Rocky Mountain Power Transmission Five Year Study Findings Meeting

Rocky Mountain Power Transmission Five Year Study Findings Meeting

Study Areas for 2009 Goshen Idaho Study Area encompasses parts of Bingham, Bonneville, Butte, Clark, Fremont, Jefferson, Lemhi, Madison and Teton Counties Southwest Utah Study Area encompasses parts of Iron and Washington Counties, Utah Utah Valley Study Area encompasses Utah County in the north to Spanish Fork in the South Nebo Study Area encompasses from Spanish Fork to parts of Juab County and Sanpete County, Utah

Goshen, Idaho Study Area Planner Greg Hansen Prepared by: Scott Murdock

Goshen, Idaho Study Blue outlined area is an approximation of the Rocky Mountain Power's Service territory as shown by Power Map. Goshen Substation

Goshen, Idaho Study Urban and agricultural areas: Service to portions of Bingham, Bonneville, Butte, Clark, Fremont, Jefferson, Lemhi, Madison and Teton counties Larger Communities served: Ammon, Rexburg, Rigby, Shelley & Sugar City Largest population center is Idaho Falls City, which has its own municipality

Goshen, Idaho Study Utilities, Municipalities, Rural Electric Associations (REA) in the area: Bonneville Power Administration (BPA) Fall River Electric Association Idaho Falls City Power Idaho Power Lost River Electric Cooperative Lower Valley Electric Rocky Mountain Power (RMP)

Load Growth 2009 Demand Total Area load: summer 755 MVA Growth Rate: 2.6% summer & 2.7% winter Anticipated 2014 Demand Total Area load: 917 MVA

250 MVA of participating Load

Sub-Transmission Substations Goshen, Idaho study has eight operating areas: Amps, Scoville (Antelope), Big Grassy, Bonneville, Goshen, Jefferson, Rigby and Sugarmill

Big Grassy Amps Jefferson Rigby Bonneville Antelope (Scoville) Sugarmill Goshen

N-0 Conditions Idaho Falls Power : 161-12.5 kv, 25MVA transformer at Westside substation. 161-12.5 kv, 25MVA mobile.

N-0 Conditions Problem: Low voltage on the 69 kv bus at Hamer in 2010. Solution: Change source for Hamer by transferring to Jefferson.

N-0 Conditions Problem: Excessive voltage swings at Big Grassy. Transmission path, load swings and phase shifter largely effect voltage. Solution: New cap bank at Big Grassy: 33 Mvar Install 69kV, (3) steps of 11 Mvar each cap bank, In-service spring, 2011 1. Arrangement and controls, similar to Amps Cap Bank 2. Voltage control on Circuit Switchers 3. SCADA on new circuit breaker and circuit switchers. 4. Proper Protection and Control. To Jefferson 3 Ci r* 3 cui Circuit t Br eaker Switchers s Mobile Connection Big Grassy Substation 69 kv To Dillon 161 kv 161-69 kv 3-11 MVAR To Sandune * Review cost of circuit switchers and regular switch. If switch is less can install 2 circuit switches and one switch. S. Murdock, Area Planning S. Smith, Planning Technologies BigGrasseyCapBank.cdr 2/27/2009

N-0 Conditions Problem: Dubois, Hamer, Mud Lake, Ririe, South Fork and Thornton have regulators which will overload. Solution: Upgrade regulators at Dubois (2012), South Fork (2013) and Thornton (2009). Distribution load transfers* mitigate the other substations overloads. *The Mud Lake Transfer (2011) will require distribution circuit upgrades.

N-0 Conditions Problem: Moody (2013), Goshen #7 (2011) and Ucon (2014) transformers will overload. Solution: Distribution load transfers*. *The Moody Transfer will require distribution circuit upgrades.

N-0 Conditions Problem: Rigby-Ucon 69 kv line overloaded in last study year. Solution: Change Ucon source to Goshen. Solution: Ririe 69 kv Tap Line overload in last year Solution: Distribution Load transfers. P A G E - 16

N-1 Conditions Problem: Loss of a 345-161kV transformer at Goshen may result in overload of the remaining transformer up to 107% today, 113% in 2014*. Solution: Third party work at Three Mile Knoll shifts load from Goshen. *This is anticipating the local generation output is average.

