FA CILITIES S TUD Y 2009-G1 · The 2009-G1 interconnection request is a proposed 200MW Large...

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Facilities Study for Interconnection Request 2009-G1 Craig – Ault 345kV Transmission Line

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Executive Summary This Facilities Study is provided by the Western Area Power Administration (Western) in response to the ongoing request of queue position 2009-G1 (Requestor). The Facilities Study provides reasonable estimates for Western’s costs and schedule of project implementation.

The 2009-G1 interconnection request is a proposed 200MW Large Generation Interconnection Project (Laramie Wind Project) on the Craig – Ault 345kV transmission line in Southern Wyoming. The proposed interconnection point is approximately 62 miles northwest of the Ault 345kV substation.

The 2009-G1 interconnection request influences WECC Constrained Path 39 (TOT 5). This constrained path consists of eight transmission lines that cross the continental divide in Colorado and Southern Wyoming. The existing transfer limits of the TOT 5 corridor is 1680 MW. The Craig – Ault 345kV transmission line is one of the lines that make up the TOT 5 constrained path and is jointly owned by Western, Tri-State Generation and Transmission Inc., and Platte River Power Authority. In addition to these participants, Public Service Company of Colorado (Xcel) is a TOT 5 participant. Joint transmission and TOT owners are impacted entities and as such must review and approve the SIS analysis for interconnection.

The SIS determined that the 200MW project would require the following facilities to interconnect to the transmission system:

1) A new 345kV sectionalizing switchyard on the Craig – Ault 345kV transmission line.

2) A 34.5kV dispatchable reactor on the collector system to off-set VAR injections from the collector system.

In addition to the above requirements this Facilities Study found that the interconnection step-up transformer must be a minimum of 9% impedance.

The TOT 5 transfer capability was not impacted as a result of the interconnection of the wind farm and the full 200MW of capacity could be interconnected with no impact to the existing transmission system. A transmission request has not been filed with Western for this proposed interconnection, therefore, transmission upgrades may be required to deliver the output of the generation to a point of delivery. These transmission upgrades may be required due to contractual, thermal, or operational constraints (i.e. Available Transfer Capacity) and may increase the overall cost of the project to deliver the power from the interconnection to the end user.

The estimated cost for the interconnection to the Craig – Ault 345kV transmission line is $9,702,561 over an estimated schedule spanning April 2012 to May 2014.


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1. DESCRIPTION

1.1. Background of Request

In January 2009, an Interconnection Request (IR) was submitted to the Rocky Mountain Region of the Western Area Power Administration (Western) for interconnection of a new wind energy development called the Laramie Wind Project. The Interconnection Customer’s Laramie Wind Project is a 200MW wind generation project on the Craig – Ault 345kV transmission line with an in-service date of November 1, 2014. This interconnection request was given the queue number 2009-G1.

A System Impact Study (SIS) was performed to determine the effects of the installation and interconnection of the wind project on the power system. The SIS used a Western Electricity Coordinating Council (WECC) approved 2011 Heavy Summer Operating case that was modified to include all relevant system upgrades to properly represent the transmission system in the 2012 time frame. A 2% annual load growth was assumed to escalate the loads from the 2011 operating case.

The Craig – Ault line is part of WECC Path 39 also known as TOT 5 and the line is jointly owned by Western Area Power Administration, Tri‐State Generation and Transmission Inc., and Platte River Power Authority. In addition, to these participants, Public Service Company of Colorado (Xcel) is a TOT 5 participant. Joint transmission and TOT owners are impacted entities and as such must review and approve the SIS analysis for interconnection. The study modeled the injection of 200MW on the Craig – Ault 345kV transmission line with all prior-queued projects included in the base case and the TOT 5 path preloaded to the maximum limit of 1680MW. Steady-state (powerflow), short circuit and dynamic stability analysis were performed during the study. The SIS determined that 2009-G1 could be interconnected to the system with the addition of the following facilities:

- A new three-breaker 345kV switching station - A 34.5kV collector system equipped with a dispatchable reactor to off-set VAR

injections from the collector system

In addition the Facilities Study found that the interconnection step-up transformer must be a minimum of 9% impedance.

