HomeMy WebLinkAbout20131430.tiffDecision No. C 13-0608-I
BEFORE THE PUBLIC UTILITIES COMMISSION OF THE STATE OF COLORADO
DOCKET NO. 13M -0019E
IN THE MATTER OF THE DESIGNATION OF ELECTRIC UTILITY TRANSMISSION
FACILITIES FOR WHICH AN APPLICATION TO OBTAIN A CERTIFICATE OF PUBLIC
CONVENIENCE AND NECESSITY IS REQUIRED OR THE FILING OF A FORMAL
DETERMINATION THAT NO CERTIFICATE IS REQUIRED.
INTERIM ORDER PROVIDING NOTICE OF
FILING AND ESTABLISHING
OPPORTUNITY TO FILE COMMENTS
Mailed Date: May 29, 2013
Adopted Date: May 22, 2013
TABLE OF CONTENTS
I. BY THE COMMISSION 1
A. Statement 1
II. ORDER 25
A. The Commission Orders That: 25
B. ADOPTED IN COMMISSIONERS' WEEKLY MEETING May 22, 2013 26
I. BY THE COMMISSION
A. Statement
1. Rule 3206(c) of the Commission's Rules Regulating Electric Utilities, 4 Code of
Colorado Regulations 723-3, requires each Colorado electric utility to file with the Commission,
no later than April 30 of each year, information on its proposed new construction or extensions of
transmission facilities for the next three calendar years.
COMAvYllitiCACOIOVIS X110013 c.
2013-1430
Before the Public Utilities Commission of the State of Colorado
Decision No. C13 -0608-I DOCKET NO. I3M-0019E
2. Rule 3206(d)(2)(A) provides that the Commission will give notice of the filing of
data to all those who, in the opinion of the Commission, are interested persons, firms, or
corporations. Any interested person, firm, or corporation may file comments regarding the
projects identified by the information filed with the Commission by June 15, 2013.
3. The following utilities have filed information on proposed construction projects as
listed. Additional information may be found in each utility's filing in this docket.
INVESTOR -OWNED UTILITIES
Black Hills/Colorado Electric Utility Company, L.P. (BHCE or Black Hills)
New projects not previously filed pursuant to Rule 3206(d)(I):
Portland 115/69 kV #2 Transformer Replacement
This project consists of a new 80 MVA 115/69 kV transformer at the Portland substation.
The new transformer is planned as a replacement for the existing 25 MVA transformer,
which was shown to be under -sized through several planning assessments. The project is
estimated to cost approximately $0.6 million with an estimated construction start, end, and
in-service date of 2015. This project is not expected to have any significant impact on noise
or magnetic field levels at or near the Portland substation. This project will be designed to
limit noise from the transmission facility to 50 d(B)A or less at the point of 25 feet from the
edge of the property line or right-of-way and limit the magnetic field to 150 mG or less at the
edge of the property line or right -of way.
Pueblo Reservoir 115 kV Distribution Substation
This project consists of constructing a new Pueblo Reservoir distribution substation by
tapping BHCE's Burnt Mill -West Station 115 kV transmission line. The substation will be
built to ultimately accommodate two, 115/13.2 kV, 25 MVA transformers, but only one bank
will be installed initially. The substation will be located near CO -96W and Pueblo Reservoir
Road near the Pueblo Reservoir, Colorado. This project is required to serve new pump station
load as well as contingency back up of existing infrastructure and future load growth in
western Pueblo. The project is estimated to cost approximately $5.5 million with an
estimated construction start date in 2013, and a completion and in-service date of 2014. This
project will be designed to limit noise from the transmission facility to 50 d(B)A or less at
the point of 25 feet from the edge of the property line or right-of-way and limit the magnetic
field to 150 mG or less at the edge of the property line or right -of way.
Boone -Nyberg 115 kV Project
This project was identified as the preferred alternative to adding a second 230/115 kV
transformer at Public Service Company of Colorado's Boone substation in late 2012. The
"Second Boone 230/115 kV Transformer" project was subsequently cancelled as mentioned
2
Before the Public Utilities Commission of the State of Colorado
Decision No. C13 -0608-I DOCKET NO. 13M -0019E
in Black Hill's filing. This project consists of rebuilding the existing 11 -mile segment of
115 kV line between the Boone 115 kV substation and the Nyberg 115 kV substation, as well
as adding a second 115 kV circuit between the aforementioned substations. The project will
place the new line and the rebuilt line on double circuit monopole steel structures, and will be
located within the existing right-of-way. Analysis is currently underway to determine if the
existing 75 foot right-of-way is sufficient for the double circuit line. The project will not be
designed for future 230 kV operation. This project was identified to mitigate thermal loading
issues on the existing Boone -Nyberg 115 kV line, which can experience loading in excess of
the established rating under various stressed system conditions. A second circuit was
identified as part of the project to provide additional local reliability following the loss of the
existing line. An alternative to the planned project design was evaluated. The alternative
consisted of a separate line route and right-of-way for the second circuit, while the existing
circuit would be rebuilt in the existing right-of-way. This alternative presented the reliability
advantage of geographic separation between the lines, but the slight reliability advantage did
not justify the incremental cost of approximately $8.5 million. The maximum (summer)
continuous rating of the proposed 115 kV facilities will be 222 MVA, assuming 795 kcmil
26/7 Strand ACSR "Drake" conductor and line design rating of 100 degrees C, and a
maximum continuous operating voltage of 120.8 kV (105% of nominal). The maximum
(winter) continuous rating of the 115 kV lines will be 240 MVA. The expected new ratings
provide an increase over the current summer/winter ratings of 119 MVA and 120 MVA,
respectively. Previously, analysis was performed for a transmission project utilizing the same
line design as the planned Boone -Nyberg project. This was done to determine the magnetic
field and noise levels with the larger conductor and higher rating under standards specified in
the Commission rules. That analysis was deemed valid for this project. The results indicated
a maximum anticipated noise level of 15.6 db(A) 25 ft beyond the edge of the right-of-way
and a maximum anticipated magnetic field level of 145 mG at the edge of the right-of-way,
one meter above the ground. The electromagnetic field (EMF) and corona noise level
analysis can be found in Black Hill's filing. The total project cost is estimated to be
$13.1 million, which includes the terminal equipment required to accommodate the new
115 kV line at the existing Nyberg and Boone 115 kV substations. This project is currently
scheduled for construction start in 2014 and in-service in 2015.
West Station -Desert Cove 115 kV Rebuild Project
This project consists of rebuilding the existing 3.9 -mile segment of 115 kV line between the
West Station 115 kV substation and the Desert Cove 115 kV substation. The project will be
located within the existing right-of-way. The project is currently planned for single circuit,
115 kV operation, but the benefits and feasibility of alternatives such as future 230 kV design
with 115 kV operation or double circuit 115 kV design and construction are being evaluated.
A detailed assessment of these alternatives was not available at the time of this filing, and
will be included in a subsequent supplemental filing as necessary. The project was identified
to mitigate thermal loading issues that arose through various transmission planning
assessments. The West Station -Desert Cove 115 kV line is one of three parallel paths
between the BHCE transmission system and the interconnection point with several other
utilities at Midway to the north. Certain conditions involving a prevailing power flow from
south to north across the BHCE system, combined with the loss of one or more transmission
3
Before the Public Utilities Commission of the State of Colorado
Decision No. C13 -0608-I DOCKET NO. 13M -0019E
elements can result in the thermal loading on the line exceeding the established thermal
capacity. Additional capacity is needed to avoid the overload risk, and replacing the existing
336 ACSR conductor with 795 kcmil 26/7 Strand ACSR "Drake" conductor was identified as
the solution. The maximum (summer) continuous rating of the proposed 115 kV facility will
be 222 MVA, assuming 795 ACSR conductor and line design rating of 100 degrees C, and a
maximum continuous operating voltage of 120.8 kV (105% of nominal). The maximum
(winter) continuous rating of the 115 kV line will be 240 MVA. The expected new ratings
provide an increase over the current summer/winter rating of 80 MVA. Previously, analysis
was performed for a transmission project utilizing the same line design as the planned Desert
Cove -West Station project. This was done to determine the magnetic field and noise levels
with the larger conductor and higher rating under standards specified in the Commission
rules. That analysis was deemed valid for this project. The results indicated a maximum
anticipated noise level of 16.7 db(A) 25 ft beyond the edge of the right-of-way and a
maximum anticipated magnetic field level of 63 mG at the edge of the right-of-way, one
meter above the ground. The EMF and corona noise level analysis can be found in Black
Hills' filing. The total project cost is estimated to be $1.3 million. This project is currently
scheduled for construction start and completion in 2015.