N-1 Conditions Problem: Loss of a Rigby 161-69 kv transformer Solution: Using a mobile back-up transformer (located at Goshen substation) corrects the Problem through the study period. Some load (10 MVA to 30 MVA throughout the study period) will be out during the installation of the mobile.

N-1 Conditions Problem: Loss of Goshen-Bonneville 161 kv line overloads the Goshen-Sugarmill 161 kv line. In 2014 this overload is three percent over the emergency rating. Solution: Reconductor the existing line (16.5 miles) with a 400 MVA rated conductor in 2014.

N-1 Conditions Underrated Fault Duty Equipment Problem: Total number is 6 pieces of equipment are underrated for fault duty Solution: Goshen CB 165, Goshen CS167I, Goshen CS169I, Goshen CS 189I, Goshen 199I and the Goshen #7 High side fuses Replace Circuit Switchers, fuses and Breaker during regular maintenance to insure proper fault interrupting. Underrated Switch Problem: Switches at Jeffco: 61A, 63A; Osgood: 1, 3; Rexburg Jct. 67A, 68A; and Ucon 61A, 62A have no capability to break parallel. Solution: Replace switch with air break switch that have loop opening and line dropping attachments.

Construction Schedule 2009 Construction 7-1 Thornton Upgrade regulators to 509 kva units $96,000 2010 Construction - In service by May 1 of this year Replace CB11 & CB12 for maintenance and 7-2 Anderson $111,000 reliability Problems 7-3 Canyon Creek 7Xfr-1T Hamer Replace Transformer high-side fuses. (This will require review of protection to ensure proper coordination) Transfer Hamer from Big Grassy CB 67 to Jefferson CB 65. This is until cap bank is installed at Big Grassy. $9,500 subtotal $216,500 n/a

Construction Schedule 2011 Construction - In service before May 1 of this year 7-4 Big Grassy Install 69 kv, 3 steps of 11 Mvar ea. (33 MVAr total) Approved job May 2009. $1,669,935 7Xfr-2D Goshen #7 Transfer Load to Shelley. n/a 7Xfr-3T Hamer Transfer Hamer to Big Grassy from Jefferson n/a 7D-1 Mud Lake Distribution Transfer from Mud Lake to Anderson. Will require line work. $750,000 7-5 Various Install bottles or replace switches with bottles to improve system operability $640,000 subtotal $3,059,935 2012 Construction - In service before May 1 of this year 7-6 Dubois Replace regulators with 509 kva units to get full capacity from transformer. $100,000 subtotal $125,000

Construction Schedule 2013 Construction - In service before May 1 of this year 7D-2 Moody Transfer distribution load to Newdale (may require distribution line regulators) $80,000 7-7 South Fork Replace regulators with 509 kva units to get full capacity from transformer. $100,000 subtotal $180,000 2014 Construction - In service before May 1 of this year 7-8 Goshen to Reconductor 16.5 miles of 397.5 ACSR with high Sugarmill temperature conductor good for 400 MVA. $6,500,000 7Xfr-4D Hamer Transfer 500 kw to Anderson. Switching only n/a 7Xfr-5T Rigby Move Ucon to Goshen. n/a subtotal $6,500,000 Grand total $10,081,435

Questions?