This Facilities Study will analyze costs for the interconnection and propose a schedule for the addition of the facilities. Since a transmission request has not been filed with Western for this proposed generator interconnection these costs may change significantly and the schedule for interconnection may change depending on the results of a transmission request System Impact Study.

1.2. Purpose

This Facilities Study verifies the results of the SIS and provides a more detailed description and cost estimate for the proposed transmission request.

1.2.1. This Facilities Study specifies and estimates the cost of the equipment, engineering, procurement and construction work needed (see Appendices A) to implement the conclusions of the SIS in accordance with Good Utility Practice.


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1.2.2. This Facilities Study identifies the electrical switching configuration and ratings of the connection equipment, including, without limitation, switchgear, breakers, meters, and other station equipment (see Appendices B and C).

1.2.3. This Facilities Study defines the nature and estimated cost of Western’s facilities and identifies network upgrades that are necessary to accomplish the interconnection. An estimate of the time required for completion of the construction and installation of such facilities is included in Appendix D.

1.3. Description of Connection Facility

The requirement for interconnection to the Craig – Ault 345kV line is a sectionalizing Switchyard. Western requires the installation of a 345kV, three breaker ring bus configuration to meet the sectionalizing requirements (see switching diagram and drawings in Appendix B and design data in Appendix C). In addition the interconnection step-up transformer must be a minimum of 9% impedance.

1.4. Description of Existing Western Facilities Related to Request

The interconnection request 2009-G1 is a 200MW wind power plant on the Craig – Ault 345kV transmission line. The existing Western facilities related to the transmission request that are required to be upgraded are as follows:

1.4.1 345kV Transmission Line from Craig to Ault

Western operates and maintains the 345kV transmission line from the Craig Substation to the Ault Substation. The cost for operation and maintenance is shared between the three owners of the transmission line.

The Craig to Ault transmission line is 181.3 miles long and has a thermal rating of 956MVA. The transmission line was constructed using bundled two-conductor 1272kCM ACSR. There are four sections of the transmission line that are constructed using 3064kCM ACSR. Those sections are the approach spans at Craig and Ault Substations, and the spans through Steamboat and over Buffalo Pass.

1.4.2 345kV Ault Substation

The Ault Substation is located near Ault, Colorado. The Craig – Ault transmission line is connected to the 345kV section of Ault Substation at switch 199. The disconnect switches in the Ault Substation are rated 345kV, 1600 amps. Switches 193 and 195, normally open, were installed for the purpose of connecting to a series capacitor bank (removed in the 1980’s, see Appendix B). Switches 193 and 195 will not be modified. The bus system on the 345kV portion of the Ault Substation is 5” IPS Aluminum. Relaying modifications are required at the Ault Substation.

1.4.3 345kV Craig Substation

The Craig Substation is located near Craig, Colorado. The Craig – Ault Transmission line is connected to the 345kV section of the Craig Substation at switches 795 and 893. The disconnect switches in the Craig Substation are rated 345kV, 1600 amps. Relaying modifications are required at the Craig Substation.

1.4.4 345kV 2007-G2 Substation

The 2007-G2 project is a higher queued project than 2009-G1 and is an interconnection of 300MW on the Craig – Ault 345-kV transmission line approximately 14 miles east of


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the 2009-G1 interconnection point. If this substation is constructed then relaying modifications will be required at the substation.

2. SUMMARY OF PRIOR STUDIES

2.1. Feasibility Study

There was no Feasibility Study performed associated with this interconnection request.

2.2. System Impact Study

The System Impact Study (SIS) for 2009-G1 was finalized in September 2011. The SIS agreement was given contract number 09RMR1918.

2.3. Environmental Studies

The Interconnection Customer has signed an Environmental Agreement with Western under contract number 10RMR2107. Environmental requirements are discussed in section 3.5.

3. FACILITY STUDY REQUIREMENTS

3.1. Contracts

Under contract 11RMR2250, Western has performed this Facilities Study to specify and estimate the cost of the equipment, engineering, procurement and construction work needed to implement the conclusions of the System Impact Study that are associated with Western owned equipment. This Facilities Study determines all electrical equipment requirements required by the SIS for Western-owned equipment. In addition, this Facilities Study develops a schedule (Appendix D) and cost estimate (Appendix A) for all Western labor, switchyard design and construction, land acquisition and associated overhead, and substation upgrades.

