HomeMy WebLinkAbout2021-12-10 IMC Agenda and docs
INTERTIE MANAGEMENT COMMITTEE (IMC)
REGULAR MEETING
Friday, December 10, 2021
9:00 am
Alaska Energy Authority Board Room
813 W Northern Lights Blvd, Anchorage, AK 99503
To participate dial 1-888-585-9008 and use code 212-753-619#
1. CALL TO ORDER
2. ROLL CALL FOR COMMITTEE MEMBERS
3. PUBLIC ROLL CALL
4. AGENDA APPROVAL
5. PUBLIC COMMENTS
6. APPROVAL OF PRIOR MINUTES – October 1, 2021
7. NEW BUSINESS
A. 2022 Proposed IMC Meeting Dates
B. FY21 Surplus approval
8. OLD BUSINESS
A. Strategic Plan for Intertie (IOC)
9. COMMITTEE REPORTS
A. OC REPORT / OPERATORS REPORT CEA
B. BUDGET TO ACTUALS Budget Subcommittee
10. COMMITTEE ASSIGMENTS
11. MEMBERS COMMENTS
12. NEXT MEETING DATE – January 28, 2022
13. ADJOURNMENT
IMC MEETING DATES
Proposed 2022
Jan 28, 2022
Mar 25, 2022
May 20, 2022
June 24, 2022
July 29, 2022
Sept 30, 2022
Dec 9, 2022
ALASKA INTERTIE - ACTUAL VS. BUDGET
Estimated FY21 Surplus (to be refunded) $188,154.94
Actual Revenues 635,106.35 More than budgeted
Actual Expenses 109,887.87 Less than budgeted
Budgeted Shortage (556,839.28)
188,154.94
Revenues:
Total revenues increased in FY21
FY20 Revenue $2.52 million*357,240$ capacity charge 146,557 mwhs @ 9.64 rate
FY21 Revenue $2.81 million*330,720$ capacity charge 196,640 mwhs @ 8.92 rate
* includes investment interest
Expenditures:
Total expenses increased in FY21
FY20 YTD Expenses $963,027
FY21 YTD Expenses $2,617,497
Total Expense Budget for FY21 is:2,727,385$
Report on variances of any budget line item greater than 5% of total expense ($136,369)
and if the variance exceeds 15% of the budgeted line item
Expenses (over) under
FY21 expenses were less than budgeted by $109,888
(over) under
FERC 562 Station Operation Expenses (1,382)$
FERC 566 Miscellaneous Transmission Expenses 226,201
FERC 567 Transmission Expenses - Rent -
FERC 569 Maintenance of Structures -
FERC 570 Maintenance of Station Equipment (154,943)
FERC 571 Maintenance of Overhead Lines 146,083
FERC 920 AEA Administrative Costs (120,409)
FERC 920 IMC Administrative Costs 9,110
FERC 924 Property Insurance 5,228
109,888$
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2021 Alaska Intertie Annual True-Up Calculation
Total Refund Due To the Participants:$188,154.94
Intertie Operating Costs Surplus Calculation
Total Operating Revenues-Usage Charges 1,754,028.80$
Total Operating Revenues-Capacity Charges 330,720.00$
Total Investment Interest 273.74$
Total Capital Credits 629.53$
Total Operating Costs (1,963,399.00)$
Intertie Operating Costs Surplus 122,253.07$ -
Intertie Cost of Improvements Shortage Calculation
Total Revenues - Cost of Improvements -$
Total Cost of Improvements -
Intertie Cost of Improvements Surplus/(Shortage)-$ -
Intertie Administrative Costs Surplus Calculation
Total Administrative Revenues 720,000.00$
Total Administrative Costs (654,098.13)$
Intertie Administrative Costs Surplus 65,901.87$ -
Total Refund Due to the Participants 188,154.94$
ALLOCATION OF SURPLUS(SHORTAGE) - PER INTERTIE AGREEMENT SECTIONS 7.4.4 & 7.4.5
Alaska Intertie Agreement - 3/11/2014
7.4.4 Excess Revenues: The IMC shall determine Excess Revenues for Intertie Operating Costs independent from Intertie Administrative Costs.
7.4.5 Revenue Deficiencies: The IMC shall determine Revenue Deficiencies for Intertie Operating Costs independent from Intertie Administrative Costs.