Projects from prior Rule 3627 filings:
La Junta -Tri-State Interconnection
The La Junta 115 kV Interconnection project consists of a new parallel 115 kV and 69 kV
line between the Tri-State Generation and Transmission Association, Inc. (Tri-State) and
Black Hills La Junta substations. The connection of the two substations, which are
approximately 0.5 miles apart, will provide increased reliability to the local area. An increase
in 115/69 kV transformation capacity at the BHCE-owned La Junta substation will also be a
part of this project to enhance load service in the area. The scope of the project is currently
under review to determine if additional benefits can be realized through changes to the final
design. The project is currently planned for completion and operation in 2015 at an estimated
cost of $6.0 million. No certificate of public convenience and necessity (CPCN) required per
Decision No. C09-1240, Docket No. 09M -392E.
Canon City Capacitor Bank
The scope of this project has been modified from the 20 MVAR capacitor at the Canon City
115 kV substation (as originally submitted in Black Hills Summary 2011 Rule 3206 Report
in Docket 11M -317E, Decision No. C11-0749). The modified project consists of a single
10 MVAR capacitor at the Canon City 69 kV substation that was placed into service on
December 17, 2012. Also included in the project is the addition of a single 10 MVAR
capacitor at the Canon City 115 kV substation with an expected completion and in-service
date of December 2014. This project is needed to facilitate compliance with Colo. House Bill
10-1365 (the Clean Air -Clean Jobs Act (CACJA)) and Decision No. C10-1330 in Docket
No. 10M -254E by providing voltage support to the Canon City area load. This modified
project is not expected to have any impact on noise or magnetic field levels at or near the
Canon City substation. No CPCN is required per Decision No. C11-0749 in Docket
No. 11M -317E.
4
Before the Public Utilities Commission of the State of Colorado
Decision No. C13-0608-1 DOCKET NO. 13M -0019E
Baculite Mesa -Overton 115 kV Line Upgrade Project
The purpose of the original project was to increase the thermal rating of the 115 kV line
between Baculite Mesa and the planned 115 kV Overton substation from 122 MVA to
222 MVA. The planned Overton substation will tap the Baculite Mesa -Northridge 115 kV
line. The scope of this project has been expanded to address the short line span into and out
of the Northridge substation from the line corridor. These spans should be upgraded to avoid
unnecessary reductions in the thermal rating of the rebuilt line between Baculite Mesa and
Northridge. Equipment within the Northridge substation will also need to be upgraded to
accommodate the increased rating. The construction, completion, and in-service dates of the
project have been delayed from 2013 to 2016. The total estimated cost of this project is
$2,000,000. The modified project is not expected to have any impact on noise or magnetic
field levels at or near the Northridge substation. No CPCN is required per Decision
No. C11-0749 in Docket No. 11M -317E.
Second Boone 230/115 kV Transformer
The addition of a second 230/115 kV transformer at the Boone substation was initially
submitted in the 2011 3206 filing. An application for a CPCN or an application for a formal
determination that no CPCN is required was to be filed per Decision No. C11-0749 in Docket
No. 11M -317E. Black Hills and its participating stakeholders agreed to cancel the Second
Boone 230/115 kV Transformer project. A notification of the cancellation was filed by Black
Hills Energy in Docket Nos. 12M -165E and 11M -317E on November 9, 2012. The project
was identified to address reliability concerns in the Rocky Ford/La Junta area of the BHCE
transmission system. The Second Boone 230/115 kV Transformer project has since been
replaced with the Boone -Nyberg 115 kV project.
Overton 115kV Substation
The in-service date of the project has been delayed from 2013 to 2015. The project has been
delayed to allow for a detailed review of the ongoing need for the project as well as the
feasibility of alternatives to the project. No CPCN is required per Decision No. C07-0553,
Case No. 6396.
Public Service Company of Colorado (PSCo, Public Service, or Company)
New projects not previously filed pursuant to Rule 3206(d)(I):
Cherokee — Arvada —Russell — Ridge 230 kV Line Conversion
This project consists of converting the existing Cherokee — Arvada — Russell — Ridge 115 kV
Transmission lines (L9556 and L9686) to 230 kV operation. This line voltage conversion
project coordinates with following Distribution system planning projects at the Arvada and
Russell load serving substations on the Cherokee — Ridge transmission corridor in Denver,
Colorado.
1. "Arvada 230/13.8 kV, 50 MVA #1&2 Replacement" distribution project.
2. "Russell 230/13.8 kV, 50 MVA #1 Replacement" distribution project.
5
Before the Public Utilities Commission of the State of Colorado
Decision No. C13 -0608-I DOCKET NO. 13M -0019E
3. "Russell 230/13.8 kV, 50 MVA #2" second distribution transformer addition at
Russell Substation.
PSCo plans to replace the existing distribution transformers at Arvada Substation due to their
age, which is reflected in the recent gassing issues seen at these units. Russell #2 distribution
transformer is needed to avoid load shedding during single contingency outage of Russell #1
distribution transformer. Considering that distribution transformer addition and replacement
projects are scheduled to occur in this corridor within the next 2-3 years, PSCo considers this
a good opportunity to convert the 115 kV transmission line to 230 kV 5 operation at minimal
overall costs. The line voltage conversion project has the following benefits:
1. Aligning the line voltage conversion project with the scheduled distribution
transformer replacement projects eliminates the need and extra cost of replacing the
distribution transformers again if the line is converted to 230 kV at a later time date.
2. This project allows PSCo to utilize the existing Cherokee — Arvada — Russell — Ridge
transmission infrastructure at its ultimate design capacity.
3. This project also reduces loading on the 230/115 kV auto -transformers at Ridge
Substation, deferring the need for any transformer capacity upgrade.
Further, the voltage conversion project also eliminates the need for the network upgrade
identified at Arvada Substation for the interconnection of Cherokee 2x1 CC, resulting in
estimated cost savings of $380,000. Because the existing transmission lines are already built
to 230kV design specifications, no line rebuilding is needed. The new 230 kV line will be in
the existing 115 kV corridor between Cherokee and Ridge substations. The estimated cost of
the project is $4.29 million. The estimated in-service date is June 2016.
Rosedale 115 kV Line Tap (WAPA)
This project consists of sectionalizing Western Area Power Administration's (WAPA or
Western) Weld — Kersey Tap 115 kV line at PSCo's Rosedale Substation. This project is
needed in order to provide an additional 115 kV source from the Weld Substation to the
eastern side of Greeley. The tap will consist of approximately 200 feet (total) of 115 kV
double circuit line via an in -and -out termination configuration, and associated termination
equipment at Rosedale Substation. This project is needed in order to mitigate certain single
contingency overload conditions and increase the reliability of the Greeley System. Due to
the retirement of Thermo Monfort and Thermo Power generating stations, and load growth in
the Greeley area, certain N-1 contingencies result in thermal overloads of transmission
elements. Specifically, in the event of a single contingency outage of the Weld — Arrowhead
Lake 115 kV line, the Weld — Greeley 115 kV line is loaded beyond 100% of its thermal
rating limit. Tapping the WAPA Weld — Kersey Tap 115 kV line successfully mitigates the
thermal overloads that are a result of the load increase and generation retirement within the
Greeley area. The proposed project will be located in Greeley, Colorado. The estimated cost
of the project is $7.8 million. The estimated in-service date is May 2014.
6
Before the Public Utilities Commission of the State of Colorado
Decision No. C13 -0608-I DOCKET NO. 13M -0019E
Weld 230/115 kV 150 MVA Transformer Replacement and Substation Upgrade
This project replaces the existing 230/115 kV, 150 MVA transformer at PSCo's Weld
Substation with a 230/115 kV, 280 MVA transformer, and rebuilds the existing main and
transfer bus configuration at the substation to a breaker and a half configuration per PSCo's
substation design guidelines. The transformer replacement is needed to avoid thermal
overloads on the existing 230/115 kV, 150 MVA transformer for the single contingency
outage of either of the 230/115 kV transformers at WAPA's Weld Substation. Moreover, in
the event of a fault on PSCo's Weld 115 kV bus, the current substation configuration would
result in an outage of the Weld — Johnstown, Weld — Greeley and Weld — Arrowhead Lake
115 kV lines serving the Greeley area. Finally, a bus fault at WAPA's Weld substation would
overload PSCo's Weld transformer beyond 100% of the emergency rating of the transformer.
Due to the age of the existing transformer and to mitigate the thermal overloads, PSCo
prefers to replace the Weld 230/115 kV, 150 MVA transformer. The bus reconfiguration is
required to increase the reliability of the transmission elements serving the Greeley area, by
reducing the exposure to a multiple contingency outage as a result of bus fault on the 115 kV
bus at PSCo Weld Substation. The proposed project will be located inside PSCo's Weld
Substation in Greeley, Colorado. The estimated cost of the project is $8.15 million. The
estimated in-service date is May 2015.