3.2. Interconnection Facilities

By definition provided in the Large Generator Interconnection Procedures (LGIP) Manual, Interconnection Facilities shall mean Transmission Provider’s Interconnection Facilities and the Interconnection Customer’s Interconnection Facilities. Collectively, Interconnection Facilities include all facilities and equipment between the Generating Facility and the Point of Interconnection, including any modifications, additions or upgrades that are necessary to physically and electrically interconnect the Generating Facility to the Transmission Provider’s Transmission System. Interconnection Facilities are sole use facilities and shall not include Distribution Upgrades, Stand Alone Network Upgrades or Network Upgrades.

3.2.1. Point of Interconnection

The Point of Interconnection is the location at which a Large Generation Facility is interconnected with the Transmission System (Section 4.1).

3.3. Network Upgrades and/or Modifications

The LGIP Manual describes Network Upgrades as the additions, modifications, and upgrades to the Transmission Provider’s Transmission System at or beyond the point at


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which the Interconnection Facilities connect to the Transmission Provider’s Transmission System to accommodate the interconnection of the Large Generating Facility to the Transmission Provider’s Transmission system. The required Network Upgrades are detailed in this Facilities Study (Section 4.2) and the estimated costs of the Network Upgrades are included in Appendix A.

3.4. Operations Requirements

An Interconnection Agreement is required prior to energization. An Operating Guide will be developed by Western to outline the necessary operating restrictions on the wind farm. Coordination of the proposed work at all affected facilities could affect the generation output capability until all work is completed. Costs associated with developing the Operating Guide are not included in this Facilities Study.

3.5. Environmental Requirements

The Requestor has made a separate request for the environmental studies. The Requestor shall be responsible for establishing the scope of the environmental studies requirements in coordination with Western. This Facilities Study estimates that a project of this size shall require an Environmental Impact Statement (EIS). The Requestor has provided Western with $70,000 to cover Western's internal costs for preparation, review and coordination of the EIS and supporting documentation. These costs are not included in the cost estimate in Appendix A.


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4. STUDY RESULTS

4.1. Interconnection Facilities

4.1.1. Interconnection Customer’s Interconnection Facilities

These costs are not included in the Facility Study Cost Estimates. The Requestor’s Facility shall include (as a minimum):

a. Point of Interconnection: One – Self supporting, full tension Dead-End Structure located approximately 200 to 400 feet outside of Western’s Switchyard and aligned with the designated connection point

b. 345kV transmission line between the Dead-End Structure and the Requestor’s Substation

c. Requestor’s Substation i. One – 345kV, 2000 amp power circuit breaker or equivalent interrupter for

transformer protection ii. One – 345kV manual group operated disconnecting switch iii. One – 34.5/345kV step-up transformer with a minimum 9% impedance. iv. Controlled/Dispatchable Reactor sized appropriately based on final

collector system layout to off-set VAR injections from the collector system onto the bulk transmission system at all times.

d. Relaying at the Requestor’s Facility shall provide adequate safeguards, at the approval of the Transmission Provider, in order to prevent the operation of the turbines onto a faulted system

Western will make the final connection from the Requestor’s 345kV dead-end structure to the dead-end in Western’s switchyard.

4.1.2. Transmission Provider’s Interconnection Facilities

Western’s Interconnection Facilities include a Switchyard configured as a 345kV three breaker ring bus and relaying at adjacent and remote terminals. The portion of the three breaker ring bus that is considered the transmission providers interconnection facilities consists of the following elements (see also Appendices A, B and C):

a. One 345kV A-Frame dead-end

b. Instrument transformers for control and relaying

c. Relay and control equipment (see also section 4.1.3)

d. Communication equipment – Communication is required from Western’s operation center located in Loveland, Colorado to the Switchyard to provide for remote control of equipment, obtain alarm status and metering data from the Switchyard, relay communications requirements and to provide a voice link to the Switchyard. Western will design, procure, and install all communication equipment necessary for communication from the Switchyard to Western’s operation center. The existing Craig – Ault 345kV transmission line has microwave and power line carrier systems for communications. Communication equipment required for the new Switchyard is included in the estimated cost.

e. Metering equipment and metering instrument transformers


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4.1.3. Relaying at Remote Terminals