Intertie Operating Costs: Excess Revenues Allocation Calculation
Energy Usage Operating Refund
Participant Paid %Due to
GVEA 1,557,628.24$ 88.80%108,560.73$
ML&P - 0.00%-$
CEA - 0.00%-$
MEA 196,400.56$ 11.20%13,692.34$
Total FY21 Energy Charges 1,754,028.80$ 100.00%122,253.07$
See Alaska Intertie Agreement Section 7.4.4.1
Intertie Cost of Improvements: Revenue Deficiency Allocation Calculation
Cost of Improvements Cost of Improvements
Participant Contribution %Refund Due from
GVEA -$ 25.00%-$
ML&P -$ 25.00%-$
CEA -$ 25.00%-$
MEA -$ 25.00%-$
Total FY21 Cost of Improvements Contribution -$ 100.00%-$
See Alaska Intertie Agreement Section 6.4.3
Intertie Administrative Costs: Excess Revenue Allocation Calculation
Administrative Administrative
Participant Contribution %Refund Due to
GVEA 220,000.00$ 30.56%20,139.61$
ML&P 60,000.00$ 8.32%5,483.04$
CEA 220,000.00$ 30.56%20,139.61$
Total to CEA 280,000.00$ 38.88%25,622.65$
MEA 220,000.00$ 30.56%20,139.61$
Total FY21 Administrative Contribution 720,000.00$ 100.00%65,901.87$
See Alaska Intertie Agreement Section 7.4.5.2
Alaska Intertie Allocation of Surplus
Total Refund Due to (from) the Participants:
Operating Usage Administrative Cost of Improvements Total Refund Due
Participant Refund Due to Refund Due to Refund Due from to Participant
GVEA 108,560.73$ 20,139.61$ -$ 128,700.34$
ML&P - 5,483.04$ -$ 5,483.04$
CEA - 20,139.61$ -$ 20,139.61$
Total Refund to CEA - 25,622.65 -$ 25,622.65$
MEA 13,692.34$ 20,139.61$ -$ 33,831.95$
Total Refund Due As Per FY21 Annual True Up:188,154.94$
7.4.4.1 –Should the annual revenues received from all sources for the Intertie Operating Costs under Section 7.4.1, Participant and User Payments, exceed
actual annual Intertie Operating Costs, the revenues in excess of the Intertie Operating Costs shall be allocated to the cont ributing Participants and Users in
proportion to the total dollar amount paid by all parties for the use of the Intertie in the fiscal year, or portion thereof,in which the revenues were accrued.
7.4.5.2 –Should the revenues received under Section 7.4.1 Participant and User Payments, be less than the actual Intertie Admin istrative Costs incurred, the revenue
deficiency shall be allocated between the Participants and Users in the same proportional manner as revenues are re-allocated between the Participants and Users
under Section 7.4.4.2.
7.4.5.3. –The IMC shall authorize AEA to bill the Participants and Users their proportionate share of any deficiency determined under this Section 7.4.5. Revenue
Deficiencies.
6.4.3 –The cost of Improvements may be apportioned among the requesting Participants and Users pursuant to a written agreement and may be adjusted to include
other sources of funding.
For FY18 Costs of Improvements see the "Utility Memorandum of Agreement for 2016 Douglas Substation Improvement" and the "Fir st Amendment to the Utility
Memorandum of Agreement for 2016 Douglas Substation Improvement".
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ALASKA INTERTIE REVENUE VARIANCE REPORT FY21
MWH ACTUAL USAGE Jul-20 Aug-20 Sep-20 Oct-20 Nov-20 Dec-20 Jan-21 Feb-21 Mar-21 Apr-21 May-21 Jun-21 TOTAL
MWH MWH MWH MWH MWH MWH MWH MWH MWH MWH MWH MWH MWH
GVEA 2,248 7,617 12,672 14,089 14,115 14,530 16,895 23,148 14,870 29,470 17,993 6,975 174,622
CURRENT VARIANCE (3,752) (383) 5,672 4,089 6,115 5,530 6,895 13,148 8,870 17,470 7,993 975 72,622
YTD VARIANCE (3,752) (4,135) 1,537 5,626 11,741 17,271 24,166 37,314 46,184 63,654 71,647 72,622
MLP - - - - - - - - - - - - -
CURRENT VARIANCE - - - - - - - - - - - - -
YTD VARIANCE - - - - - - - - - - - -
CEA - - - - - - - - - - - -
CURRENT VARIANCE - - - - - - - - - - - - -
YTD VARIANCE - - - - - - - - - - - -
MEA 786 1,628 1,651 1,817 2,065 2,154 2,197 2,082 2,210 1,855 1,821 1,752 22,018
CURRENT VARIANCE (1,321) (376) (233) 106 350 114 (257) 74 355 105 (190) (250) (1,523)