Foidel Creek 230 kV Line Tap
This project consists of tapping the Hayden — Gore Pass 230 kV line at PSCo's Foidel Creek
Substation. The 230 kV line will be tapped at approximately 11 miles from the Hayden
Substation, approximately 800 feet (total) of in -and -out 230 kV transmission will be built
from the tap point to Foidel Creek 230 kV Substation using 2-1272 kcmil ACSR conductor
strung on 345 kV double circuit structures similar to the existing Hayden -Gore Pass 230 kV
line. This project is needed in order to avoid high voltages above 1.1 per unit at the
Steamboat, Wolcott, Cooley Mesa buses, and the adjoining Holy Cross Electric Association
system in the event of the loss of existing Hayden — Foidel Creek line under light load
conditions. Due to the generation connected at Hayden, the new line will provide voltage
regulation and help eliminate the over voltages. Also, the new line will hence improve
reliability of the system by providing an additional source for YVEA and HCEA loads which
would be fed radially when the existing Hayden — Foidel Creek 230 kV line is lost. The
proposed project will be located in Routt County, Colorado. The in-service date is June,
2015. The estimated cost is $5.26 million.
Monfort 15 MVAR, 44 kV Capacitor Banks
This project installs two steps of 7.5 MVAR, a total of 15 MVAR capacitor bank at the
Monfort 44 kV bus. The capacitor bank is needed for voltage support and stability on the
northern 44 kV transmission system in Greeley under certain single contingency outage
conditions. Loss of Monfort 115/44 kV transformer causes voltages below 0.9 p.u. at the Ault
and Eaton substations, and potentially overloads the Weld 115/44 kV transformer. The
Monfort capacitor bank will eliminate the voltage violations. The capacitor bank will
eliminate thermal overloads on the Weld 115/44 kV transformer by reducing MVAR flow on
the bank. The proposed project will be located at PSCo's Monfort Substation in Greeley,
Colorado. The in-service date is May, 2014. The estimated cost is $1.17 million.
7
Before the Public Utilities Commission of the State of Colorado
Decision No. C13 -0608-I DOCKET NO. 13M -0019E
Russell 230/13.8 kV, 50 MVA #1 Replacement
This project consists of replacing the existing 115/13.8 kV, 50 MVA distribution transformer
at PSCo's Russell Substation with a 230/13.8 kV, 50 MVA transformer. The transmission
portion of this project consists of installing the substation transmission facilities required to
supply the new 230/13.8 kV, 50 MVA distribution transformer and associated equipment.
The transformer replacement is required to accommodate the "Cherokee- Arvada - Russell —
Ridge 230 kV Line Conversion." The second transformer is essentially needed to avoid load
shedding under a single contingency outage of the existing transformer due to lack of
distribution back up in the area. Because of the 230 kV line conversion project, PSCo has
changed the scope of "Russell 115/13.8 kV, 50 MVA #2" project to include a 230/13.8 kV,
50 MVA transformer instead of the previously proposed 115/13.8 kV, 50 MVA transformer.
This is because PSCo's practice is to connect both the distribution transformers in parallel as
they are essentially serving the same load and have to provide backup in case one of the
transformers fails. Because both the new and existing distribution transformers will be
operated in parallel per PSCo's operation standards, PSCo is pursuing the replacement of the
existing 115/13.8 kV transformer with 230/13.8 kV transformer. This project will be located
inside the existing Russell Substation in Jefferson County, Colorado. The in-service date is
June, 2015. The estimated cost is $0.65 million.
Arvada 230/13.8 kV 50 MVA #1 & 2 Replacement
This project consists of replacing the existing 115/13.8 kV, 42 MVA distribution
transformers #1 & #2 at PSCo's Arvada Substation with 230/13.8 kV, 50 MVA distribution
transformers. The transmission portion of this project consists of installing the substation
transmission facilities required to supply the new 230/13.8 kV, 50 MVA distribution
transformers and associated equipment. The Arvada distribution transformers need to be
replaced because of heavy gassing issues seen at the existing transformers. Considering the
cost involved in replacing the transformers, PSCo finds it economically advantageous to
install 230/13.8 kV transformers instead of replacing the existing 115/13.8 kV transformer.
This allows PSCo to operate the Cherokee — Ridge — Arvada — Russell line at 230 kV, and
saves the costs of replacing the transformers at a later time when the line is converted to
230 kV. Also, the 230/13.8 kV, 50 MVA transformers provide increased load serving
capacity. This project will be located inside the existing Arvada Substation in Jefferson
County, Colorado. The in-service date is June, 2015. The estimated cost is $1.2 million.
Projects from prior Rule 3627 filings:
Weld 230/115 kV 150 MVA #3
Install a third 115/230 kV, 150 MVA transformer at WAPA's Weld Substation. This project
is needed to relieve overloads on the existing 115/230 kV transformers (PSCo and WAPA
transformers) at Weld Substation for single contingency outage of either transformer. This
project is a joint project between PSCo and WAPA. The proposed project will be located
inside WAPA's Weld Substation in Weld County, Colorado. No CPCN is required for this
project pursuant to Decision No. C11-0927 in Docket No. 11M -375E. The in-service date is
April 2013, at a cost of $3 million.
8
Before the Public Utilities Commission of the State of Colorado
Decision No. C13 -0608-I DOCKET NO. 13M -0019E
90 MVAR Capacitor Bank at Cherokee 115 kV Bus
Install a 90 MVAR capacitor bank at Cherokee 115 kV bus. This capacitor bank is needed to
provide voltage support in the Cherokee area after the retirement of Cherokee #1 and #2
generating units per the Commission's CACJA Decision Nos. C10-1328 and C11-0121 in
Docket No. 10M -245E. No CPCN is required per Decision No. C11-0749 in Docket
No. 11M -317E. The proposed project will be located inside Cherokee Substation in Adams
County. The in-service date is April 2013, at a cost of $2.28 million.
Jewell 230/13.8 kV, 50 MVA #3
The distribution portion of the project consists of installing a third 230/13.8 kV, 50MVA
transformer at Jewell Substation. The transmission portion of the project consists of installing
the 230 kV substation transmission facilities required to supply the new transformer and
associated equipment. This project is needed due to the lack of distribution tie back up
support in case of a single contingency outage of one of the existing transformers. The
proposed project will be located inside Jewell Substation in Arapahoe County, Colorado. No
CPCN is required per Decision No. C11-0749 in Docket No. 11M -317E. The in-service date
is March 2013, at a cost of $0.1 million.
Federal Heights 115/13.8 kV, 50 MVA #3
The distribution portion of the project consists of installing a third 115/13.8 kV, 50 MVA
transformer at Federal Heights Substation. The transmission portion of the project consists of
installing the 115 kV substation transmission facilities required to supply the new
transformer and associated equipment. This project is needed to avoid overloading of the
existing transformers under a single contingency outage of either transformer. The proposed
project will be located inside Federal Heights Substation in Federal Heights, Colorado. No
CPCN is required per Decision No. C11-0749 in Docket No. 11M -317E. The in-service date
is March 2013, at a cost of $0.25 million.
90 MVAR Capacitor Bank at Arapahoe 115 kV Bus
Install a 90 MVAR Capacitor bank at Arapahoe 115 kV bus. This project is needed to
provide voltage support in the Arapahoe area after the retirement of Arapahoe #3 generating
unit per the Commission's CACJA Decision Nos. C10-1328 and C11-0121 in Docket
No. 10M -245E. The proposed project will be located inside Arapahoe Substation in Denver,
Colorado. No CPCN is required per Decision No. C11-0749 in Docket No. 11M -317E. The
in-service date is December 2013, at a cost of $3.34 million.
Godfrey Breaker Station and 30 MVAR Capacitor Bank
Convert the existing Godfrey switching station to a Breaker station using a three breaker ring
configuration. This project is needed to provide reliability to the Greeley area after the
expiration of power purchase contracts with Thermo Greeley (32 MW, 6/2011) and Thermo
Power (69 MW, 8/2013). A 30 MVAR capacitor bank will be installed at Monfort 115 kV
bus to provide voltage support for Eastern Greeley. The proposed project will be located
inside the Godfrey Switching Station in Weld County, Colorado. No CPCN is required per
Decision No. C11-0749 in Docket No. 11M -317E. The in-service date is May 2013, at a cost
of $4.54 million.
9
Before the Public Utilities Commission of the State of Colorado
Decision No. C13-0608-1 DOCKET NO. 13M -0019E
Pawnee -Smoky Hill 345kV Transmission Line Project
The Commission granted PSCo a CPCN for this project on February 26, 2009, Decision
No. C09-0048, Docket No. 07A -421E. The in-service date is May 2013.
Havana 115/13.8 kV, 50 MVA #3
The distribution portion of the project consists of installing a third 115/13.8 kV, 50 MVA
transformer at Havana Substation. The transmission portion of the project consists of
installing the 115 kV substation transmission facilities required to supply the new
transformer and associated equipment. This project is needed to avoid overloading of the
existing transformers in case of a single contingency outage of either transformer. The
proposed project will be located inside Havana Substation in Denver, Colorado. No CPCN is
required per Decision No. C11-0749 in Docket No. 11M -317E. The in-service date is
June 2013, at a cost of $0.41 million.