Changes to the existing line relays in the adjacent substations of Craig and 2007-G2 substations will be required for interconnection. In addition adjustment of Zone 3 distance relay settings at secondary substations and switchyards not directly adjacent to the Craig or Ault substations may be required. This Facilities Study identifies Zone 3 distance relay setting adjustments will be required for the following secondary substations:

• Ault – 2007-G2 345kV Line (breakers 692, 696) at Ault • Craig – Bears Ears 345kV Line (breakers 1392, 1496) at Bears Ears • Craig – Meeker 345kV Line (breakers 696, 492) at Meeker (Non-Western)

4.2. Western Network Upgrades

The System Impact Study determined that the upgrade required to interconnect 2009-G1 was a 345kV sectionalizing switchyard. These costs are included in the Facility Study Cost Estimates (Appendix A).

4.2.1. 345kV Sectionalizing Switchyard

Western’s Interconnection Facility is a Switchyard configured as a 345kV three breaker ring bus. The portion of the three breaker ring bus that is considered a Network Upgrade consists of the following elements (see Appendices B and C):

a. Three 345kV, 2000 amp, SF6 power circuit breakers b. Six 345kV, 2000 amp, motor operated, group operated disconnect switches c. Three 345kV, 2000 amp, motor operated, group operated disconnect switches

with ground blades d. 5 acres (217,800 square feet) of land for the new Switchyard e. One 345kV A-Frame dead-end f. One 230 square foot Control building g. Approximately 1.5 miles of distribution interconnect for station service power

from Carbon Power and Light, Inc

4.3. Non-Western Network Upgrades

The 2009-G1 interconnection request required one Non-Western Network Upgrade: remote relaying changes identified in Section at 4.1.3.at Tri-State’s Meeker Switchyard. The Requestor is responsible for coordinating with Tri‐State Generation and Transmission Inc. to accomplish these changes.

4.4. Cost Estimate

The Project Cost Estimate is provided in Appendix A. The Estimated Cost of each line item is given in FY 2010 dollars (per the WAPA 2010 Conceptual Planning and Budget Cost Estimate Guide) then escalated to FY 2012 dollars. Total Costs will depend on actual expenditures and actual project schedule. The Requestor shall reimburse Western for actual expenditures incurred.


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4.5. Project Schedule

The Estimated Schedule for the switching station project is provided in Appendix D based on construction by Western. If the project is delayed, Western will reevaluate equipment lead times, workload, and construction seasons to determine a reasonable schedule.

The Requestor’s new in-service date of November, 2014 is highly dependent on the length of time required to complete the EIS, and may not be acceptable. Western estimates 18-24 months to complete the EIS process from the Notice of Intent. This timeframe may be shorter dependent on the public review process. The EIS must be completed prior to signing the LGIA and commencing construction. However, at the request of the Interconnection Customer, Western can commence design while the environmental study is in progress. This assumption was accounted for in the schedule

As shown in the Estimated Schedule, a project start date of April 2012 allows for an in-service date of July 2015. Major Milestones and Project Phases are listed below:

4.5.1. Switching Station Construction

a. Project Start – April, 2012

b. Environmental Studies – April, 2012 to May, 2014

c. Design & Specification – June, 2012 to February, 2013

d. Construction – August, 2014 to July 2015

e. Commissioning –May, 2015 to July, 2015

f. In Service Date – July, 2015

Facilities Study for Interconnection Request 2009-G1 Craig-Ault 345kV Transmission Line

APPENDIX A Cost Estimates


Appendix A: Design and Construction Budgetary Cost Estimates

Description Qty Cost (2010) Extnd Cost Year Esc Final Cost NotesCT/VT Metering

(Metering Unit)3 $138,000 $414,000 2012 1.0435 $432,000 Metering Units

VT Protection (3ph‐

CCVT)3 $36,000 $108,000 2012 1.0435 $112,700 Metering Units

Substation

Communications1 $480,000 $480,000 2012 1.0435 $500,900 Microwave Communications

Relaying Changes

(Adjacent Terminals)2 $25,000 $50,000 2012 1.0435 $52,200 Western Labor Costs

Relaying Changes

(Remote Terminals)3 $25,000 $75,000 2012 1.0435 $78,300 Western Labor Costs

$176,415

Westerns' Labor Costs1 $197,976

$1,550,491

Description Qty Cost (2010) Extnd Cost Year Esc Final Cost Notes345kV, 2000A Bus Line