YTD VARIANCE (1,321) (1,697) (1,930) (1,824) (1,474) (1,360) (1,617) (1,543) (1,188) (1,083) (1,273) (1,523)
TOTAL 3,034 9,245 14,323 15,906 16,180 16,684 19,092 25,230 17,080 31,325 19,814 8,727 196,640
CURRENT VARIANCE (5,073) (759) 5,439 4,195 6,465 5,644 6,638 13,222 9,225 17,575 7,803 725 71,099
YTD VARIANCE (5,073) (5,832) (393) 3,802 10,267 15,911 22,549 35,771 44,996 62,571 70,374 71,099
ACTUAL REVENUES
Jul-20 Aug-20 Sep-20 Oct-20 Nov-20 Dec-20 Jan-21 Feb-21 Mar-21 Apr-21 May-21 Jun-21 TOTAL
Rate per MWH 8.92$ 8.92$ 8.92$ 8.92$ 8.92$ 8.92$ 8.92$ 8.92$ 8.92$ 8.92$ 8.92$ 8.92$
GVEA Energy Charges 20,052$ 67,944$ 113,034$ 125,674$ 125,906$ 129,608$ 150,703$ 206,480$ 132,640$ 262,872$ 160,498$ 62,217$ 1,557,628
GVEA Administrative Charges 15,000$ 15,000$ 15,000$ 15,000$ 20,000$ 20,000$ 20,000$ 20,000$ 20,000$ 20,000$ 20,000$ 20,000$ 220,000
GVEA Cost of Improvements -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -
GVEA Capacity Charges 165,360$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ 165,360
YTD Actuals 200,412$ 283,356$ 411,390$ 552,064$ 697,970$ 847,577$ 1,018,281$ 1,244,761$ 1,397,401$ 1,680,274$ 1,860,771$ 1,942,988$ 1,942,988
YTD Variance (33,468)$ (36,884)$ 13,710$ 50,184$ 109,730$ 164,057$ 230,561$ 352,841$ 436,961$ 597,794$ 674,091$ 687,788$
MLP Energy Charges -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -
MLP Administrative Charges 15,000$ 15,000$ 15,000$ 15,000$ -$ -$ -$ -$ -$ -$ -$ -$ 60,000
MLP Cost of Improvements -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -
MLP Capacity Charges 51,217$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ 51,217
YTD Actuals 66,217$ 81,217$ 96,217$ 111,217$ 111,217$ 111,217$ 111,217$ 111,217$ 111,217$ 111,217$ 111,217$ 111,217$ 111,217
YTD Variance -$ -$ -$ -$ (15,000)$ (30,000)$ (45,000)$ (60,000)$ (75,000)$ (90,000)$ (105,000)$ (120,000)$
CEA Energy Charges -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -
CEA Administrative Charges 15,000$ 15,000$ 15,000$ 15,000$ 20,000$ 20,000$ 20,000$ 20,000$ 20,000$ 20,000$ 20,000$ 20,000$ 220,000
CEA Cost of Improvements -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -
CEA Capacity Charges 70,065$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ 70,065
YTD Actuals 85,065$ 100,065$ 115,065$ 130,065$ 150,065$ 170,065$ 190,065$ 210,065$ 230,065$ 250,065$ 270,065$ 290,065$ 290,065
YTD Variance -$ -$ -$ -$ 5,000$ 10,000$ 15,000$ 20,000$ 25,000$ 30,000$ 35,000$ 40,000$
MEA Energy Charges 7,011$ 14,522$ 14,727$ 16,208$ 18,420$ 19,214$ 19,597$ 18,571$ 19,713$ 16,547$ 16,243$ 15,628$ 196,401
MEA Administrative Charges 15,000$ 15,000$ 15,000$ 15,000$ 20,000$ 20,000$ 20,000$ 20,000$ 20,000$ 20,000$ 20,000$ 20,000$ 220,000
MEA Cost of Improvements -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -
MEA Capacity Charges 44,078$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ 44,078
YTD Actuals 66,089$ 95,611$ 125,338$ 156,545$ 194,965$ 234,179$ 273,776$ 312,348$ 352,061$ 388,607$ 424,851$ 460,479$ 460,479
YTD Variance (11,783)$ (15,137)$ (17,216)$ (16,270)$ (8,148)$ (2,131)$ 576$ 6,236$ 14,403$ 20,340$ 23,645$ 26,415$
TOTAL ENERGY CHARGES 27,063$ 82,465$ 127,761$ 141,882$ 144,326$ 148,821$ 170,301$ 225,052$ 152,354$ 279,419$ 176,741$ 77,845$ 1,754,029
TOTAL ADMINISTRATIVE CHARGES 60,000$ 60,000$ 60,000$ 60,000$ 60,000$ 60,000$ 60,000$ 60,000$ 60,000$ 60,000$ 60,000$ 60,000$ 720,000
TOTAL COST OF IMPROVEMENTS -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -
TOTAL CAPACITY CHARGES 330,720$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ 330,720
YTD TOTAL REVENUES 417,783$ 560,249$ 748,010$ 949,891$ 1,154,217$ 1,363,038$ 1,593,339$ 1,878,390$ 2,090,744$ 2,430,163$ 2,666,904$ 2,804,749$ 2,804,749
YTD TOTAL VARIANCE (45,251)$ (52,021)$ (3,506)$ 33,914$ 91,582$ 141,926$ 201,137$ 319,077$ 401,364$ 558,133$ 627,736$ 634,203$
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ALASKA INTERTIE REVENUE VARIANCE REPORT FY21
