capacitor Bank 0 122.817 .4 3029 14 4815

Feeder 2 Boiler Load 500 123.239 .6 3029 14 4813

Feeder 2 Load 1 375 121.961 2.6 3029 14 4802 end of feeder

Feeder 2 Load 2 375 122.523 2.4 3028 24 4203 end of feeder

Load on 29‐1 Point 1 545 120.731 1.4 3035 12 8401 mid‐feeder

Load on 29‐1 Point 2 181 119.508 4.9 3050 20 5400 end of feeder

Load on 29‐3 Point 1 462 121.660 2.0 3032 24 6613 mid‐feeder

Load on 29‐3 Point 2 154 120.998 4.9 3028 36 4200 end of feeder

Load on 29‐4 426 121.687 1.8 3034 23 7805 end of feeder

Load on 29‐5 868 121.628 1.6 3036 15 9000 end of feeder

Load on 29‐6 559 121.881 1.1 3034 11 7802 end of feeder

Load on 29‐7 174 121.962 1.1 3026 11 3001 end of feeder

Load on 29‐8 145 122.001 .4 3023 14 1202 end of feeder

Load on 29‐9 1,134 120.093 2.1 3034 14 7800 end of feeder

Load on 29‐10 634 121.850 1.0 3028 15 4200 end of feeder

Load on 29‐11 61 121.996 .2 3027 14 3602 end of feeder

Table 9

The results of the case 6B calculations show once again that reducing the voltage at the sub to

122 volts will maintain voltages throughout the substation feeders to between 117‐126 volts.

Case 6A and 6B represent the possible voltages seen if the substation voltage is reduced to 123 volts with a bandwidth of +/‐ 2 volts. Case 4A would be the high end of 124 volts while case 6B would be the low end of 122 volts.

VI‐12

Case 7: Load at 20% and 126 Volt Substation Setting with Capacitor Bank and Generator

In case 7 the substation is set for 126 volts, the capacitor bank is in place and the generator is running. All loads on all feeders have been reduced to 20% of near peak. This situation may not be possible because if the Boiler Load is only 201 KW, then the generator may not be running. However, the scenario is still calculated for this report. The results of this calculation are shown below in table 10.

Voltage (Volts)

Distance from Sub (miles)

Map Nearby Location on Feeder

Feeder 2 Outside Sub 0 126.058 ‐ ‐

Capacitor Bank 0 126.914 .4 3029 14 4815

Feeder 2 Boiler Load 201 127.331 .6 3029 14 4813

Feeder 2 Load 1 150 126.829 2.6 3029 14 4802 end of feeder

Feeder 2 Load 2 150 127.096 2.4 3028 24 4203 end of feeder

Load on 29‐1 Point 1 217 125.710 1.4 3035 12 8401 mid‐feeder

Load on 29‐1 Point 2 72 125.413 4.9 3050 20 5400 end of feeder

Load on 29‐3 Point 1 185 126.073 2.0 3032 24 6613 mid‐feeder

Load on 29‐3 Point 2 62 125.877 4.9 3028 36 4200 end of feeder

Load on 29‐4 170 125.932 1.8 3034 23 7805 end of feeder

Load on 29‐5 347 126.010 1.6 3036 15 9000 end of feeder

Load on 29‐6 224 126.004 1.1 3034 11 7802 end of feeder

Load on 29‐7 69 125.986 1.1 3026 11 3001 end of feeder

Load on 29‐8 58 126.017 .4 3023 14 1202 end of feeder

Load on 29‐9 454 125.368 2.1 3034 14 7800 end of feeder

Load on 29‐10 254 125.963 1.0 3028 15 4200 end of feeder

Load on 29‐11 25 125.998 .2 3027 14 3602 end of feeder

Table 10

The results case 7 calculations should be considered a worst case scenario. There are voltages exceeding 126.0 volts on both feeder #2 and on several other feeders. Again, this scenario may be unlikely to occur if the generator is offline on lightly loaded days.

VI‐13

Case 8A: Load at 20% and 124 Volt Substation Setting with Capacitor Bank and Generator

In case 8A the substation is set for 124 volts, the capacitor bank is in place and the generator is running. As in case 7 the loads on all feeders are set for 20% of near peak which is an unlikely scenario.

Nevertheless, lowering the voltage at the sub brings the high voltages throughout feeder #2 and the substation back to an acceptable level. The results of this calculation are shown below in table 11.