Bay3 $1,641,000 $4,923,000 2012 1.0435 $5,137,000 Substation Costs

Lands 5 $10,000 $50,000 2012 1.0435 $52,200 Land Cost

Substation Service

Building (ft2)230 $1,000 $230,000 2012 1.0435 $240,000 Substation Costs

$814,380

Western's Labor Costs1 $913,624

$7,157,204

$870,770

$9,578,465

10% Contingency

2009-G1 SWITCHING STATION

Notes:

1. The above is a budgetary level estimate intended to be accurate to +/‐20%.

2. Estimate includes escalation as indicated.

3. The estimate does not include the design and construction cost of a new access road to the Switchyard, if it is required.

4. Interconnection Customer's Interconnection Facilities (Section 4.1.1) are not included in this estimate.

TRANSMISSION PROVIDER'S INTERCONNECTION FACILITIES

NETWORK UPGRADES - Construction Contract

Total for Transmission Providers Interconnection Facilities

Total for Network Upgrades

15% Location and Terrain Factor

1 Western Labor Costs are assigned proportionality: 18% to TP's Interconnection Faciliies, 82% to Network Upgrades

15% Location and Terrain Factor

Total for 2009‐G1 SWITCHING STATION:


APPENDIX B Switching Diagrams

Switchyard General Arrangement and Sections Plan and Profile of Interconnection

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APPENDIX C Design Data


DESIGN DATA SHEET 2009-G1

APPENDIX D

DESCRIPTION UNITS DESIGN

REQUIREMENT

Service Conditions

Location -- WY T12N R74W Section 5

Maximum ambient temperature °C (°F) 43.3 (110)

Average 24 hour temperature °C (°F) 8.5 (47.3)

Minimum ambient temperature °C (°F) -37.8 (-36)

Seismic zone rating -- 1

Altitude (approximate) feet 7720

Maximum wind speed mph 110

Snow and ice loading -- Yes, 1-inch radial ice

System Description

Primary voltage kV 345

Frequency Hz 60

Transmission Line

Conductor size (at proposed site) Kcmil 1272 (2C-Bundle)

Conductor type (at proposed site) ACSR, AAC ACSR

Conductor stranding (at proposed site) Al / steel 54/19

Length of transmission line, total (Craig – Ault) Miles 181.30

Length of transmission line, 2009-G1 to Craig Miles 119.30

Length of transmission line, 2009-G1 to 2007-G2 Miles 14

Length of transmission line, 2009-G1 to Ault Miles 62

Switching station electrical data

Current rating Amps 2000

Phase to phase clearance* Inches 156

Phase to ground clearance* Inches 106

Equipment basic impulse level (BIL) kV 1300

Switching station bus

Material Aluminum Tube

Diameter (IPS) Inches 4

Schedule - 40

Alloy - 6063-T6


DESIGN DATA SHEET 2009-G1

APPENDIX D

DESCRIPTION UNITS DESIGN

REQUIREMENT

Breakers

Quantity 3

Voltage rating kV 345


Interrupt rating kA 40

Metering Units

Quantity 3

Voltage kV 345

PT Ratio - 1800/3000:1

Single or multi-ratio - Single

CT Ratio - 2000:5

Accuracy % ±0.3

Disconnect switches

With ground blades, Quantity 3

Without ground blades, Quantity 6

Motor operated -- Yes

Voltage rating kV 345


Material Al / Cu Al

Configuration - Vertical break

Group operated -- Yes

Interconnection Transformer

Voltage – HV Side kV 345

BIL – HV Side kV 1300

Impedance (Minimum) PU 9% * In accordance with NEMA SG6-2000 Appendix A, Table 36-2