Prepared by: Seth Riding Area Planner: Nathan Powell

2 1 7 5 8 6 4 Primary Sources Washington Co. 1. 345 kv line from Sigurd to Red Butte 2. 345/138 kv at Red Butte and Central 3. 138/69 kv at Middleton Iron Co. 4. 230 kv line from Sigurd to West Cedar 5. 138 kv line from Cameron to Coleman 6. 230/138 kv at Parowan 7. 230/138 kv at West Cedar 8. 138/69 kv at Coleman 3

Summer 2009 Load: 462 MVA Average Growth Rate: 5.6% (34 MVA per year) Projected Summer 2014 Load: 773 MVA

Coleman Transformer #4 Problem 2013 the area utilization for Coleman and Crosshollow is projected to be over 90%. Solution Replace Transformer #4 with a 40 MVA transformer and replace the 12.5 kv bus with 2000A rated bus. Estimated Cost: $3.25 million

Parowan Coleman Substation Coleman 138 kv breaker Problem An outage on the 138 kv line between Coleman and West Cedar will result in a loss of Crosshollow substation and all four transformers at Coleman. Solution Install a 138 kv breaker where switch 107A is located. Estimated Cost: $400,000 138 kv 69 kv and below West Cedar

Middleton 138 kv breaker Problem An outage to either 138/69 kv transformer results in a loss of both transformers and all 69 kv loads fed from Middleton. Solution Install a 138 kv breaker and 138 kv bus to separate transformers #4 and #5. Estimated Cost: $1.5 million

Middleton to St George 138 kv line Problem An outage on the 138 kv line between Middleton and St George will cause a loss of Middleton substation and approximately 50 MW. Solution Install a second 138 kv line between Middleton and St George with added breaker positions at each substation. Estimated Cost: $3 million

Parowan 230 kv switch 138 kv 230 kv Cameron and Coleman Problem An outage on the 230 kv line between Sigurd and Parowan will cause an outage to West Cedar resulting in the 138 kv voltage between Coleman and Cameron to fall below.95 pu. The 230 kv line from Sigurd to Parowan to West Cedar will be out until repairs are complete. West Cedar Solution Install a 230 kv switch at Parowan on the line to Sigurd. Sigurd Estimated Cost: $200,000

West Cedar 138 kv breaker Problem An outage to the 230/138 kv transformer at West Cedar will result in a loss of the north side of the 138 kv bus and the 138/34.5 kv transformer which feeds the 34.5 kv in Iron County. Solution Install a 138 kv breaker on the low side of the 230/138 kv transformer. Sigurd Estimated Cost: $900,000 34.5 kv 138 kv 230 kv West Cedar Substation Red Butte Parowan Commerce

Three Peaks and Parowan Substations Problem Limited sources to Iron county with low voltage on the 138 kv system in steady-state conditions. To Red Butte Solution Completed 138 kv breaker at Cameron and a 138 kv two stage 30 MVAr capacitor bank at Parowan. Under construction 345/138 kv substation with a 30 MVAr capacitor bank at Three Peaks, a new 138 kv line from WECCO to Three Peaks and a four breaker ring bus at Parowan. This construction to be completed by summer 2010. Estimated Cost: $60 million

To Sigurd To Parowan Red Butte to St. George Rebuild 138 kv line to 345 kv double circuit To Harry Allen Problem The 138 kv lines from Red Butte and Central to St George are the main sources for Washington county. The growth in will require an additional 345 kv source to St George and this is the first phase of the project. Solution Rebuild existing 138 kv line between Red Butte and St George to double circuit 345 kv and initially operate single circuit 138 kv. Construction to be completed in 2010. Estimated Cost: $15.7 million

Windy Ridge Substation To Middleton Problem In 2009 RMP purchased a 69 kv line from Garkane Energy feeding the Twin Cities area. The line will be fed through Hurricane City s Clifton Wilson facility until a new facility is constructed. Solution Build Windy Ridge substation with a 69 kv breaker to feed from the Gateway to Toquerville 69 kv line. Construction to be completed in 2010. Estimated Cost: $2 million

Middleton to Gateway, rebuild 2.2 miles Problem A 2.2 miles section of 4/0 ACSR between Middleton and Gateway is projected to overloaded by summer 2011. Solution The long term plan for this line is to convert to 138 kv. Rebuild this section of line with 1272 ACSR at 138 kv construction. Estimated Cost: $1.2 million