MWH PROJECTIONS Jul-20 Aug-20 Sep-20 Oct-20 Nov-20 Dec-20 Jan-21 Feb-21 Mar-21 Apr-21 May-21 Jun-21 TOTAL
MWH MWH MWH MWH MWH MWH MWH MWH MWH MWH MWH MWH MWH
GVEA 6,000 8,000 7,000 10,000 8,000 9,000 10,000 10,000 6,000 12,000 10,000 6,000 102,000
YTD 6,000 14,000 21,000 31,000 39,000 48,000 58,000 68,000 74,000 86,000 96,000 102,000
MLP - - - - - - - - - - - - -
YTD - - - - - - - - - - - -
CEA - - - - - - - - - - - - -
YTD - - - - - - - - - - - -
MEA 2,107 2,004 1,884 1,711 1,715 2,040 2,454 2,008 1,855 1,750 2,011 2,002 23,541
YTD 2,107 4,111 5,995 7,706 9,421 11,461 13,915 15,923 17,778 19,528 21,539 23,541
TOTAL 8,107 10,004 8,884 11,711 9,715 11,040 12,454 12,008 7,855 13,750 12,011 8,002 125,541
YTD 8,107 18,111 26,995 38,706 48,421 59,461 71,915 83,923 91,778 105,528 117,539 125,541
BUDGETED REVENUES
Jul-20 Aug-20 Sep-20 Oct-20 Nov-20 Dec-20 Jan-21 Feb-21 Mar-21 Apr-21 May-21 Jun-21 TOTAL
Budgeted Rate per MWH 8.92$ 8.92$ 8.92$ 8.92$ 8.92$ 8.92$ 8.92$ 8.92$ 8.92$ 8.92$ 8.92$ 8.92$
GVEA Energy Charges 53,520$ 71,360$ 62,440$ 89,200$ 71,360$ 80,280$ 89,200$ 89,200$ 53,520$ 107,040$ 89,200$ 53,520$ 909,840
GVEA Administrative Charges 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 180,000
GVEA Cost of Improvements -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -
GVEA Capacity Charges 165,360$ 165,360
YTD 233,880$ 320,240$ 397,680$ 501,880$ 588,240$ 683,520$ 787,720$ 891,920$ 960,440$ 1,082,480$ 1,186,680$ 1,255,200$ 1,255,200
MLP Energy Charges -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -
MLP Administrative Charges 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 180,000
MLP Cost of Improvements -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -
MLP Capacity Charges 51,217$ 51,217
YTD 66,217$ 81,217$ 96,217$ 111,217$ 126,217$ 141,217$ 156,217$ 171,217$ 186,217$ 201,217$ 216,217$ 231,217$ 231,217
CEA Energy Charges -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -
CEA Administrative Charges 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 180,000
CEA Cost of Improvements -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -
CEA Capacity Charges 70,065$ 70,065
YTD 85,065$ 100,065$ 115,065$ 130,065$ 145,065$ 160,065$ 175,065$ 190,065$ 205,065$ 220,065$ 235,065$ 250,065$ 250,065
MEA Energy Charges 18,794$ 17,876$ 16,805$ 15,262$ 15,298$ 18,197$ 21,890$ 17,911$ 16,547$ 15,610$ 17,938$ 17,858$ 209,986
MEA Administrative Charges 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 15,000$ 180,000
MEA Cost of Improvements -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -
MEA Capacity Charges 44,078$ 44,078
YTD 77,872$ 110,748$ 142,553$ 172,816$ 203,113$ 236,310$ 273,200$ 306,111$ 337,658$ 368,268$ 401,206$ 434,064$ 434,064
TOTAL ENERGY CHARGES 72,314$ 89,236$ 79,245$ 104,462$ 86,658$ 98,477$ 111,090$ 107,111$ 70,067$ 122,650$ 107,138$ 71,378$ 1,119,826
TOTAL ADMINISTRATIVE CHARGES 60,000$ 60,000$ 60,000$ 60,000$ 60,000$ 60,000$ 60,000$ 60,000$ 60,000$ 60,000$ 60,000$ 60,000$ 720,000
TOTAL COST OF IMPROVEMENTS -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -
TOTAL CAPACITY CHARGES 330,720$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ 330,720
YTD 463,034$ 612,270$ 751,515$ 915,978$ 1,062,635$ 1,221,112$ 1,392,202$ 1,559,313$ 1,689,380$ 1,872,030$ 2,039,168$ 2,170,546$ 2,170,546
634,203
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Effective 7/1/20 YTD Actuals as a OVER
Approved % of Total (UNDER)
FY21 Budget YTD Budget YTD Actuals Annual Budget YTD Variance
REVENUES
GVEA 1,255,200 1,255,200 1,942,988 154.8%687,788
ML&P 231,217 231,217 111,217 48.1%(120,000)
CEA 250,065 250,065 290,065 116.0%40,000
MEA 434,064 434,064 460,479 106.1%26,414
INTEREST / CAPITAL CREDITS 903 0.0%903
TOTAL REVENUES 2,170,546 2,170,546 2,805,652 129.3%635,106
EXPENSES
FERC 562 - Station Operation Expenses
GVEA - Substation Electricity Usage 8,000 8,000 9,382 117.3%1,382
8,000 8,000 9,382 117.3%1,382