APPENDIX D Schedule

ID Task Name Duration Start Finish

1 2009-G1 345-KV ADDITIONS 864 days 4/2/2012 8/17/20152 PROJECT MANAGEMENT 864 days 4/2/2012 8/17/20153 Project start date 1 day 4/2/2012 4/2/20124 Project Kick Off Meeting & Site Meetings 5 days 3/19/2013 3/25/20135 Project Plan Approved 5 days 3/26/2013 4/1/20136 Project Close-out Completed 28 days 7/9/2015 8/17/20157 All Contracts are closed out 10 days 7/9/2015 7/22/20158 All Work Orders are closed out 5 days 7/14/2015 7/20/20159 Lessons learned meeting held 10 days 7/14/2015 7/27/2015

10 Final report on project metrics complete 10 days 7/28/2015 8/10/201511 Project close out report completed and signed by pr 5 days 8/11/2015 8/17/201512 LARGE GENERATOR INTERCONNECTION AGREEMENT 1 day 6/9/2014 6/9/201413 LGIA executed 1 day 6/9/2014 6/9/201414 ENVIRONMENT 532 days 4/3/2012 5/9/201415 Environmental Kick Off Meeting 1 day 4/3/2012 4/3/201216 Notice of Intent (EIS) 8 wks 4/4/2012 5/30/201217 Required Studies Completed 22 mons 5/31/2012 2/27/201418 Draft EIS Document Review 30 days 2/28/2014 4/10/201419 Environmental Clearance Received 1 day 5/9/2014 5/9/201420 FIELD DATA COLLECTION 36 days 3/3/2014 4/21/201421 Land and ROW needs/routes Identified 2 wks 3/3/2014 3/14/201422 Route & Cadastral Surveys Completed 5 days 3/17/2014 3/21/201423 Geological Investigation Completed (includes Resistivity 21 days 3/17/2014 4/14/201424 Field/Design Data Completed 5 days 4/15/2014 4/21/201425 LANDS 52 days 2/28/2014 5/12/201426 Crossing Agreements Completed (write or modify) 1 day 2/28/2014 2/28/201427 Title Surveys 30 days 2/28/2014 4/10/201428 Rights of Entry Completed 1 day 2/28/2014 2/28/201429 Lands/ROW Acquired 1 day 5/12/2014 5/12/201430 DESIGN AND SPECIFICATIONS 179 days 4/2/2013 12/16/201331 Outdoor Design & Specifications 179 days 4/2/2013 12/16/201332 Pre-design Site Meeting 2 days 4/2/2013 4/3/201333 Start Construction Specification & Design 55 days 4/4/2013 6/20/201334 Outdoor 1/3 Design - Review Completed 5 days 7/29/2013 8/2/201335 Outdoor 2/3 Design - Complete Review 11 days 9/20/2013 10/4/201336 Final Spec & Drawings - Complete Review 7 days 10/28/2013 11/5/201337 Final Spec & Drawing Review Meeting 1 day 11/21/2013 11/21/201338 Final Design & Specifications Received 1 day 12/16/2013 12/16/201339 Indoor Design & Specifications 112 days 4/18/2013 9/25/201340 Start Control Design 40 days 4/18/2013 6/13/201341 Contol Design Single Line Diagram Review 2 days 6/28/2013 7/1/201342 Control Design Panel Board Layout Drawings Revie 2 days 7/17/2013 7/18/201343 Control Design AC Circuits Review 2 days 8/2/2013 8/5/201344 Contol Design DC Circuits Review 2 days 8/20/2013 8/21/201345 Control Design Misc Schematic Items and Logic Dia 2 days 9/6/2013 9/9/201346 Control Design Wiring Diagrams Final Review 2 days 9/24/2013 9/25/201347 PROCUREMENT 297 days 7/19/2013 9/15/201448 OUTDOOR GFE-Government Furnished Equipment 194 days 12/17/2013 9/15/201449 GFE 345-KV Breakers 194 days 12/17/2013 9/15/201450 Outdoor GFE Specifications Received 1 day 12/17/2013 12/17/201351 Outdoor GFE Solicitations Issued 1 day 12/18/2013 12/18/201352 Outdoor GFE Bid Opening 1 day 12/27/2013 12/27/201353 Outdoor GFE Contract Awarded 1 day 12/30/2013 12/30/201354 Breakers Shipped 10 days 9/2/2014 9/15/201455 INDOOR GFE-Control Panels & Relays 146 days 7/19/2013 2/14/201456 Indoor GFE Specifications Received 1 day 7/19/2013 7/19/201357 Indoor GFE Solicitations Issued 9 days 7/22/2013 8/1/201358 Indoor GFE Bid Opening 1 day 8/16/2013 8/16/201359 Indoor GFE Contract Awarded 5 days 8/19/2013 8/23/201360 Control Panels w/relays shipped 10 days 2/3/2014 2/14/201461 Principle Construction Contract 164 days 12/17/2013 8/4/201462 Specifications, Drawings, and Contract Prep Sheet 4 days 12/17/2013 12/20/201363 CO Prepares and issues SB Clearance (DOE F422 1 day 12/23/2013 12/23/201364 CSO/SBA review & approval of DOE 4220.F 15 days 12/24/2013 1/14/201465 CO prepares solicitation package & documentation 15 days 1/15/2014 2/4/201466 CSO review & approval of solicitation 5 days 2/5/2014 2/11/201467 Issue Synopsis 5 days 6/10/2014 6/16/201468 Issue Solicitation & Receive proposals 20 days 6/17/2014 7/14/201469 Evaluation of proposals and prepare award docume 3 days 7/15/2014 7/17/201470 CO finalize documents & make award 2 days 7/18/2014 7/21/201471 Issue Notice To Proceed for Construction Contract 10 days 7/22/2014 8/4/201472 CONSTRUCTION SUPERVISION 363 days 2/17/2014 7/8/201573 Precon Meeting 2 days 8/5/2014 8/6/201474 Contract Period 343 days 2/17/2014 6/10/201575 Construction Period 220 days 8/7/2014 6/10/201576 Control Panels (Indoor GFE) Received 10 days 2/17/2014 2/28/201477 Breakers Received On-Site 20 days 9/16/2014 10/13/201478 Contract Completion Date 0 days 6/10/2015 6/10/201579 Final Payment & Release of Claims 20 days 6/11/2015 7/8/201580 COMMISSIONING 46 days 5/11/2015 7/13/201581 Commissioning Completed 45 days 5/11/2015 7/10/201582 In Service Date 1 day 7/13/2015 7/13/2015

