Small Generator Interconnection System Impact Study Report. Completed for Q0373

Transcription

1 Small Generator Interconnection Completed for Q0373 Proposed Interconnection To the Existing Q kV substation on the 13.8kV side of the bus July 7, 2011

2 TABLE OF CONTENTS 1.0 DESCRIPTION OF THE GENERATING FACILITY SCOPE OF THE STUDY DESCRIPTION OF PROPOSED INTERCONNECTION STUDY ASSUMPTIONS REQUIREMENTS GENERATING FACILITY MODIFICATIONS TRANSMISSION MODIFICATIONS EXISTING BREAKER MODIFICATIONS SHORT-CIRCUIT PROTECTION REQUIREMENTS DATA REQUIREMENTS (RTU) COMMUNICATION REQUIREMENTS For LINE Protection For Data Delivery to the Control Centers SUBSTATION REQUIREMENTS METERING REQUIREMENTS COST ESTIMATE SCHEDULE PARTICIPATION BY AFFECTED SYSTEMS APPENDICES... 8 Q373 Page 1 July 7, 2011

3 1.0 DESCRIPTION OF THE GENERATING FACILITY Interconnection Customer proposed interconnecting 5 MW of new generation to PacifiCorp s ( Transmission Provider ) switch 11L16 (Q0006 Meridian 500kV transmission line) and to the Transmission Providers switch 11L34 (Q0006 Captain Jack 500kV transmission line) through the existing Interconnection Customer Q kV substation on the 13.8kV side of the Q0006 bus. The Project is located in Klamath County, Oregon and will consist of 10 SMA Sunny Central 500HE inverters for a total output of 5 MW. The requested commercial operation date is approximately March 1, The Interconnection Customer will not operate this generator as a Qualified Facility as defined by the Public Utility Regulatory Policies Act of 1978 (PURPA). The Transmission Provider has assigned the project Q SCOPE OF THE STUDY The may consist of a short circuit analysis, a stability analysis, a power flow analysis, voltage drop and flicker studies, protection and set point coordination studies, and grounding reviews, as necessary. These studies were deemed not necessary by the Transmission Provider for the Q0373 interconnection. The System Impact Study shall state the assumptions upon which it is based, state the results of the analyses, and provide the requirement or potential impediments to providing the requested interconnection service, including a preliminary indication of the cost and length of time that would be necessary to correct any problems identified in those analyses and implement the interconnection. The System Impact Study shall provide a list of facilities that are required as a result of the Interconnection Request and non-binding good faith estimates of cost responsibility and time to construct. A stability study will not be performed because the project is less than 10 MWs. 3.0 DESCRIPTION OF PROPOSED INTERCONNECTION The Project s proposed interconnection is located on the Transmission Provider s switch 11L16 (Q0006 Meridian 500kV transmission line) and on the Transmission Providers switch 11L34 (Q0006 Captain Jack 500kV transmission line). Metering and associated communication equipment will need to be installed at the Q0373 generation facility as well as at the 901 and 902 units. Figure 1 is a one-line diagram that illustrates the interconnection of the proposed generation facility to the Transmission Provider s system. Q373 Page 1 July 7, 2011

4 Figure 1: Simplified System One Line Diagram Q373 Page 2 July 7, 2011

5 3.1 STUDY ASSUMPTIONS All active higher priority transmission service and/or generator interconnection requests will be considered in this study and are listed in Appendix 1. If any of these requests are withdrawn, the Transmission Provider reserves the right to restudy this request, as the results and conclusions contained within this study could significantly change. For study purposes there are two separate queues: o Transmission Service Queue: to the extent practical, all network upgrades that are required to accommodate active transmission service requests and are expected to be in-service on or after the Interconnection Customer s requested in-service date for the Project will be modeled in this study. o Generation Interconnection Queue: when relevant, interconnection facilities associated with higher queue interconnection requests will be modeled in this study. However, network upgrades required to provide delivery will only be modeled for projects which have requested network resource integration service only or qualified facility status. No generation will be simulated from any higher queued project unless a commitment has been made to obtain transmission service. The Interconnection Customer s request for interconnection service in and of itself does not convey transmission service. This study assumes the Project will be integrated into Transmission Provider s system at the agreed upon and/or proposed point of interconnection. Unless otherwise specified, the Interconnection Customer will construct and own the any facilities required between the point of interconnection and the Project. Generator tripping may be required for certain outages. All facilities will meet or exceed the minimum WECC, NERC, and Transmission Provider performance and design standards. Q373 Page 3 July 7, 2011