Chambers 230/115 kV, 280 MVA #2
Install a second 230/115 kV, 280 MVA transformer at Chambers Substation. This project is
needed to avoid overloading of the existing transformer under certain double -contingency
outages and for increased reliability. The proposed project will be located inside Chambers
Substation in Aurora, Colorado. No CPCN is required for this project pursuant to Decision
No. C11-0927 in Docket No. 11M -317E. The in-service date is June 2013, at a cost of
$5.2 million.
Lacombe 230/13.8 kV, 50 MVA #3
The distribution portion of the project consists of installing a third 230/13.8 kV, 50 MVA
transformer at Lacombe Substation. This project is needed to provide load relief for the 2nd
network under system intact conditions and to construct the 14th network off the new
Lacombe #3. The transmission portion of the project consists of installing the 230 kV
substation transmission facilities required to interconnect the third transformer and associated
equipment. The proposed project will be located inside Lacombe Substation in Denver,
Colorado. No CPCN is required per Decision No. C11-0749 in Docket No. 11M -317E. The
in-service date is June 2013, at a cost of $0.2 million.
Malta 230/115 kV, 100 MVA #2
Install a second 230/115 kV, 100 MVA transformer and associated equipment at Malta
Substation. This project is required to support a 40 MW load addition at Climax Substation.
Without the second transformer, the existing transformer overloads under certain single
contingency outages requiring load shed. The proposed project will be located inside Malta
Substation in Lake County, Colorado. No CPCN is required per Decision No. C11-0927 in
Docket No. 11M -317E. The in-service date is October 2013, at a cost of $13.3 million.
Poncha Junction 115/230 kV Auto Transformer (280 MVA)
In-service date changed from 5/2013 to 11/2013 due to construction delays in relocating
WAPA's lines. WAPA has committed to 20% capacity in this project. The project scope will
also include 40 MVAR reactors on the tertiary winding of the 230/115/13.8 kV, 280 MVA
transformer. The reactors will compensate for the capacitive charging on the line, and reduce
high voltages in the San Luis Valley area under system intact conditions. The in-service date
10
Before the Public Utilities Commission of the State of Colorado
Decision No. C13 -0608-I DOCKET NO. 13M -0019E
is November 2013 at a cost of $8.4 million. No CPCN is required per Decision
No. C09-0681, Docket No. 09M -392E.
Plainview - Eldorado 115 kV Line Rebuild Project
Replace the existing Plainview — Eldorado 115 kV line with 115 kV transmission structures
and 477 ACSR Hawk conductor rated for 150 MVA. This line has been derated to 17 MVA
due to low line to ground clearance limitations of the existing "Milliken" structures, per
NESC requirements. Because of the age of the existing conductor, structures, and extremely
low line rating, replacement of the tower structures and conductor is required. The low rating
of the present line causes system intact overloads. Line terminations and other necessary
substation transmission facilities will be installed at Plainview and Eldorado Substations to
accommodate the new line. The new line will be built to meet the Commission's
requirements for EMF and noise specified in sections (e) and (f) of Rule 3206. The 115 kV
line is located in Boulder and Jefferson Counties, Colorado. Pursuant to Decision
No. C11-0927 in Docket No. 11M -317E a CPCN is not required.
Monfort to DCP Midstream 115 kV Line
A Petition for Declaratory Order was filed on March 9, 2012 seeking a declaration from the
Commission that the construction of a single circuit, 3.5 mile, 115 kV radial transmission
line to provide interconnection between DCP Midstream LP's Plant No. 9 and Public
Service's Monfort substation is in the ordinary course of business and does not require a
CPCN from the Commission. The estimated cost of the project is $10,650,000. The
Commission determined in Decision No. C12-0306, Docket No. 12D -227E that no CPCN is
required.
Ptarmigan Substation (230/24.0 kV, 28 MVA)
Public Service continues its siting activities for a new distribution substation. The project
involves a transmission line tap on the existing Dillon -Blue River 230 kV transmission line
to a "to -be -determined" substation site, and construction of feeders from the new substation
facility to interconnect with the existing distribution system in the Silverthorne area.
As described in the Company's 2011 3206 Report, in 1999 Summit County denied Public
Service's application for approval of a substation site and transmission line tap after the
Company identified a preferred site through a comprehensive siting process that included
substantial public involvement. Public Service decided to not appeal Summit County's
denial, and instead built a 4 -mile express feeder from the Dillon Substation into the
Silverthorne area to help address reliability concerns. Over time, load growth in the area has
continued to stress the delivery system driving the need for this new substation to serve
existing and future customers.
Since its last 3206 Report, Public Service has been searching for a potential site. Finding an
acceptable location for this distribution substation and associated facilities continues to be
very challenging due to the mountainous topography, vocal opposition to any substation site
near existing subdivisions, environmental sensitivities, and the visual qualities of the area.
However, Public Service continues to actively investigate potential sites while considering a
variety of the substation designs to help minimize potential impacts.
11
Before the Public Utilities Commission of the State of Colorado
Decision No. C13 -0608-I DOCKET NO. I3M-0019E
The current forecasted capital cost is $6.3 million at the transmission level and $17.1 million
at the distribution level (not including feeder work). Over time, land availability, land price
escalation, increased construction costs, and equipment price increases have contributed to
this substantial escalation in costs. The in-service date is October 2014.
Capitol Hill 115/13.8 kV 50 MVA #3
The distribution portion of the project consists of installing a third 115/13.8 kV 50 MVA
transformer at Capitol Hill Substation. The transmission portion of the project consists of
extending the 115 kV bus and installing the 115 kV transmission facilities required to supply
the new transformer. This project is needed to eliminate overloads on the existing
transformers for single contingency outage of the other transformer. The proposed project
will be located inside Capitol Hill Substation in Denver, Colorado. No CPCN is required per
Decision No. C11-0749 in Docket No. 11M -317E. The in-service date is May 2014, at a cost
of $1.4 million.
Russell 115/13.8 kV, 50 MVA #2
The scope of this project has changed to include a 230/13.8 kV, 50MVA # 2 transformer
instead of the 115/13.8 kV, 50 MVA#2 previously reported. The230/13.8 kV transformer
would allow conversion of the Cherokee — Arvada —Russell — Ridge 115 kV line to 230 kV
operation as stated in the "Cherokee —Arvada — Russell — Ridge230 kV Conversion" project
found in the "New Projects" section of this report. This eliminates the need to replace this
transformer in the future when the 115 kV line is converted to 230 kV. No CPCN is required
for the original project pursuant to Decision No. C11-0749, Docket No. 11M -317E.
Brantner Substation (Distribution, 115/13.8 kV, 50 MVA)
The in-service date is June 2014 at a cost of $1.76 million. No CPCN is required per
Decision No. C10-0644, Docket No. 10M -206E.
Hayden 230/138 kV, 250 MVA #KZ2A Transformer
This project would replace the existing 230/138 kV, 150 MVA #KZ2A transformer at
Western's Hayden Substation with a 230/138 kV, 250 MVA transformer. The project is
100% owned and operated by Western. Public Service will have capacity rights in this
transformer. Public Service requires this capacity in order to continue supplying station
service power to its Hayden generation plant and Yampa Valley Rural Electric Association
(YVEA) loads at Mt. Harris Substation, both of which are currently being served by Hayden
transformers through a transmission service contract. Western is proposing this transformer
replacement project in order to eliminate thermal overloads on the existing 230/138 kV,
150 MVA #KZ2A transformer when the other parallel 230/138 kV, 250 MVA #KZ1A
transformer is not available. The agreement between Western and Public Service (SLC-0229
Exhibit F) stipulates that parties negotiate good faith participation in the projects when the
transformer needs to be replaced. Pursuant to the discussions between the participating
entities (Western, Tri-State, and Public Service), Western will be responsible for installing
and maintaining the transformers and Public Service will have 20% capacity rights in the
transformer. This project will be located inside Western's Hayden Substation in Moffat
County, Colorado. The in-service date is 2014, with an estimated cost of $2.02 million
12
Before the Public Utilities Commission of the State of Colorado
Decision No. C13 -0608-I DOCKET NO. I3M-0019E
(Public Service's share, transmission dollars). Pursuant to Decision No. C12-0996, Docket
No. 12M -165E a CPCN is not required.
Leetsdale 230/115 kV, 280MVA #2
In compliance with the final Commission Order in the CACJA in Docket No: 10M -245E,
Public Service will retire Cherokee Units 1 & 2 in 2012. Public Service also plans to operate
Arapahoe Unit 4 only as needed during peak system conditions.