Red Butte to St George Operate double circuit 138 kv Problem The growth in Washington county is causing the existing 138 kv lines to be insufficient in an outage condition. Also the long term plan is to bring 345 kv to St George substation. Solution Finish the 345 kv double circuit line from Red Butte to St George and operate double circuit 138 kv. Projected to be operated 345 kv around 2017 to 2019. Estimated Cost: $2 million

Middleton to Gateway, finish 138 kv conversion Problem The single delivery point at St George substation for Washington county provides a reliability issue for the area. Also, by 2012 Middleton #4 138/69 kv transformer will not be able to support the 69 kv load with an outage to the Middleton #5 138/69 kv transformer. Solution Complete 138 kv conversion of 69 kv line from Middleton to Gateway in 2013 removing part of the 69 kv load fed from Middleton. Connect with proposed 345/138 kv substation in west Hurricane to provide an alternate source to the area. Estimated Cost: $15 million

Projects proposed by Main Grid Planning during the study period. Install an SVC connected to the 345 kv bus at Red Butte in 2011. Estimated cost is $26.5 million Construct second 345 kv line from Sigurd to Red Butte by 2014. Estimated cost is $153 million.

N-0 Project Coleman Install a 40 MVA 138-12.5 kv transformer to replace transformer #4 $ 3,250,000 subtotal $ 3,250,000 N-1 Projects Coleman Install a 138 kv breaker protecting line to West Cedar $ 400,000 Parowan Install a 230 kv switch at Parowan on line to Sigurd $ 200,000 Middleton Install a new 138 kv breaker $ 1,500,000 Middleton Construct a second 138 kv line to St George $ 3,000,000 West Cedar Install a 138 kv breaker on the 230-138 kv transformer #1 $ 900,000 subtotal $ 6,000,000 Projects Under Construction Three Peaks Construct a 345-138 kv substation with 30 MVAr capacitor bank $ 60,000,000 Parowan Install a 138 kv four breaker ring bus (part of Three Peaks) $ 15,700,000 Red Butte - St George Rebuild existing 138 kv line to double circuit 345 kv (operate single circuit 138 kv) Windy Ridge Install a 69 kv breaker station with metering for the line to Twin Cities $ 2,000,000 subtotal $ 77,700,000 SWTTF Identified Projects Middleton - Gateway Rebuild 2.2 miles of 4/0 ACSR at 138 kv with 1272 ACSR $ 1,200,000 Red Butte - St George Operate the 345 kv double circuit line as 138 kv double circuit $ 2,000,000 Middleton - Gateway Finish 138 kv conversion and connect with new Hurricane West substation $ 15,000,000 subtotal $ 18,200,000 Main Grid Identified Projects Red Butte Install a 345 kv SVC $ 26,500,000 Sigurd - Red Butte Install a second 345 kv line from Sigurd to Red Butte $ 153,000,000 subtotal $ 179,500,000 Total $ 284,650,000

Utah Valley Study Prepared by: Tim Reynolds Area Planner: Nathan Powell

Utah Valley Study Utah County in the North Wallsburg Substation to the East Part of Utah Lake to the West Spanish Fork and Benjamin in the South

Utah Valley Study UAMPS Members Encompassed in Area Lehi, Eagle Mountain, Springville, Strawberry ESD, and Payson UMPA Members Encompassed in Area Spanish Fork, Salem, and Provo

Load Growth Base System Loads Summer 2008: 865 MW Growth Average Percentage 4.5% Average growth of 43 MW per year Projected System Loads Summer 2014: 1166 MW

N-0 Conditions Saratoga Transformer Problem In 2011: Saratoga #1 XFMR at 101% Most feeders are projected to be close to or over 100% of their rating Solution: (Approved project) Install a second LTC transformer at Saratoga substation. Estimated cost at $7.6 Million

N-0 Conditions American Fork Transformer Problem In 2012: American Fork #1 XFMR at 98% Utilization for American Fork, Tri-City #1, and Highland #2 will be at 93% By 2014, upon a loss of one of the Hale to Highland or Highland to West Field 138 kv line, the Tri-City to American Fork 138 kv line loads to 93% Solution Install a second 40 MVA LTC transformer at American Fork substation Perform transmission work to utilize a unused 46 kv line to put American Fork on another source. Estimated cost at $8.5 Million