4/2 4/23/19 3/25

3/26 4/1

7/9 7/227/14 7/207/14 7/27

7/28 8/108/11 8/17

6/9 6/9

4/3 4/34/4 5/30

5/31 2/272/28 4/10

5/9 5/9

3/3 3/143/17 3/213/17 4/14

4/15 4/21

2/28 2/282/28 4/102/28 2/28

5/12 5/12

4/2 4/34/4 6/20

7/29 8/29/20 10/4

10/28 11/511/21 11/21

12/16 12/16

4/18 6/136/28 7/1

7/17 7/188/2 8/5

8/20 8/219/6 9/9

9/24 9/25

12/17 12/1712/18 12/18

12/27 12/2712/30 12/30

9/2 9/15

7/19 7/197/22 8/1

8/16 8/168/19 8/23

2/3 2/14

12/17 12/2012/23 12/2312/24 1/14

1/15 2/42/5 2/11

6/10 6/166/17 7/14

7/15 7/177/18 7/217/22 8/4

8/5 8/6

8/7 6/102/17 2/28

9/16 10/136/10

6/11 7/8

5/11 7/107/13 7/13

Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug SepQtr 2, 2012 Qtr 3, 2012 Qtr 4, 2012 Qtr 1, 2013 Qtr 2, 2013 Qtr 3, 2013 Qtr 4, 2013 Qtr 1, 2014 Qtr 2, 2014 Qtr 3, 2014 Qtr 4, 2014 Qtr 1, 2015 Qtr 2, 2015 Qtr 3, 2015

Task

Critical Task

Progress

Milestone

Summary

Rolled Up Task

Rolled Up Critical Task

Rolled Up Milestone

Rolled Up Progress

Split

External Tasks

Project Summary

Group By Summary

Deadline

Facility Study Schedule2009-G1"Ridgeline"

Interconnection to Craig - Ault 345kV Transmission line

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Project: 2009-G1 PROJECT SCHEDUDate: 3/12/2012

FA CILITIES S TUD Y 2009-G1 · The 2009-G1 interconnection request is a proposed 200MW Large...

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Transcript of FA CILITIES S TUD Y 2009-G1 · The 2009-G1 interconnection request is a proposed 200MW Large...