FERC 566 - Miscellaneous Transmission Expense
Private Line Telephone Service for AKI SCADA (GVEA)50,000 50,000 5,556 11.1%(44,444)
Cell Phone Comm. Svc for Weather Monitoring (Verizon)15,000 15,000 11,904 79.4%(3,096)
SLMS Support and Intertie Ground Patrol 100,000 100,000 98,540 98.5%(1,460)
165,000 165,000 115,999 70.3%(49,001)
FERC 567 - Transmission Expenses - Rents
Rents - Alaska Railroad 700 700 700 100.0%-
MEA - Talkeetna Storage 7,200 7,200 7,200 100.0%-
7,900 7,900 7,900 100.0%-
FERC 570 - Maintenance of Station Equipment
GVEA - Healy, Cantwell, Goldhill 65,000 65,000 154,917 238.3%89,917
GVEA - SCADA Maintenance Healy, Cantwell, Gold Hill 5,000 5,000 - 0.0%(5,000)
GVEA - Perform Maintenance, repaint Reactors Healy SVC Yard 10,000 10,000 145,494 1454.9%135,494
GVEA - Cantwell Standby Generator Replacement 75,000 75,000 29,016 38.7%(45,984)
CEA - Teeland Substation 90,000 90,000 183,401 203.8%93,401
MEA - Douglas Substation 4,000 4,000 26,115 652.9%22,115
MEA - Douglas Substation 138 kV Bus Repair & BKR Inspections 75,000 75,000 - 0.0%(75,000)
GVEA - Douglas Substation OOS relaying and communications 50,000 50,000 - 0.0%(50,000)
CEA - Telecomm Support (Douglas Substation Communications)10,000 10,000 - 0.0%(10,000)
384,000 384,000 538,943 140.3%154,943
FERC 571 - Maintenance of Overhead Lines
GVEA - Northern Maintenance 130,000 130,000 68,204 52.5%(61,796)
GVEA - Northern ROW Clearing 130,000 130,000 36,721 28.2%(93,279)
MEA - Special Patrols [Incl Helicopter Inspections]3,000 3,000 - 0.0%(3,000)
MEA - Southern Maint (Incl Ground and Climbing Inspect)160,485 160,485 138,199 86.1%(22,286)
MEA - Southern ROW Clearing 125,000 125,000 228,413 182.7%103,413
MEA - Equipment Repair and Replacement 850,000 850,000 780,866 91.9%(69,134)
1,398,485 1,398,485 1,252,403 89.6%(146,082)
FERC 924 - Property Insurance
AK Intertie - Insurance 44,000 44,000 38,773 88.1%(5,227)
44,000 44,000 38,773 88.1%(5,227)
Intertie Operating Costs Total 2,007,385 2,007,385 1,963,399 97.8%(43,986)
FERC 920 - AEA Administrative Costs
Personal Services, Travel and Other Costs 90,000 90,000 210,409 233.8%120,409
90,000 90,000 210,409 233.8%120,409
FERC 920 - IMC Administrative Costs
IMC Administrative Costs (Audit, meetings, legal)40,000 40,000 30,890 77.2%(9,110)
40,000 40,000 30,890 77.2%(9,110)
FERC 566 - Miscellaneous Transmission Expense
Misc. System Studies 290,000 290,000 186,675 64.4%(103,325)
LIDAR Survey 300,000 300,000 226,125 75.4%(73,875)
590,000 590,000 412,800 70.0%(177,200)
Intertie Administration Costs Total 720,000 720,000 654,098 90.8%(65,902)
TOTAL EXPENSE 2,727,385 2,727,385 2,617,497 96.0%(109,888)
SURPLUS (SHORTAGE)(556,839) (556,839) 188,155 -33.8%744,994
Alaska Intertie FY21 Budget to Actuals Status Report for the Period July 1, 2020 through June 30, 2021
11/10/2021 1 of 2
Alaska Intertie FY21 Budget to Actuals Status Report for the Period July 1, 2020 through June 30, 2021
Budgeted Usage Actual Usage to Date
GVEA MEA CEA ML&P TOTAL GVEA MEA CEA ML&P TOTAL
MONTH MWH MWH MWH MWH MWH MONTH MWH MWH MWH MWH MWH
Jul 6,000 2,107 - - 8,107 Jul 2,248 786 - - 3,034
Aug 8,000 2,004 - - 10,004 - Aug 7,617 1,628 - - 9,245
Sep 7,000 1,884 - - 8,884 Sep 12,672 1,651 - - 14,323
Oct 10,000 1,711 - - 11,711 Oct 14,089 1,817 - - 15,906
Nov 8,000 1,715 - - 9,715 Nov 14,115 2,065 - - 16,180
Dec 9,000 2,040 - - 11,040 Dec 14,530 2,154 - - 16,684
Jan 10,000 2,454 - - 12,454 Jan 16,895 2,197 - - 19,092
Feb 10,000 2,008 - - 12,008 Feb 23,148 2,082 - - 25,230
Mar 6,000 1,855 - - 7,855 Mar 14,870 2,210 - - 17,080
Apr 12,000 1,750 - - 13,750 Apr 29,470 1,855 - - 31,325
May 10,000 2,011 - - 12,011 May 17,993 1,821 - - 19,814
Jun 6,000 2,002 - - 8,002 Jun 6,975 1,752 - - 8,727
- -
TOTAL 102,000 23,541 - - 125,541 TOTAL 174,622 22,018 - - 196,640
INTERTIE PROJECTED ENERGY USAGE TO DATE (MWH)125,541 INTERTIE ACTUAL ENERGY USAGE TO DATE (MWH) 196,640