As was foreshadowed in the Settlement Agreement approved by the Commission in Docket
No. 11A -209E, in the Company's view it is likely that the Arapahoe 3 synchronous
condenser approved in the CACJA docket will not be needed, and that the unit can be retired.
See Decision No. R11-0854 in Docket No. 11A -209E. Finally, Public Service's contracts for
power from Arapahoe Units 5, 6, & 7 and Valmont Units 7 & 8 expire in 2012. Under these
conditions, the Capitol Hill — Denver Terminal 115 kV underground line (L9007)
can become overloaded during 2014 summer peak load conditions under certain
generation dispatch patterns after the forced outage (contingency) of the Leetsdale
230/115 kV#1 auto -transformer. With Cherokee Unit 4 unavailable due to its unscheduled
(forced) outage, this contingency causes the Capitol Hill — Denver Terminal 115 kV
underground line # L9007 to overload to 119% of its 131 MVA summer normal rating.
To mitigate this potential overload, the preferred solution is to add a second Leetsdale
230/115 kV auto -transformer to effectively eliminate the contingency causing the overload.
The next best alternative would be to upgrade the Capitol Hill — Denver Terminal 115 kV
line with a new underground cable. Due to the access limitations to the Capitol
Hill — Denver Terminal 115 kV line for construction, this alternative is not being pursued.
The Leetsdale 230/115 kV, 280 MVA #2 transformer project was recommended by the
Commission as part of its CACJA order.
This project will be located inside the Leetsdale Substation in Denver, Colorado. The
in-service date is October, 2014, with an estimated cost of $8.69 million. Pursuant to
Decision No. C12-0996, Docket No. 12M -165E a CPCN is not required.
MVAR Reactors at Midway and Waterton Substations
In this project the Company proposes to install one 13.8 kV, 40 MVAR reactor on the tertiary
winding of each of the 345/230/13.8 kV, 560 MVA transformers at Midway and Waterton
Substations. The reactors are required to compensate for the capacitive line charging Vars
(Volt Ampere Reactive) produced by the Midway - Waterton 345 kV line which results in
high voltages at the Midway 345 kV and Waterton 345 kV buses. The high voltages are
aggravated during light load conditions or when Comanche unit #3 is offline. In addition, the
Comanche -Daniels Park 345 kV lines #1 & 2 are also producing capacitive line charging
Vars which further increase the high voltages. The need for this project exists at present and
the current operational practice is to take one of these 345 kV lines out of service under high
voltage conditions. Taking lines out of service is not a preferred alternative as it affects the
reliability of the system. Installation of the 40 MVAR reactors at the Midway and Waterton
transformers will help maintain voltage at the buses below 1.05 per unit, and will provide
operational flexibility. The Midway Substation is located in El Paso County, Colorado and
13
Before the Public Utilities Commission of the State of Colorado
Decision No. C13 -0608-I DOCKET NO. 13M-00 l9E
Waterton Substation is located in Douglas County, Colorado. The in-service date is October,
2014, at a cost of $3.48 million. Pursuant to Decision No. C12-0996, Docket No. 12M -165E
a.CPCN is not required.
Mt. Harris 138/69 kV, 50 MVA #2
This project consists of adding a second Mt. Harris 138/69 kV, 50 MVA transformer at
Public Service's Mt. Harris Substation. The project is needed to alleviate contingency
overloads of the existing 138/69 kV, 50 MVA transformer at Mt. Harris Substation.
The YVEA system consists of 69 kV transmission and 44 kV transmission that provides
radial transmission service to several load -serving substations in the YVEA service territory.
The YVEA system is supplied through four transmission transformers - the Mt. Harris
138/69 kV, 50 MVA transformer, the Craig Transfer 230/69 kV, 50 MVA transformer, the
Steamboat 230/69 kV, 50 MVA transformer #1 and the Steamboat 230/69 kV transformer
#2. YVEA can shift loads among the transformers by opening and closing transmission
connections on the system. Formerly, one of the transformers could be taken out of service
and the remaining three transformers could serve the YVEA system. The YVEA demand has
increased to a high enough level that serving all the YVEA loads under various demand
conditions with one of the transformers out -of -service is no longer possible. System studies
have shown that adding a second Mt. Harris 138/69 kV transformer will allow the Mt. Harris
138/69 kV transformer #1 or the Craig Transfer 230/69 kV transformer to be taken
out -of -service and still serve the YVEA loads. The proposed project will be located inside
the existing Mt. Harris Substation in Routt County, Colorado. No CPCN is required pursuant
to Decision No. C12-0777, Docket No. 12M -165E. The in-service date is October, 2014, at a
cost of $6.21 million.
RiflePS - Parachute 230 kV Line #2
This project consists of building a second 230 kV transmission line between PSCo's Rifle
Substation and Parachute Substation. Approximately 21 miles of 230 kV transmission, rated
for 576 MVA will be built using a 1-1272 kcmil conductor, in a new right-of-way. An
application for a CPCN or an application for a formal determination that no CPCN is
required shall be filed per Decision No. C11-0749 in Docket No. 11M -317E. The in-service
date is October, 2015, at a cost of $27 million. A CPCN for this project was granted in
Decision No. C13-0256, Docket No. 13A -0032E.
Bluestone Valley Substation and De Beque-Bluestone Valley 69 kV Line
"Bluestone Valley Substation" was contained in a prior Rule 3206 Report and reflected a
2014 in-service date in that report. The project scope has been modified to include a
230/69 kV transformer and 69 kV protection equipment at the Bluestone Valley Substation.
The Bluestone Valley 230 kV yard will be laid out to accommodate the future
Bluestone Valley — Clear Creek 230 kV double -circuit transmission line. A two-mile
De Beque-Bluestone Valley 69 kV line will be constructed. The De Beque-Cameo 69 kV
transmission line will be removed. The "Bluestone Valley Substation and De Beque-
Bluestone Valley 69 KV Line" project has an in-service date of October, 2015. No CPCN is
required per Decision C09-0681, Docket No. 09M -392E.
14
Before the Public Utilities Commission of the State of Colorado
Decision No. C13-0608-1 DOCKET NO. 13M -0019E
Weld — DCP Midstream 115 kV Line
In this project the Company proposes to construct a new 115 kV transmission line;
approximately nine miles in length, from the Weld Substation to the DCP Midstream
Substation (located approximately three miles west of the town of Lucerne). This
transmission line will be a single 115 kV circuit routed along the northwestern area of
Greeley and will require an expansion of existing transmission corridor or acquisition of new
transmission corridor. With the completion of the "Monfort — DCP Midstream 115 kV Line"
described below and in the Company's Petition for Declaratory Order filed on March 9, 2012
in Docket No. 12D -227E, constructing this proposed transmission circuit from Weld
Substation to DCP Midstream Substation will provide an alternative 115 kV transmission
source from Weld Substation to Monfort Substation (Weld — DCP Midstream — Monfort).
The project will increase the reliability of the 115 kV system in Greeley, as well as increase
reliability to the DCP Midstream Substation. This project eliminates thermal overloads on the
Weld - Arrowhead Lake 115 kV line under certain single contingency outage conditions.
This project also provides added capacity on the 115 kV system for future load growth in the
area. The proposed 115 kV line will be built from the Weld Substation to the
DCP Midstream Substation, both located in Weld County, Colorado. No CPCN is required
for this project pursuant to Decision No. C12-0306, Docket No. 12D -227E. The in-service
date is 2015 with an estimated cost of $15 million.
Sheridan 115/13.8 kV, 50 MVA #2
The transmission portion of this project consists of installing the substation transmission
facilities required to supply a second 115/13.8 kV, 50 MVA distribution transformer and
associated equipment at Public Service's Sheridan Substation. The second transformer is
required to eliminate thermal overloads on the first existing transformer under certain single
contingency outage conditions. This project will be located inside the existing Sheridan
Substation in Jefferson County, Colorado. No CPCN is required for this project pursuant to
Decision No. C12-0777 in Docket No. 12M -165E. The in-service date is October, 2015, at a
cost of $0.24 million.
Happy Canyon 115kV (IREA load service, 115/12.47 kV, 50 MVA)
The transmission project cost estimate is $1.77 million with an in-service date of January,
2016. No CPCN is required per Decision No. C06-0761, Case No. 6396.
Glenn 230/13.8 kV 50 MVA#3
The transmission portion of this project consists of installing the 230 kV substation
transmission facilities required to supply a third 230/13.8 kV, 50 MVA distribution
transformer and associated equipment at the existing Glenn Substation. The third transformer
is needed to provide reliability to the distribution loads and avoid thermal overloads on the
two existing transformers during a single contingency outage of the other transformer. This
project will be located inside the existing Glenn Substation in Adams County, Colorado. The
in-service date is June, 2016, with an estimated cost of $0.18 million. No CPCN is required
pursuant to Decision No. C12-0777 in Docket No. 12M -165E.