Voltage (Volts)

Distance from Sub (miles)

Map Nearby Location on Feeder

Feeder 2 Outside Sub 0 124.058 ‐ ‐

Capacitor Bank 0 124.921 .4 3029 14 4815

Feeder 2 Boiler Load 201 125.345 .6 3029 14 4813

Feeder 2 Load 1 150 124.831 2.6 3029 14 4802 end of feeder

Feeder 2 Load 2 150 125.101 2.4 3028 24 4203 end of feeder

Load on 29‐1 Point 1 217 123.705 1.4 3035 12 8401 mid‐feeder

Load on 29‐1 Point 2 72 123.403 4.9 3050 20 5400 end of feeder

Load on 29‐3 Point 1 185 124.067 2.0 3032 24 6613 mid‐feeder

Load on 29‐3 Point 2 62 123.867 4.9 3028 36 4200 end of feeder

Load on 29‐4 170 123.930 1.8 3034 23 7805 end of feeder

Load on 29‐5 347 124.003 1.6 3036 15 9000 end of feeder

Load on 29‐6 224 124.001 1.1 3034 11 7802 end of feeder

Load on 29‐7 69 123.985 1.1 3026 11 3001 end of feeder

Load on 29‐8 58 124.017 .4 3023 14 1202 end of feeder

Load on 29‐9 454 123.357 2.1 3034 14 7800 end of feeder

Load on 29‐10 254 123.961 1.0 3028 15 4200 end of feeder

Load on 29‐11 25 123.998 .2 3027 14 3602 end of feeder

Table 11

VI‐14

Case 8B: Load at 20% and 122 Volt Substation Setting with Capacitor Bank and Generator

In case 8B the substation is set for 122 volts, the capacitor bank is in place and the generator is running. As in case 7 the loads on all feeders are set for 20% of near peak which is an unlikely scenario.

The results of this calculation are shown below in table 12.

Voltage (Volts)

Distance from Sub (miles)

Map Nearby Location on Feeder

Feeder 2 Outside Sub 0 122.059 ‐ ‐

Capacitor Bank 0 122.930 .4 3029 14 4815

Feeder 2 Boiler Load 201 123.359 .6 3029 14 4813

Feeder 2 Load 1 150 122.835 2.6 3029 14 4802 end of feeder

Feeder 2 Load 2 150 123.106 2.4 3028 24 4203 end of feeder

Load on 29‐1 Point 1 217 121.700 1.4 3035 12 8401 mid‐feeder

Load on 29‐1 Point 2 72 121.012 4.9 3050 20 5400 end of feeder

Load on 29‐3 Point 1 185 122.060 2.0 3032 24 6613 mid‐feeder

Load on 29‐3 Point 2 62 121.728 4.9 3028 36 4200 end of feeder

Load on 29‐4 170 121.928 1.8 3034 23 7805 end of feeder

Load on 29‐5 347 121.986 1.6 3036 15 9000 end of feeder

Load on 29‐6 224 121.985 1.1 3034 11 7802 end of feeder

Load on 29‐7 69 121.985 1.1 3026 11 3001 end of feeder

Load on 29‐8 58 122.016 .4 3023 14 1202 end of feeder

Load on 29‐9 454 121.259 2.1 3034 14 7800 end of feeder

Load on 29‐10 254 121.959 1.0 3028 15 4200 end of feeder

Load on 29‐11 25 121.998 .2 3027 14 3602 end of feeder

Table 12

The results of the case 8B calculations show once again that reducing the voltage at the sub to

Case 8A and 8B represent the possible voltages seen if the substation voltage is reduced to 123 volts with a bandwidth of +/‐ 2 volts. Case 8A would be the high end of 124 volts while case 8B would be the low end of 122 volts.

VI‐15

Case 9: No Load on Feeder 2 and 126 Volt Substation Setting with Capacitor Bank and Generator

In case 9 the substation is set for 126 volts, the capacitor bank is in place and the generator is running. The line is opened at recloser 29203 and the load at the Boiler Plant is reduced to zero. The

20% of near peak loading on the other feeders is left in place. This is to simulate an outage on recloser

29203 so that the generator puts 2.5 MW onto the electric system without delivering any power to the

Boiler Plant itself. Whether or not this is an actual possibility is unknown.

In this scenario with the other feeders loaded to only 20% of peak loading, the sum load of the other feeders is only 2,137 KW which is less than what the Boiler Plant can generate. In this unlikely instance, load could feed back through the substation to the Sho Me Power transmission system. As noted on page IV‐3, however, the lowest loading on substation #29 in the last 12 months was 7,454 KW on 11/13/2017. The results of the case 9 calculation are shown below in table 13.