6 4.0 REQUIREMENTS 4.1 GENERATING FACILITY MODIFICATIONS The Interconnection Customer shall design its generating facility to operate reactive compensation, typically located at the collector station, under voltage control mode with the voltage sensed electrically at the point of interconnection, and to have sufficient reactive capacity to enable the facility to deliver 100 percent of the plant output to the point of interconnection at unity power factor measured at 1.0 per unit voltage. The voltage control shall be designed to include a voltage control band, nominally set to 1.01 and 1.04 per unit (actual voltage band may be adjusted depending on typical voltage at the interconnection or other area local conditions), such that if the actual voltage is above the upper band setting, capacitor increments will be automatically removed and if the actual voltage is below the lower band setting, capacitor increments will be automatically be added. The control scheme should be designed so as to avoid hunting when switching between modes (i.e., effectively power factor control inside the band, voltage control outside the band). Inside the voltage bandwidth, the facility shall operate as much as possible to a unity power factor. Settings must be coordinated with the Transmission Provider who may, from time to time, request changes in response to operating conditions or actual operating experience. The reactive compensation must be designed such that the capacitor switching does not cause step voltage changes greater than +/-3% on the Transmission Provider s system. 4.2 TRANSMISSION MODIFICATIONS There are no transmission modifications required for the Q0373 Project. 4.3 EXISTING BREAKER MODIFICATIONS SHORT-CIRCUIT The increase in the fault duty on the system as the result of the addition of the generation facility with photovoltaic arrays fed through ten (10) 500kVA inverters and five 1000kVA 13.8kV 270V transformers with 4% impedance will not push the fault duty above the interrupting rating of any of the existing fault interrupting equipment. 4.4 PROTECTION REQUIREMENTS The existing transmission line protection will continue to response to faults on the Transmission Provider s system. The Interconnection Customer shall install facilities to detect faults and isolate the new facilities from the existing generation facilities at this site. Q373 Page 4 July 7, 2011

7 4.5 DATA REQUIREMENTS (RTU) The Transmission Provider has as a RTU at the Q0006 substation. As part of this project the following quantities will need to be added to that RTU: Analogs: Real power from the PV 13.8kV collector line Reactive power flow from the PV 13.8kV collector line Accumulator Pulses: Interchange metering kwh from the PV 13.8kV collector line Status: 13.8-kV breaker for the PV collector line 4.6 COMMUNICATION REQUIREMENTS For LINE Protection No additional line protection communication is required For Data Delivery to the Control Centers The Transmission Provider will install a Loop 3440A channel bank equipped with digital channel cards at the Q0006 substation. DNP 3.0 protocol outputs from the three new interconnect backup meters will be routed to the channel cards, through fiber-optic modems if necessary. The channels will be bridged to a new digital SCADA comm line in Transmission Provider s Medford Digital Cross-Connect System. The primary meter outputs will be wired to the Transmission Provider s existing GE D20 RTU in the Q0006 substation. The Transmission Provider will install a data concentrator in the Q0373 generation facility. The Transmission Provider will install Multimode fiber-optic cable between the Q0373 generation facility and the existing Q0006 substation. Fiber optic modems will enable the data concentrator to communicate with the Transmission Provider s channel bank in the Q0006 substation. A circuit will be routed to Transmission Provider s EMS system carrying the data concentrator circuit. The Interconnect Customer will provide a dial-up circuit for meter remote interrogation in the generation facility. 4.7 SUBSTATION REQUIREMENTS No addition Transmission Provider substation work was identified for this portion of the project. Q373 Page 5 July 7, 2011