15
Before the Public Utilities Commission of the State of Colorado
Decision No. C13 -0608-I - DOCKET NO. 13M -0019E
Wilson #1 Substation (Distribution 115/13.8 kV 14 MVA)
The in-service date is May 2018 at a cost of $3.37 million. No CPCN is required per
Decision No. C10-0644, Docket No. 10M -206E.
New Castle 115/69-24.9 kV Substation (Distribution, 16 MVA)
The project involves the installation of a 115-24.9 kV, 16 MVA distribution transformer.
The in-service date is October, 2019. No CPCN is required per Decision No. C08-0676,
Case No. 6396.
Harvest Mile 230/345 kV Substation
This project is a component of the Lamar - Front Range (LFR) Transmission Project (filed in
the 2010 Rule 3206 report). LFR studies showed that when resources are injected into the
345 kV system east of Smoky Hill Substation, the planned Smoky Hill 345/230 kV,
560 MVA auto transformers (proposed in the Pawnee - Smoky Hill 345 kV Senate Bill (SB)
07-100 project) have the potential to overload for single contingency outages of the other
parallel transformer. Harvest Mile Substation will also accommodate future transmission
projects to Spruce, Daniels, Park, and Pawnee. An application for a CPCN or an application
for a formal determination that no CPCN is required shall be filed per Decision
No. C11-0749 in Docket No. 11M -317E. The in-service date is 2018-19, at a cost of
$21 million.
Pawnee- Daniels Park 345 kV
Transmission Line Project Scheduled for in-service in2019. A CPCN is required for this
project pursuant to Decision No. C12-0777, Docket No. 12M -165E.
Barker Substation (Distribution, 230/13.8 kV 50 MVA)
The in-service date is June, 2021 at a cost of $16.4 million. No CPCN is required per
Decision No. C10-0644, Docket No. 10M -206E.
Parachute -Cameo 230kV transmission line
The in-service date has been delayed to a drop in anticipated load growth. Estimated cost is
$48.5 million. A CPCN is required per Decision No. C10-0644, Docket No. 10M -206E.
Lamar - Front Range 345 kV Transmission Line Project
The Lamar — Front Range studies have been performed in concert with studies of the Lamar
— Vilas Transmission Project. The planning studies have been completed, and Public Service
and Tri-State are preparing project study reports that should be available this summer.
However, no decisions have been made with respect to implementation and both companies
are evaluating what strategies are most appropriate should the Company believe moving
forward with the project would benefit our customers. A CPCN is required for this project
pursuant to Decision No. C10-0644, Docket No. 10M -206E.
Lamar - Vilas 230/345 kV Transmission Line Project
Several transmission alternatives were evaluated through the Lamar -Front Range study
process, and the most recent plan consisted of double-circuit230 kV transmission with an
associated cost estimated to be approximately $90 million. Due to the uncertainties described
16
Before the Public Utilities Commission of the State of Colorado
Decision No. C13-0608-1 DOCKET NO. 13M -0019E
for the Lamar Front Range project, and the fact that the Lamar — Vitas project relies on the
Lamar Front Range project, implementation has been moved beyond 2019. A CPCN is
required for this project pursuant to Decision No. C10-0644, Docket No. 10M -206E.
Weld County Transmission Expansion Project
The project name has been changed to "TOT7 expansion project". Public Service recognized
the potential for the project to help meet reliability and load -serving needs north of the
Denver metro area, particularly in the Greeley area. The other transmission entities have
expressed interest in participating in the project to explore the potential to meet their own
reliability and resource needs. Public Service has announced that the project will go through
the WECC Project Coordination Review and Project Rating Review processes, and has
invited all interested parties to participate in a "Project Review Group". Public Service will
begin the transmission study process this summer. Participants and stakeholders will have the
opportunity to provide input into the plan, with the goal of recommending a discreet
transmission project that can serve a variety of needs. Once a project has been recommended,
PSCo will assess a plan for implementation. A CPCN is required for this project pursuant to
Decision No. C10-0644, Docket No. 10M -206E.
Rifle(Ute)-Story Gulch 230 kV Transmission Line Project
This project has been delayed due to a delay in customer load growth. The new in-service
date has not been determined. A CPCN is required for this project pursuant to Decision
No. C10-0644, Docket No. 10M -206E.
San Luis Valley - Calumet - Comanche Transmission Project
A CPCN was granted in Decision No. R10-1245, Docket No. 09A -325E. However, as stated
in the Company's SB 07-100 Designation of Energy Resource Zones and Transmission
Planning Report, dated October 2011, our electric resource plan calls into question any
immediate need to pursue the San Luis Valley -Calumet -Comanche project in the form
discussed in earlier SB100 reports. The Company has further stated that to the extent the
Commission's Phase 1 decision in its 2011 Electric Resource Plan did not significantly
deviate from Public Service's Phase 1 proposals, Public Service anticipated ending its
involvement in the Project. The Commission issued its initial Phase 1 decision on
January 24, 2013. Several parties including Public Service filed applications for rehearing,
reargument, and reconsideration (RRR). The Commission deliberated on those applications
for RRR on March 12, 2013 and issued its written decision on March 15, 2013. In its
March 15, 2013 order the Commission made substantive changes to its January 24, 2013
decision. As a result, the Company filed another application for RRR on April 4, 2013.
However, Public Service has determined that in its view, the Commission's March 15, 2013
decision did not significantly deviate from Public Service's Phase 1 proposals. In addition,
the Company has also determined that the issue raised in the Company's second application
for RRR will have no impact on the Company's decision to pursue the Project. As a result,
the Company is currently in a position to state that it is ending its involvement in the Project,
and will not proceed with its construction.
17
Before the Public Utilities Commission of the State of Colorado
Decision No. C13 -0608-I DOCKET NO. 13M -0019E
RURAL ELECTRIC ASSOCIATIONS
Grand Valley Power (Grand Valley)
Grand Valley filed a letter indicating that it has no plans for new generation or transmission
facilities within the next three years.
La Plata Electric Association, Inc.
New projects not previously filed pursuant to Rule 3206(d)(I):
Bayfield to County Line 115 kV Conversion
This project is a rebuild of an existing line to provide clearance for upgraded under built
distribution. The estimated cost of this project is $1,516,666. The in-service date is 2014.
TS Bayfield to US160 Relocation
This project is to relocate an existing 69 kV line to allow for substation relocation. The
estimated cost of this project is $658,000. The in-service date is 2015.
Intermountain Rural Electric Association, Inc. (IREA)
New projects not previously filed pursuant to Rule 3206(d)(I):
Compark Substation (Compark Area, Town of Parker Douglas County)
This project is to construct a new substation to provide additional capacity for anticipated
loads in the Compark area. The substation location is still to be determined. The facility will
be IREA's standard configuration of two, 30/40/50 MVA, 115/12.47 kV transformers and
metal clad switchgear. The in-service date is April 2017. The estimated cost is $5,000,000.
Grandview-Compark 115 kV transmission line (from existing Grandview Substation in a
westerly direction to the proposed South Creek Substation; Route still being determined.)
This project will construct a new double -circuit 115 kV line from the existing Grandview
Substation west approximately 1.0 mile to the proposed Compark Substation. The continuous
MVA rating to be 239 MVA. The in-service date is April 2017. The estimated cost is
$1,500,000.
Projects from prior Rule 3627 filings:
Como substation (56 County Road 33, Como, CO 80432)
No CPCN is required pursuant to Decision No. C07-0553, Case No. 6396. The purpose of
this project is to increase capacity and convert the existing IREA substation from 44 kV to
115 kV and add a 10/12/14 MVA, 115/12.47 kV transformer and a 50 MVA, 115-44 kV
autotransformer. The expected in-service date is January 2013.
Shaffers Crossing to Pine Junction 115 kV transmission line (Jefferson County between
Shaffers Crossing and Pine Junction along State Highway 285)
The purpose of this project is to rebuild and upgrade the existing 44 kV transmission line to
115 kV. This line segment is approximately 1.5 miles and is required to be relocated due to
18
Before the Public Utilities Commission of the State of Colorado
Decision No. C13 -0608-I DOCKET NO. 13M -0019E
road improvement project. The continuous MVA rating is 239 MVA. The in-service date is
November 2014. The estimated cost is $1,200000. No CPCN is required pursuant to
Decision No. C12-0777 in Docket No. 12M -165E.
Phase 1 - Conifer to Shaffers Crossing 115 kV transmission line(Jefferson County between
Conifer and Shaffers Crossing along State Highway 285)
No CPCN is required pursuant to Decision No. C10-0644, Docket No. 10M -206E. This
project will rebuild and upgrade an existing 44 kV transmission line to 115 kV. This line
segment is approximately 7 miles of which 1.5 miles is scheduled to be rebuilt in 2014. The
continuous MVA rating is to be 239 MVA. The in-service date is September 2017. The
estimated cost is $1,300,000. No CPCN is required per Decision No. C10-0644, Docket
No. 10M -206E.