Voltage (Volts)

Distance from Sub (miles)

Map Nearby Location on Feeder

Feeder 2 Outside Sub 0 126.078 ‐ ‐

Capacitor Bank 0 127.248 .4 3029 14 4815

Feeder 2 Boiler Load 0 127.861 .6 3029 14 4813

Feeder 2 Load 1 0 NA 2.6 3029 14 4802 end of feeder

Feeder 2 Load 2 0 NA 2.4 3028 24 4203 end of feeder

Load on 29‐1 Point 1 217 125.710 1.4 3035 12 8401 mid‐feeder

Load on 29‐1 Point 2 72 125.413 4.9 3050 20 5400 end of feeder

Load on 29‐3 Point 1 185 126.073 2.0 3032 24 6613 mid‐feeder

Load on 29‐3 Point 2 62 125.877 4.9 3028 36 4200 end of feeder

Load on 29‐4 170 125.932 1.8 3034 23 7805 end of feeder

Load on 29‐5 347 126.010 1.6 3036 15 9000 end of feeder

Load on 29‐6 224 126.004 1.1 3034 11 7802 end of feeder

Load on 29‐7 69 125.986 1.1 3026 11 3001 end of feeder

Load on 29‐8 58 126.017 .4 3023 14 1202 end of feeder

Load on 29‐9 454 125.368 2.1 3034 14 7800 end of feeder

Load on 29‐10 254 125.963 1.0 3028 15 4200 end of feeder

Load on 29‐11 25 125.998 .2 3027 14 3602 end of feeder

Table 13

VI‐16

Case 10A: No Load on Feeder #2 and 124 Volt Substation Setting with Capacitor Bank and Generator

In case 10A the substation is set for 124 volts, the capacitor bank is in place and the generator is running. The line is opened at recloser 29203 and the load at the Boiler Plant is reduced to zero. The

20% of peak loading on the other feeders is left in place. This is to simulate an outage on recloser 29203 so that the generator puts 2.5 MW onto the electric system without delivering any power to the Boiler

Plant itself. Whether or not this is an actual possibility is unknown. The results of this calculation are shown below in table 14.

Voltage (Volts)

Distance from Sub (miles)

Map Nearby Location on Feeder

Feeder 2 Outside Sub 0 124.079 ‐ ‐

Capacitor Bank 0 125.263 .4 3029 14 4815

Feeder 2 Boiler Load 0 125.885 .6 3029 14 4813

Load on 29‐1 Point 1 217 123.705 1.4 3035 12 8401 mid‐feeder

Load on 29‐1 Point 2 72 123.403 4.9 3050 20 5400 end of feeder

Load on 29‐3 Point 1 185 124.067 2.0 3032 24 6613 mid‐feeder

Load on 29‐3 Point 2 62 123.867 4.9 3028 36 4200 end of feeder

Load on 29‐4 170 123.930 1.8 3034 23 7805 end of feeder

Load on 29‐5 347 124.003 1.6 3036 15 9000 end of feeder

Load on 29‐6 224 124.001 1.1 3034 11 7802 end of feeder

Load on 29‐7 69 123.985 1.1 3026 11 3001 end of feeder

Load on 29‐8 58 124.017 .4 3023 14 1202 end of feeder

Load on 29‐9 454 123.357 2.1 3034 14 7800 end of feeder

Load on 29‐10 254 123.961 1.0 3028 15 4200 end of feeder

Load on 29‐11 25 123.998 .2 3027 14 3602 end of feeder

Table 14

The results of the case 10A calculations show that reducing the voltage at the sub to 124 volts will maintain voltages throughout the substation feeders to between 117‐126 volts.

VI‐17

Case 10B: No Load on Feeder #2 and 122 Volt Substation Setting with Capacitor Bank and Generator

In case 10B the substation is set for 122 volts, the capacitor bank is in place and the generator is running. The line is opened at recloser 29203 and the load at the Boiler Plant is reduced to zero. The

20% loading on the other feeders is left in place. This is to simulate an outage on recloser 29203 so that the generator puts 2.5 MW onto the electric system without delivering any power to the Boiler Plant itself. Whether or not this is an actual possibility is unknown. The results of this calculation are shown below in table 15.

Voltage (Volts)

Distance from Sub (miles)

Map Nearby Location on Feeder

Feeder 2 Outside Sub 0 122.080 ‐ ‐

Capacitor Bank 0 123.279 .4 3029 14 4815

Feeder 2 Boiler Load 0 123.911 .6 3029 14 4813

Load on 29‐1 Point 1 217 121.700 1.4 3035 12 8401 mid‐feeder

Load on 29‐1 Point 2 72 121.012 4.9 3050 20 5400 end of feeder

Load on 29‐3 Point 1 185 122.060 2.0 3032 24 6613 mid‐feeder

Load on 29‐3 Point 2 62 121.728 4.9 3028 36 4200 end of feeder

Load on 29‐4…