N-0 Conditions West Field Transformer Problem In 2013: West Field #1 XFMR at 101% Transfers are maxed out with existing distribution feeders Solution: Install a second 40 MVA LTC transformer at West Field substation. Estimated cost at $6 Million

N-1 Conditions Vineyard substation Problem In 2013: Under the loss of the 138-46 kv transformer at Hale or the Hale to Willow Ridge 46 kv line Timp to Vinyard Tap line loaded to 100%. Timp 138-46 kv XFMR at 107% Weak 46 kv system prevents looping Sharon (Overloads are only transferred to another line). Solution: Rebuild ~4 miles of 46 kv line to 1272 ACSR at 138 kv construction Convert Vineyard to 138-12.5 kv substation with a LTC, 40 MVAR XFMR Estimated cost at $6 Million

N-1 Conditions Spanish Fork 345-138 kv Transformer & Spanish Fork to Dry Creek 138 kv line Problem In 2014: Estimated that the loss of one 345-138 kv transformer at Spanish Fork will overload the other one after switching to 100% of name plate rating. Loss of the Dry Creek to Spanish Fork 138 kv line overloads the 138-46 kv transformers at Spanish Fork and loss of power to the Nebo Study Area. There are extremely few to no load transfers available to correct this issue Solution: Build a new 345-138 kv substation named Clover in the Nebo Study Area Estimated cost at $44 Million

N-1 Conditions Underrated Fault Duty Equipment Problem Total number is 12 pieces of equipment are underrated for fault duty Solution: Cherrywood CS134I, Hale CB102, Highland CS134I, Orem CS44I, Spanish Fork CS141I, Spanish Fork CS143I, Spanish Fork 139I, Spanish Fork CB46, Spanish Fork CB49, Spanish Fork CB50, Spanish Fork CB51, and Timp CS130I. Replace Transrupters, Circuit Switchers, and Breaker to insure proper fault interrupting Underrated Switch Problem Switch 133A at Wallsbug substation is not rated to loop open or line drop Solution: Replace switch with air break switch that has loop opening and line dropping attachments

Total Construction Costs 2010 Saratoga 2 nd 138-12.5 kv XFMR $7.6 Million 2012 American Fork 2 nd 138-12.5 kv XFMR and Transmission Work $8.5 Million Vineyard Convert to 138-12.5 kv Substation and Transmission Work $6 Million 2013 West Field 2 nd 138-12.5 kv XFMR $6 Million 2014 Build Clover Substation, a 345-138 kv Substation $44 Million Total - $52.1 Million ($28.1 Million without Clover substation)

Questions?

Nebo Utah Study Prepared by: Jeremy Viula Area Planner: Nathan Powell

System Overview 1 4 5 Primary Sources 1. 1-46 kv lines from Spanish Fork 2. 1-138 kv line from Spanish Fork Normally Open / Limited Back-up Sources 1. 3-46 kv lines from Utah Valley 2. 2-46 kv lines from Gunnison 6 2 3 3. 1-46 kv lines from Scipio 4. 1-46 kv lines from Delta

Load Growth Base System Loads Summer 2008: 89 MW Growth Average Percentage 3.7% Average growth of 3 MW per year Projected System Loads Summer 2013: 120 MW

N-0 Conditions Spanish Fork Substation Problem In 2010: Jerusalem 138-kV bus voltage projected to sag to 0.88 p.u. Vickers, Nephi City, Comnet, Levan, Juab, Fayette, Fool Creek, North Field, and Oak City 46-kV bus voltages lower than 0.90 p.u. Solution: Change both Spanish Fork 345-138 kv transformers high side no load tap from 345 to 336.375.