Happy Canyon Substation (City of Centennial. 125 and Happy Canyon)
No CPCN is required pursuant to Decision No. C06-0761 in Case No. 6396. The purpose of
this project is to construct a new substation to provide additional capacity to serve new 1REA
loads in the area. The facility will be 1REA's standard configuration with two 30/40/50 MVA,
115/12.47 kV transformers and metal clad switchgear. The substation will tap PSCo's
existing 115kV transmission line from Daniels Park to Castle Rock Substation. PSCo will
own the 115kV bus configuration and 1REA will own the transformers and distribution
switchgear. The in-service date is January 2016. The estimated cost is $4,000,000.
Mountain View Electric Association, Inc.
New projects not previously filed pursuant to Rule 3206(d)(I):
Anderson Substation Expansion
This project will install a 3rd Transformer, distribution exit circuits, and 115 kV
sectionalizing at Anderson Substation. The estimated cost of this project is $1,811,250. The
in-service date is 2014.
Lorson Substation Expansion
The purpose of this project is to install a second transformer. The estimated cost of this
project is $569,100. The in-service date is 2014.
Tri-State Generation and Transmission Association, Inc. (Tri-State)
New projects not previously filed pursuant to Rule 3206(d)(I):
Keota 345/115 kV Substation
The project involves constructing a new 345/115 kV 225 MVA substation to serve oil and
gas field loads and a new natural gas processing plant being constructed, owned, and
operated by Noble Energy near Keota. The proposed substation will interconnect to the
existing Laramie River Station to Story 345 kV transmission line owned in part by Tri-State.
Tri-State considers the project to be load -serving in nature. Noble Energy will be a customer
19
Before the Public Utilities Commission of the State of Colorado
Decision No. C13 -0608-I DOCKET NO. 13M -0019E
of Morgan County REA, which will take electric service from the Keota 345/115 kV
Substation for service to Noble Energy and other Morgan County REA customers. The
facilities associated with the Keota 345/115 kV Substation project do not materially affect
Tri-State's 10 -year Plan as presented in its PUC 3627 filing. The estimate cost of the project
to Tri-State is $11 million and the expected in-service date is 2014.
Lamar 2nd 230/115 kV Transformer
The project involves adding a new 230/115 kV 100 MVA transformer to the existing Lamar
Substation and sectionalizing the existing 230/115 kV transformer bank with the addition of
three 230 kV breakers and three 115 kV breakers.
The existing transmission system between the Boone and Lamar substations consists of a
230 kV line, a 115 kV load serving loop, an underlying 69 kV sub -transmission system, and
generation facilities. Planning studies have investigated the performance of the transmission
and sub -transmission system in the Lamar area without the availability of the Lamar
generators. The Lamar generators have a combined rating of 44 MW and are connected to the
69 kV sub -transmission system. Their availability greatly effects the load serving capability
of the local sub -transmission system. Studies have found that for certain system conditions,
voltage collapse in the Boone -Lamar area is possible during a Lamar 230/115 kV transformer
outage when the Lamar generators are out of service.
The addition of a second transformer at Lamar will provide critical backup for a loss of the
existing Lamar transformer bank. The sectionalizing will prevent simultaneous loss of the
Lamar -Willow Creek and Lamar-Vilas 115 kV lines for certain system conditions. The
facilities associated with the Lamar 2nd 230/115 kV Transformer project do not materially
affect Tri-State's 10 -year Plan as presented in its PUC 3627 filing. The estimate cost of the
project to Tri-State still needs to be determined, and the expected in-service date is 2015.
Projects from prior Rule 3627 filings:
Bullock #2 115/12kV Transformer Replacement
Replace Tri-State's existing 12/16/20/22.4 MVA 115-12.5 kV transformer (T2) at Bullock
Substation with a new 21/28/35 MVA top -rated two -winding transformer to serve existing
and new load in the area. Bullock Substation is in the service territory of Delta Montrose
Electric Association (DMEA). Tri-State will coordinate replacement with DMEA as it will
be replacing T1 with a similar transformer at the same time. The relay protection will be
replaced for T1 and T2 transformers. Tri-State's cost of the project is $1.27 million with an
in-service date of 2013. No CPCN is required per Decision No. C09-0681, Docket
No. 09M -392E.
Carey 230kV Substation
Construction of a new tap and substation sectionalizing PRPA's Ault -Timberline 230 kV
transmission line for delivery to Poudre Valley REA. This new distribution substation will
enable Poudre Valley to serve existing load and new load in the vicinity of Severance,
Windsor, and Timnath caused by the growth of these communities along the interstate
corridor. The proposed project will provide transmission system capacity, voltage support,
20
Before the Public Utilities Commission of the State of Colorado
Decision No. C13 -0608-I DOCKET NO. 13M -0019E
and reliability to Poudre Valley's existing customer load that currently must be served from a
combination of five other distribution substations (Black Hollow, Boxelder, Airport, Trilby,
and Windsor). A CPCN is not required per Decision No. CI1-1146 in Docket
No. 11D -747E. The in-service date is 2013 at a cost of $7.775 million.
Davis Delivery Point
To serve the new Anadarko Lancaster Plant (gas compression and petroleum refining) by
interconnecting with an existing 115 kV transmission line between Fort Lupton and Hudson
owned by Public Service. Tri-State intends to construct a short (1.5 mile) 115 kV radial
transmission line (795 ACSR conductor) from Public Service's line to serve a new substation
(Davis), which is to be constructed at the Anadarko site. The new Davis substation will
initially include a single 40 MVA 115-13.2 kV transformer, with provisions for additional
transformation. It is to be located in United Power's service territory, in Weld County, north
and east of Fort Lupton. Tri-State considers the project to be "in the ordinary course of
business" since the facilities will be designed for 115 kV and the 1.5 mile transmission line
will be a radial line terminating at the Anadarko premises. Both Anadarko and United Power
will take distribution service from the Davis substation. All facilities associated with the
Davis Delivery Point project are load -serving facilities and do not materially affect
Tri-State's 10 -year Plan as presented in its PUC 3627 filing. A CPCN is not required
pursuant to Decision No. C12-0777 in Docket No. 12M -165E. The in-service date of this
project is 2013, with an estimated cost of $5.615 million.
DCP Midstream 115 kV Delivery Point
To serve the new LaSalle Natural Gas Processing Plant (to be owned and operated by
DCP Midstream) by interconnecting with an existing 115 kV transmission line
(Weld-Willoby) owned by the WAPA, and constructing a short (2 -mile) radial transmission
line (795 ACSR conductor, single steel pole) to serve a new substation (South Kersey),
which is to be constructed adjacent to the gas plant. The new South Kersey substation will
ultimately include 3 - 115 kV breakers, two (2) 20 MVA 115-4.16 kV transformers, and
4.16 kV metering. It is to be located in Poudre Valley Rural Electric Association's service
territory, in Weld County, about 2 miles southwest of the town of Kersey. A CPCN is not
required pursuant to Decision No. C12-0777 in Docket No. 12M -165E. The in-service date
of this project is 2013, with an estimated cost of $10.337 million.
Delta County 115 kV Transmission Line Improvement Project
The existing 115 kV transmission system serving the area surrounding the City of Delta
consists of one radial line feeding Garnet Mesa Substation. This radial line is tapped off the
Hotchkiss to North Mesa 115 kV line at a point, approximately 8 miles east of Garnet Mesa
Substation, known as Garnet Mesa Tap. At Garnet Mesa Substation, this 115 kV line is a
power source for Delta -Montrose Electric Association's (DMEA) 46 kV system through a
single 38 MVA, 115/46 kV autotransformer. Under normal system conditions the DMEA
46 kV system is operated open between Garnet Mesa Substation and Tri-State's Hotchkiss
Substation as well as Garnet Mesa and Tri-State's Happy Canyon Substation. Tri-State also
has a Grand Junction to Montrose 115 kV line, which is located west of the City of Delta.
The project is needed to provide improved reliability to DMEA and the City of Delta, which
are the utilities served from Garnet Mesa Substation by Tri-State. Tri-State currently has no
21
Before the Public Utilities Commission of the State of Colorado
Decision No. C13 -0608-I DOCKET NO. 13M -0019E
ability to backup this substation for a single contingency outage. DMEA has a 46 kV
transmission system through which it takes delivery of power from Tri-State at several
substations, including Garnet Mesa Substation. In the past, DMEA has been able to serve its
own loads as well as provide backup wheeling of power to the City of Delta at Garnet Mesa
Substation through its existing 46 kV system during an outage of the 115 kV system.