8 4.8 METERING REQUIREMENTS Stand alone revenue metering will be installed at the Q0006 substation on the 13.8kV side of the transformer to measure the net output of the Interconnection Customers Q0373 project. Two revenue grade meters (primary and back-up) will be installed on a panel in the Interconnection Customers control house. The primary and backup meter will be used for SCADA which will include: bi-directional MWH and MVARH quantities, MW, MVAr, and per phase volts and amps. Both meters will provide these quantities to the existing RTU at the Transmission Provider s control house in the 500kV yard via a DNP3.0 signal or ma analog signals and KYZ outputs. The current transformers must be 0.15% metering grade accuracy and be dedicated solely for metering. The voltage transformers will be connected in a WYE configuration. A single land line must be installed for MV90 communications, which can be used for all the meters. Digital or analog output signals from the meter can be provided to the Interconnection Customer, but must be requested before final designs are complete. The existing net metering for the 901 and 902 units is on the high-side of the GSU. With the addition of the Q0373 project on the low side of the GSU, two new metering points will be required to capture the net generation. In addition to the metering required for the Q0373 Project, one meter for the 901 unit and one meter for the 902 unit will also be required. A primary and back-up meter will be installed on a panel for each unit. Each meter will be used for SCADA which will include: bi-directional MWH and MVARH quantities, MW, MVAr, and per phase volts and amps. Both meters will provide these quantities to the new data concentrator and then to the existing RTU at the control house in the 500kV yard via a DNP3.0 signal or ma analog signals and KYZ outputs. MV90 communications will be required for each meter, which will require a dial up land line. Q373 Page 6 July 7, 2011

9 5.0 COST ESTIMATE Costs for all excavation, duct installation and easements shall be borne by the Interconnection Customer and are NOT included in this estimate. This estimate is as accurate as possible given the level of study that has been undertaken to-date and approximates the costs incurred by the Transmission Provider to interconnect this generator to Transmission Provider s electrical transmission system. The Interconnection Customer will be responsible for all actual costs, regardless of the estimated costs communicated to or approved by the Interconnection Customer. A more detailed estimate is calculated during the Facilities Study. Direct Assignment Costs Q0006 substation - Engineering, procurement and installation of communication equipment. $ 64,000 Q0373 Generation Facility - Engineering, procurement and installation of communication equipment. $78,000 Q0006 and Q0373 Generation Facilities - Engineering, procurement and installation of metering equipment. $340,000 Subtotal Direct Assigned $482,000 Network Upgrades Costs Klamath substation Engineering and installation of communication upgrades. $ 15,000 Medford Service Center Engineering and installation of communication upgrades. $ 10,000 Portland Control Center Engineering and installation of communication upgrades. $ 5,000 Subtotal Network Upgrades $ 30,000 Estimated Total Project Costs $ 512, SCHEDULE At this time, it is estimated that the upgrades required to place this project in service could be completed within 12 months of a signed interconnection agreement. Further details regarding the schedule will be available through the Facilities Study when a more detailed estimate has been prepared. Q373 Page 7 July 7, 2011

10 The schedule is driven by the date that the Small Generator Interconnect Agreement is signed. Changes in this date affect the entire schedule. Please note this timeframe does not support the Interconnection Customer s requested in-service date of March 1, PARTICIPATION BY AFFECTED SYSTEMS Transmission Provider has identified the following entities as having affected systems based upon the interconnection of the proposed generation facility. A copy of this report will be shared with the identified Affected Systems: Bonneville Power Administration 8.0 APPENDICES Appendix 1: Higher Priority Requests Q373 Page 8 July 7, 2011

11 APPENDIX 1: HIGHER PRIORITY REQUESTS All active higher priority transmission service and/or generator interconnection requests will be considered in this study and are identified below. If any of these requests are withdrawn, the Transmission Provider reserves the right to restudy this request, as the results and conclusions contained within this study could significantly change. Transmission/Generation Interconnection Queue Requests considered: QUEUE OASIS AREF Completed Request Received Control Area Type of Request POR (TSR) / Location of Interconnection (GI) POD (TSR) Start Date (TSR) / Commercial Operation (GI) MW 1 9/1/2000 West N/A Wallula Substation, 230 kv 6/1/ /31/2001 West N/A Distribution Connect, Near Murder Creek Substation, 12 kv 6/1/ /16/2001 West N/A Roseburg Lumbar Substation, 69 kv /20/2001 West N/A Meridian-Captain Jack Line 500 kv 9/1/ /25/01 West GEN Meridian-Captain Jack 500kV 11/15/ /21/01 West GEN Walla Walla- N.Lewiston 230kV 11/1/ /21/01 West GEN Walla Walla- N.Lewiston 230kV 11/1/ /08/01 West GEN Wallula 230kV 12/21/ /08/01 West N/A Walla Walla Central - Pendleton Line, 69-kV 12/22/ Q373 Page 9 July 7, 2011