Budgeted Operating Costs for the period 2,007,385$ Actual Operating Costs for the period 1,963,399$
(based on amended budget)
Budgeted Usage Revenue for the period 1,119,826$ Actual (Billed) Usage Revenue for the period 1,754,029$
(budgeted rate x projected usage)(budgeted rate x actual usage)
Estimated Budgeted Energy Rate per MWH 13.35$
(based on to date budgeted costs and usage)
Annual Budgeted Energy Rate (Billed Rate)8.92$ Projected Actual Energy Rate per MWH 8.34$
(based on minimum contract value)(based on to date actual costs and usage)
11/10/2021 2 of 2
Alaska Intertie Asset Management Plan- draft
(Also referred to in the 10/1/21 IMC meeting as: Preventive Maintenance Plan, Predictive
Maintenance Plan, Holistic Asset Plan, Long-term Capital Improvement Plan, Strategic Plan)
Asset Management Plan Outline
• Purpose
• Background
• Current asset condition
• History of AK Intertie maintenance and repair
• Asset management decision making
o Preventative maintenance plan
o Life cycle costs
o Repair and maintenance budget cash flow and financing
o Capital project funding to improve overall transfer capability on the Intertie
Infrastructure Investment and Jobs Act opportunities
o Site control
Land lease
Right of Way
• Asset management software
o Geographic Information System Mapping (GIS)
o Equipment and materials database
• Major factors impacting future use:
o Economy energy and/or firm energy opportunities/transactions
o Power flow and stability studies
o Load changes
o Reserve sharing opportunities
o System upgrades (increase Intertie operating voltage for example)
System stability improvements
Reduce losses
o Healy #1 refurbishment/decommissioning plans
o Healy #2 refurbishment/decommissioning plans
o N-1 contingencies affecting the Intertie
230kV line between Pt. MacKenzie and Teeland
Additional projects underway
• O’Neill tap path to McRae potential impacts
o Generation fuel sources
Price
Availability
RPS or carbon reduction plans
o Climate change
Melting permafrost
Erosion
Wildfire
• Conclusions and recommendations
Alaska Intertie Asset Management Plan- draft
(Also referred to in the 10/1/21 IMC meeting as: Preventive Maintenance Plan, Predictive
Maintenance Plan, Holistic Asset Plan, Long-term Capital Improvement Plan, Strategic Plan)
• Appendices
o Preventive maintenance plan
o LIDAR study results and recommendations
o Vegetation management plan
o GE SVC inspection reports and recommendations
AK Intertie condition reports
Structures and foundations
Transformers
Conductors
Switchgear
Lightning protection (static lines, arrestors, etc.)
Intertie SVC’s
Access roads
Intertie Management Committee Meeting
Intertie Operating Committee Report
December 10, 2021
1. Intertie Operating Committee (IOC)
a. The IOC last met on December 3, 2021.
i. IMC assignments
1. Develop an Intertie Asset Management Plan
2. Provide the magnitude of system oscillations occurring during the
June 3, 2021 system disturbance – See Attached Report.
ii. AEA and GVEA finalizing a draft proposal for transferring Cantwell Substation
assets from AEA to GVEA.
iii. Motion passed unanimously to move the Marker Ball Project to the FY 23
budget.
iv. Recommended a Lidar presentation be provided to the IMC.
b. Subcommittee updates
i. Dispatch and Systems Operations Subcommittee
1. Developing a Railbelt system wide process to return the grid
Balancing Areas AGC’s back to Tie Line Bias after a disturbance –
Ongoing.
ii. Engineering, Relaying and Reliability Subcommittee has been requested to
install out of step relaying protection at Douglas – Ongoing.
iii. Machine Ratings Subcommittee
1. Review and update Railbelt generation resource ratings data
including a recommendation for an application for accessing and
maintaining the data - Revised assignment.
iv. SCADA and Telecommunications Subcommittee
1. Developing a final scope of work for the Douglas communication
project – Ongoing.