However, this ability is being diminished through continuing load growth in the area. In the
near future, DMEA is likely to have to use this system only for its own customers during
disturbances to the radial 115 kV system serving Garnet Mesa Substation. During peak load
conditions, the 46 kV system is currently insufficient to serve all area load, even that of
DMEA, without the 115 kV line. The scope and feasibility of the project is dependent upon
agreement between DMEA, the City of Delta, and Tri-State. A CPCN is not required
pursuant to Decision No. C03-0707 in Case No. 6396. The in-service date of this project is
2013, with an estimated cost to Tri-State of $10.732 million.
East Montrose 115 kV Delivery Point
DMEA has experienced a significant increase in load east of the City of Montrose. A number
of new loads are proposed along Highway 50 east of Montrose. DMEA is proposing to
initially install a 115-12.5 kV, 12/16/20 MVA, transformer in a new East Montrose
Substation.
Ultimate layout of this substation is a 115 kV six circuit breaker ring bus, with initial
installation of three circuit breakers, one 115-12.5 kV, 20 MVA transformers serving
distribution feeders, and one 34.5-115 kV 10.5 MVA step up transformer from the South
Canal Hydro station. This substation will be fed from a 115 kV line that will be terminated at
the new Peach Valley Switching Station. This switching station will be a tap out of the
Hotchkiss to North Mesa transmission line. The new Peach Valley Switching Station will be
a three (3) breaker ring bus and will be located north of the North Mesa substation. The
115 kV line segment from the new East Montrose Substation to South Canal Substation will
be constructed later.
Tri-State will construct approximately 10 miles of 477 MCM ACSR wood H -frame 115 kV
transmission line from the new Peach Valley Switching Station to the proposed East
Montrose Substation and from the East Montrose Substation to the South Canal Substation.
In addition, Tri-State will construct the new Peach Valley station and will be responsible for
the installation of the line disconnect switches and the revenue quality metering at the East
Montrose Substation. DMEA will be responsible for the distribution transformers, at East
Montrose Sub, and the 115 kV circuit breakers. A CPCN is not required pursuant to Decision
No. C06-0761 in Case No. 6396. The in-service date of this project is 2013, with an
estimated cost to Tri-State of $13.949 million.
Olive Creek 115 kV Delivery Point (Formerly Williams Midstream Wray Project)
To serve a gas pipeline pumping station located south and east of Wray, CO and operated by
Williams -Midstream. The liquid natural gas pumping load will be approximately 5 MW. The
proposed project will provide adequate transmission system capacity, voltage support, and
reliability to the customer.
22
Before the Public Utilities Commission of the State of Colorado
Decision No. C13-0608-1 DOCKET NO. 13M -0019E
The project was submitted in Tri-State's 3627 filing with a change in project scope from the
3206 supplemental filing. Instead of a radial line extending from the Wray Substation, as was
originally envisioned, the project will now interconnect (at Olive Creek Tap) to Tri-State's
existing Wray -Vernon Tap 115 kV transmission line south of the Wray Substation. A new
radial 115 kV transmission line will be constructed from that interconnection approximately
three miles to the Williams -Midstream Wray facility. Tri-State will add 115 kV breakers at
Vernon Tap.
Consistent with the original project scope, Tri-State considers the revised project scope to
also be "in the ordinary course of business" since the facilities will be designed for 115 kV
and since the transmission line extension will be a radial line serving a single customer
terminating at the customer's premises.
This project was submitted to the CPUC on May 13, 2011 as a supplement to Tri-State's
2011 3206 filing. CPCN Decision No. C11-0749 in Docket No. 11M -317E determined that
no CPCN is required. The in-service date of this project is 2013, with an estimated cost of
$5.552 million.
Plaza —Waverly 115 kV Loop Project
The existing transmission system in San Luis Valley cannot adequately serve the loads under
single line outage conditions. It is proposed to rebuild the existing Waverly -Plaza 69 kV line
to 115 kV to solve this problem. The project includes the following:
Install three 115 kV line positions at Waverly. One line position is for the
Wavery-Carmel-Switch Rack 115 kV line, and the other one is for the
Waverly -Stockade -San Acacio 115 kV, which now operates at 69 kV but is insulated
at 115 kV.
Rebuild 14 miles, 1/0 ACSR, Carmel -Switch Rack 69 kV line to 115 kV with
795 ACSR. The existing 2 miles, Waverly -Carmel 69 kV line, is insulated at 115 kV.
Rebuild 13 miles, 1/0 ACSR, Switch Rack -Plaza Junction 69 kV line to 115 kV with
795 ACSR.
Construct a new 3.5 miles, Plaza Junction -Plaza 115 kV line with 795 ACSR.
Install three 115 kV line positions at Plaza to loop the San Luis Valley -Ramon line
and connect the Plaza -Switch Rack line.
Move the existing Waverly 115/69 kV transformer and install two new 69 kV
breakers to Plaza.
A CPCN is not required pursuant to Decision No. C07-0553 in Case No. 6396. The
in-service date of this project is 2013, with an estimated cost to Tri-State of $11.111 million.
23
Before the Public Utilities Commission of the State of Colorado
Decision No. C13-0608-1 DOCKET NO. 13M -0019E
Bayfield 115/69 kV Transformer Replacement
To serve new industrial load, mainly for the San Juan Basin Project, and native load growth
in the area between Bayfield and Pagosa Substations. Originally the additional gas wells
being developed in this area were to be served from the Saul's Creek 115 kV Delivery Point
but that plan has changed to have the new well load added to the 69 kV system. Tri-State will
remove the existing 115-69 kV, 10/12.5 MVA transformer and replace it with a new
115-69 kV, 21/28/35 MVA transformer. Tri-State will also install the oil containment pit as
required by the transformer change. A CPCN is not required pursuant to Decision
No. C09-0681 in Docket No. 09M -392E. The in-service date of this project is 2014, with an
estimated cost to Tri-State of $1.614 million.
Burlington -Wray 230 kV Line
The in-service date is 4Q 2015 at a cost of $40.27 million. A CPCN was required pursuant to
Decision No. C10-0644, Docket No. 10M -206E, and was granted in Decision No. C11-0042,
Docket No. 10A -906E.
FARR-Windy Gap 138/69 kV Double Circuit Loop Project
This projects cost is $14.3 million and has an in-service of 2015. No CPCN is required per
Decision No. C90-1125, Case No. 6396.
La Junta 69 kV Tie Line Addition
The in-service date is 2015 at a Tri-State cost of $0.578 million. A CPCN is not required
pursuant to Decision No. C10-0644, Docket No. 10M -206E.
United Power system Improvement Project — Phase III
The in-service date is 2015 at a cost to Tri-State of $4.929 million. No CPCN required per
Decision No. C04-0725, Case No. 6396.
LPEA-San Juan Project
Tri-State's share of the project cost is $113,938,000 million with an in-service date of 2016.
CPCN required per decision No. C09-0681, Docket No. 09M -392E.
Lamar -Front Range and Lamar-Vilas Transmission Project
The Lamar to Front Range project is in the development stage. Tri-State has been evaluating
technical studies for several alternatives in cooperation with a variety of stakeholders. The
current in-service date is outside the time period required for the Rule 3206 filing. Additional
information concerning the status of this project will be provided as it becomes available.
The Lamar-Vilas transmission project is also in the planning stage. Tri-State has been
evaluating technical studies for several alternatives in cooperation with a variety of
stakeholders. The current in-service date is outside the time period required for the Rule 3206
filing. Additional information concerning the status of this project will be provided as it
becomes available. A CPCN is required per Decision No. C10-0644, Docket No. 10M -206E.
24
Before the Public Utilities Commission of the State of Colorado
Decision No. C13 -0608-I DOCKET NO. I3M-0019E
H. ORDER
A. The Commission Orders That:
1. Notice is hereby given that the above investor -owned utilities and rural electric
cooperative associations have submitted information concerning the proposed construction of
transmission facilities in accordance with Rule 3206 of the Rules Regulating Electric Utilities,
4 Code of Colorado Regulations 723-3. Pursuant to that rule, you are notified that the
information is available for inspection at the offices of the Commission during regular business
hours.
2. By June 15, 2013, any interested person, firm, or corporation may file comments
about the projects identified by the information now filed with the Commission. The
Commission will consider any comments in determining which projects do not require a
certificate of public convenience and necessity, which projects will require the utility to file an
application for a certificate of public convenience and necessity, or which projects will require
the utility to file for a formal determination that a certificate is not required.
3. This Order is effective upon its Mailed Date.
25
Before the Public Utilities Commission of the State of Colorado
Doug Dean,
Director
Decision No. C13 -0608-I DOCKET NO. 13M -0019E
B. ADOPTED IN COMMISSIONERS' WEEKLY MEETING
May 22, 2013.
(S EA L) THE PUBLIC UTILITIES COMMISSION
OF THE STATE OF COLORADO
JAMES K. TARPEY
PAMELA J. PATTON
ATTEST: A TRUE COPY Commissioners
CHAIRMAN JOSHUA B. EPEL ABSENT.
26
Hello