12 39 03/09/04 West GEN Tieton 115kV 9/6/ /28/04 West GEN Tieton 115kV 9/6/ /05/05 West GEN 54 04/21/05 West GEN Line 66, Iajkabd- Winchester Segment, 115kV 9/13/ kV Line in Weed, CA 7/1/ /30/05 West GEN /09/05 West NT 68 12/28/05 West NR w/er Santiam- Hazelwood Lyons, OR 11/1/ Hermiston (from BPA) Ponderosa 25 JC Boyle Hydro Plant Sub, 230kV 6/22/ /17/06 West 75 04/21/06 West NR 97 10/16/06 West N/A 99 10/20/06 West N/A Three Mile Road, Boardman Oregon 7/15/ Clearwater Switching Station, 115Kv 3/7/ Near O'Brian Substation, 12.47kV 2/18/ Distribution Feeder 4M100, 20.8kV 2/26/ /07/06 West N/A Substation, 69kV 2/23/ /07/06 West N/A Substation, 69kV 2/23/ S/3.3-W /07/06 West N/A Substation, 69kV 1/7/ /07/06 West N/A Substation, 69kV 2/23/ /07/06 West N/A Substation, 69kV 1/7/ Q373 Page 10 July 7, 2011

13 108 11/28/06 West N/A Rocky Point Feeder near Running Y sub.48kv 8/18/ A 12/12/06 West ER Union Gap- Midway, 230kV 8/15/ B 12/12/06 West ER /17/07 West NT Union Gap- Midway, 230kV 11/1/ PACW (Resource) PACW 01/01/ /16/07 West NR Talbot Switchyard near Dayton, WA 8/1/ /12/07 West N/A Deschutes, OR 5/14/ a 07/02/07 West N/A Substation, 69kV 1/11/ b 07/02/07 West N/A Substation, 69kV 1/11/ /02/07 West N/A Substation, 69kV 1/11/ /02/07 West N/A Substation, 69kV 1/11/ /03/07 West NR w/er /16/07 West ER Wallula - Hatrock, 230kV 10/1/ PAC's 115 kv system on Line 40 from White City to Vilas Road 2/3/ /06/07 West N/A Marion, OR TBD /08/07 West N/A Marion, OR TBD /05/07 West N/A PAC's 20.8 kv Sunset Feeder 4M182 out of Hillview Substation 7/9/ Q373 Page 11 July 7, 2011

14 176 12/26/07 West N/A Linn County, OR 6/17/ /09/08 West NR w/er 500 kv Burns Reactor (Oregon) 12/1/ /09/08 West NR w/er 500 kv Burns Reactor (Oregon) 12/1/ /09/08 West NR w/er 190 1/11/2008 West N/A 193a 1/28/2008 West NR w/er 193b 1/28/2008 West NR w/er 197 2/18/2008 West N/A 500 kv Burns Reactor (Oregon) 12/1/ Chiloquin - Mile Hi 115 KV, Line 61 7/1/2012 PAC's 500 kv Burns Reactor 12/31/ PAC's 500 kv Burns Reactor 12/1/ PAC's 69 kv Arlington Substation 12/1/ /30/08 West NR w/er New Substation on PAC's 230 kv WALA-ENPR line 12/31/ /30/08 West NR w/er New Substation on PAC's 230 kv WALA-ENPR line 12/31/ /23/08 West NR w/er 234 7/1/08 West NR w/er line 5, 69-kV transmission line in Klamath County, OR 10/19/ Walla Wall- Enterprise Line 230 kv 12/31/ Q373 Page 12 July 7, 2011

15 237A 7/31/08 West NR w/er Swift 1 switching station adjacent to Swift 1 12/31/ B 7/31/08 West NR w/er Swift 1 switching station adjacent to Swift 1 12/31/ C 7/31/08 West NR w/er Swift 1 switching station adjacent to Swift 1 12/31/ /12/08 West NR with ER existing 115-kV line between Davis Creek and Mile High substations 10/1/ /14/08 West N/A 69- kv Tumalo Line (Bend-Redmond) south of Deschutes Substation 9/1/ /17/08 N/A West /20/08 N/A West 260 3/3/09 West N/A 261 3/3/09 West N/A Distribution grid along existing Memorial Dr. Fountain Ave kV circuit 5L49 out of Lakeport Substation 3/31/ /6/ Substation, 69 kv 12/30/09 10 Substation, 69 kv 12/30/09 10 Q373 Page 13 July 7, 2011