2. Determine requirements to upgrade communication between
Douglas and Healy Substations - Ongoing
v. Operations, Maintenance and Scheduling Subcommittee
1. Reviewing Intertie Vegetation Management plan developed by
GVEA and MEA including delivery date. – Ongoing
2. Develop an Intertie preventative maintenance plan including delivery
date – New assignment.
3. Review the type of lightning arrestors used on the Intertie, evaluate
lifecycle and condition, and make a recommendation for
replacement as required – New assignment.
4. Review the Lidar survey final report with GVEA (project manager) to
identify and develop mitigation plan as required.
vi. Budget subcommittee
1. Remove the Marker Ball Project from the FY 22 Budget and have a
placeholder to include in the FY 23 Budget - New assignment
vii. System Studies Subcommittee
1. Reserves Study.
2. Oscillation Study
viii. Utility updates – Oscillation study
1. GVEA - Completed its tuning of Healy 1 and 2. GVEA has not disabled
the BESS Power System Stabilizer (PSS) as recommended in the PTI
study in order to maintain existing contingency reserves response.
2. HEA – In process of completing a voltage control study before PSS
tuning commences.
3. Chugach – Has not budgeted for Beluga PSS tuning. Units rarely in
operation.
2. Intertie Trip October 26, 2021 at 3:53 PM
a. Outage information will be provided during meeting
PART 2: EVENT SUMMARY
11/17/2021
TO01/01/2021 12/31/2021
IOC ANNUAL RELIABILITY REPORT
Event
Num
Date/Time Duration Description Freq
extreme
Intertie Kenai
opened opened
Unit Line
Trip Trip
BESS Silos Load
Shed
Comments
1,121 01/12/2021 06:24:07 SPP Unit 13 trip during switching. 59.62 X 0.0 0.0 7.30.3
1,122 02/17/2021 03:32:59 HLP ST1 Trip 59.90 X 0.0 0.0 0.01.9
1,123 02/25/2021 16:07:38 SPP Unit 13 Ramp and Trip due to
node fault.
59.79 X 0.0 0.0 10.30.1
1,124 02/24/2021 05:35:07 HLP ST2 Trip 59.68 X 0.0 0.0 17.10.4
1,125 02/28/2021 12:16:12 HLP ST1 Trip 59.88 X 0.0 0.0 0.00.7
1,126 03/15/2021 20:36:21 HLP ST2 Trip 59.72 X 0.0 0.0 17.50.9
1,127 03/24/2021 13:06:14 NPC Trip (caused by NIS-NPC
138kV Line Tripping)
59.19 X 0.0 0.0 0.03.6
1,128 03/24/2021 13:36:38 HLP ST2 Trip 59.50 X 0.0 0.0 0.01.2
1,129 03/27/2021 14:33:41 HLP ST2 Trip 59.68 X 0.0 0.0 0.00.5
1,130 03/29/2021 07:40:24 BCT Unit 4 trip 59.74 X 0.0 0.0 0.06.6
1,131 04/26/2021 17:20:29 138 kV CSS to GHS Trip 60.19 X 0.0 23.3 0.02.1
1,132 04/28/2021 10:16:29 HLP ST1 Trip 59.82 X 0.0 0.0 0.01.7
1,133 05/02/2021 12:20:00 HLP ST1 Trip 59.83 X 0.0 0.0 0.07.7
1,134 05/03/2021 16:08:30 HLP ST1 Trip 59.77 X 0.0 0.0 12.10.6
1,135 05/04/2021 04:31:24 HLP ST2 Trip 59.69 X 0.0 0.0 0.00.8
1,136 05/18/2021 07:35:12 FKS jogs ball mill 59.79 X 0.0 0.0 0.00.5
1,137 05/18/2021 14:03:33 69kV FWS-HPS Trip 60.19 X 0.0 6.9 17.53.0
1,138 06/20/2021 06:28:07 NPC Trip 59.43 X 0.0 0.0 0.05.3
1,139 06/20/2021 12:50:04 NPC GT3 Trip 59.62 X 0.0 0.0 0.01.0
1,140 06/21/2021 09:49:39 GHS B10 Trip (raven) 60.23 X 0.0 19.5 0.02.8
1,141 06/24/2021 14:43:41 Nikkels 4 Trip (load rejection test) 59.53 X 0.0 0.0 0.00.4