N-0 Conditions North Fields Substation Problem In 2010: Oak City and North Fields substation 46-kV bus voltage projected to sag to 0.89 p.u. Solution: Install 600-kVAR of distribution power factor correction at North Fields substation. (Included in the Vickers increase line capacity project) Estimated cost: $45,000

N-0 Conditions Ockey Substation Problem In 2010: Ockey XFMR at 110% of normal summer rating Solution: Replace the existing Ockey transformer with 500-kVA 46-7.2 kv transformer Estimated cost: $88,800

N-0 Conditions Vickers Substation Problem In 2010 The Nebo-Vickers B 46-kV line is projected to load to 124% normal summer rating with the 46-kV voltages dropping to 0.86 p.u. at Oak City, Fayette, and Nephi City The Vickers-Nephi City 46-kV line will be loaded to 100% normal summer rating) The Vickers 46-12.47 kv transformer is projected to overload to 100% of normal summer rating Solution: Add four 46- kv line circuit breakers at the Vickers substation Connect the Scipio 46-kV line to the Vickers bus by building 1,000 feet of 46-kV line Rebuild the Vickers-Nephi City 46-kV line (1.0 mile) with 795 ACSR conductor Add 600-kVAR of distribution capacitors to the North Fields substation 12.47-kV feeder Install fans on the existing Vickers substation transformer to increase capacity to 2.3 MVA Estimated cost: $4.3 Million

N-0 Conditions Vickers Substation (Continued) Problem In 2013: The Vickers 46-12.47 kv transformer (with fans added in 2010) is projected to overload to 104% of normal summer rating Solution: Replace existing transformer with a surplus 46-12.5 kv 3.75-MVA (or higher) transformer Estimated cost: $300,000

N-0 Conditions Vickers Substation (Continued)

N-0 Conditions North Fields Substation Problem In 2011: North Fields XFMR at 100% normal summer rating Solution: Fit the existing North Fields transformer with fans to increase capacity to 2.3- MVA Estimated cost: $10,000

N-0 Conditions Elberta Substation Problem In 2012: Elberta XFMR at 100% of normal summer rating Solution: Replace Elberta XFMR with a surplus 46-12.5 kv 10- MVA (or higher) transformer Estimated cost: $300,000

N-0 Conditions Rasmusson Substation Problem In 2012: Rasmusson XFMRs at 103% of normal summer rating Solution: Replace T-4510, 4527,4728 with a single surplus 46-12.5 kv 2-MVA (or higher) transformer Estimated cost: $300,000

N-0 Conditions Nebo Substation Problem In 2012: The Jerusalem and Ashgrove 138-kV bus voltage is projected to sag to 0.89 p.u. The Vickers, Soma, Moroni Feed Nephi, Nephi City, Comnet, Levan, Juab, Fayette, Fool Creek, North Field, Canyon Fuel, and Oak City 46 kv buses also experiencing voltages under 0.9 p.u. Solution: Add second step of 12 MVAR to the existing 11- MVAR capacitor bank Estimated cost: $900,000

N-1 Conditions Spanish Fork 345-138 kv Transformer & Spanish Fork to Dry Creek to Nebo 138 kv line Problem Today: Loss of power the Nebo Study Area In 2014: Estimated that the loss of one 345-138 kv transformer at Spanish Fork will overload the other one after switching to 100% of name plate rating. Loss of the Dry Creek to Spanish Fork 138 kv line overloads the 138-46 kv transformers at Spanish Fork and loss of power to the Nebo Study Area. Solution: Build a new 345-138 kv substation named Clover near the Nebo Substation Estimated cost at $44 Million

Total Construction Costs 2010 2011 2012 2013 2014 North Fields Install Distribution Power Factor Correction $45,000 Ockey Replace Transformer $88,800 Vickers Add Four Breakers and Transmission Work $4.2 Million Vickers Install Transformer Fans $10,000 North Fields Install Transformer Fans $10,000 Elberta Replace Transformer $300,000 Rasmusson Replace Transformer $300,000 Nebo Second Step12 MVAR Capacitor Bank $900,000 Vickers Replace Transformer $300,000 Build Clover Substation, a 345-138 kv Substation $44 Million Total - $50.2 Million ($6.2 Million without Clover substation)

Thank You For Your Time Questions?