16 262 3/3/09 West N/A 263 3/3/09 West N/A Substation, 69 kv 12/30/09 10 Substation, 69 kv 12/30/ /29/09 West PTP Walla Walla McNary 01/01/ /11/09 West NR with ER 230- kv Wallula Substation 12/31/ /30/09 West N/A Powerdale Woody Gutherie 69-kV Line 01/25/ /11/09 West PTP Walla Walla McNary 01/01/ /17/09 West N/A 284 8/19/09 West NR with ER Creighton Feeder, 4W8 out of Enterprise Substation 11/01/ kv Lemolo Switchyard 07/21/ /21/09 West N/A 289 9/21/09 West NR with ER 292 9/25/09 West NR/ER /5/09 West N/A 12 kv Yuba Feeder 12/14/ miles past Summer Lake Substation 09/01/ Roseburg Lumber Substation, 69 kv 07/01/ kv Circuit 5P395 05/30/ /13/09 West N/A 12.0 kv Crystal Springs, 5L45 out of Hornet Substation 04/30/ /13/09 West N/A 20.8 kv Aumsville feeder, out of Stayton Substation 08/31/ Q373 Page 14 July 7, 2011

17 /24/2009 West NT BPAT.PACW (BPAP) PACW (Yakama) 8/1/ /27/2010 West NR/ER 319 2/4/2010 West N/A 230 kv breaker ring bus station approx. 5 mi. south of Wallula 230 kv substation 10/1/ Chiloquin - Mile Hi 115 kv, Line 61 7/1/ /26/2010 West N/A /10/2010 West PTP New POR Low side of 12.5kV/277/480V transformer at the end of existing tap line 8/27/ Round Mountain 1/1/ /11/2010 West NT PACW PACW (Load) 12/31/ /2/2010 West NT PACW PACW 1/1/ /15/2010 West NT GSHN PACE TBD /13/2010 West N/A 350 9/8/2010 West N/A 351 9/8/2010 West NR 12.5-kV Circuit, 5P123, out of Killingsworth Substation 12/31/ kv line 32 7/1/ line 18, 69-kV transmission line in Klamath County, OR 3/1/ S/39-W 352 9/15/2010 West N/A Knappa Svensen Substation, kv TBD /23/2010 West PTP Summer Lake Hemingway 6/1/ /23/2010 West PTP Midpoint 500kV Hemingway 6/1/ Q373 Page 15 July 7, 2011

18 353 10/7/2010 West N/A kV Distribution line out of Warrenton Substation 12/18/ /12/2010 West NR/ER West Salem -- Dallas 115 kv transmission line in Polk Co., Oregon 12/1/ S/32.5-W /1/2010 West N/A /3/2010 West N/A /3/2010 West N/A 12.5 kv distribution line out of Cave Junction Substation TBD KV Mint circuit, 4M125, out of Jefferson Substation 7/31/ kv Mint circuit, 4M125, out of Jefferson Substation 7/31/ /4/2010 West N/A kV South circuit, 5K74, out of Hood River Substation TBD /9/2010 West PTP Malin230 Malin500 9/2/ /11/2010 West N/A /15/2010 West N/A /15/2010 West NT BPAT.PACW 34.5-kV Sim/Tag circuit, 4K40, out of Dalreed Substation 11/30/ kV Village Green Substation 7/1/ PACW (Load) 1/1/ Q373 Page 16 July 7, 2011

19 366 12/22/2010 West N/A 20.8-kV Circuit 4U30 out of Southgate Substation 10/1/ /21/2010 West NT PACW /11/2011 West PTP M500 BPAT.PACW (Load) 4/1/ Summer Lake 12/1/ /18/2011 West N/A 20.8-kV Circuit 4U38 out of Cloake Substation 10/1/ /19/2011 West PTP BPAT.PACW CRAG 10/1/ /14/2011 West N/A /25/2011 West NT PACW 34.5-kV Sim/Tag circuit, 4K40, out of Dalreed Substation 11/30/ PACW (Load) 3/31/ /25/2011 West N/A kV Culver circuit, 5D5, out of Madras Solar TBD /28/2011 West ER Existing Q0006 Substation 3/15/ Q373 Page 17 July 7, 2011