*has sub event
Event
Num
Date/Time Duration Description Freq
extreme
Intertie Kenai
opened opened
Unit Line
Trip Trip
BESS Silos Load
Shed
Comments
1,142 06/24/2021 15:06:48 Nikkels 4 Trip (load rejection test) 59.66 X 0.0 0.0 0.00.2
1,143 06/25/2021 14:19:38 Nikkels 4 Trip (load rejection test
for Sullivan CC ProBoost Tuning )
59.66 X 0.0 0.0 0.00.1
1,144 07/28/2021 01:10:22 HPS Bus Fault 59.77 X 0.0 3.0 0.00.1
1,145 08/06/2021 11:25:26 AEP ST1 & ST2 Trip (blown fuse
cutout on buss)
59.79 X 0.0 0.0 0.03.7
1,146 08/09/2021 01:23:48 HLP ST2 Trip (lightning strike) 59.39 X 0.0 0.0 0.00.9
1,147 08/26/2021 23:48:10 AEP ST5 & ST1 Trip 59.78 X 0.0 0.0 0.02.3
1,148 08/28/2021 17:11:02 NPS GT2 Trip 59.81 X 0.0 0.0 0.02.9
1,149 09/15/2021 10:17:06 Beluga #5 Trip Load Rejection Test
1 - Testing ABB PODs
59.66 X 0.0 0.0 0.00.1
1,150 09/15/2021 11:18:01 Beluga #5 Trip Load Rejection Test
2 - Testing ABB PODs
59.67 X 0.0 0.0 0.00.1
1,151 06/03/2021 10:59:43 Douglas and Teeland tripped - a
phase to ground fault
60.97 X 10.3 31.3 20.00.1
1,152 08/03/2021 21:46:31 Douglas and Teeland tripped - a
phase to ground fault
60.32 X 0.0 0.0 16.10.0
1,153 10/07/2021 08:43:46 SPP Unit 10 trip - Operator Error 59.72 X 0.0 0.0 0.00.1
1,154 10/13/2021 13:54:03 SPP Unit 12 trip; cause unknown 59.57 X 0.0 0.0 0.00.3
1,155 10/21/2021 21:50:18 Hope 152 Trip due to B Phase to
ground fault
59.54 X 0.0 0.0 0.060.1
1,156 11/01/2021 11:07:06 ZNP GT1 Trip 59.78 X 0.0 0.0 0.01.4
1,157 10/26/2021 15:52:55 Douglas 1B1 Trip due to fault on
Healy line
60.39 X 0.0 0.0 0.00.1
3.10Average Duration
*has sub event
11/17/2021 SYSTEM EVENTS
EVENT DATE DESCRIPTION AEGT SES MEA MLP CEA GVEA HEA ORIGINATOR
1,157 Douglas 1B1 Trip due to fault on Healy line10/26/2021 15:52:55 X X CEA
1,156 ZNP GT1 Trip11/01/2021 11:07:06 X X GVEA X
1,155 Hope 152 Trip due to B Phase to ground fault10/21/2021 21:50:18 X X CEA X XX
1,154 SPP Unit 12 trip; cause unknown10/13/2021 13:54:03 X X CEA X XX
1,153 SPP Unit 10 trip - Operator Error10/07/2021 08:43:46 X X CEA X XX
1,152 Douglas and Teeland tripped - a phase to ground fault08/03/2021 21:46:31 X X CEA X XX
1,151 Douglas and Teeland tripped - a phase to ground fault06/03/2021 10:59:43 X X CEA X XX
1,150 Beluga #5 Trip Load Rejection Test 2 - Testing ABB
PODs
09/15/2021 11:18:01 X X CEA X XX
1,149 Beluga #5 Trip Load Rejection Test 1 - Testing ABB
PODs
09/15/2021 10:17:06 X X CEA X XX
1,148 NPS GT2 Trip08/28/2021 17:11:02 X X GVEA X XX
1,147 AEP ST5 & ST1 Trip08/26/2021 23:48:10 X X GVEA X XX
1,146 HLP ST2 Trip (lightning strike)08/09/2021 01:23:48 X X GVEA X XX
1,145 AEP ST1 & ST2 Trip (blown fuse cutout on buss)08/06/2021 11:25:26 X X GVEA X XX
1,144 HPS Bus Fault07/28/2021 01:10:22 X X GVEA X XX
1,143 Nikkels 4 Trip (load rejection test for Sullivan CC
ProBoost Tuning)
06/25/2021 14:19:38 X X CEA X XX
1,142 Nikkels 4 Trip (load rejection test)06/24/2021 15:06:48 X X CEA X XX
1,141 Nikkels 4 Trip (load rejection test)06/24/2021 14:43:41 X X CEA X XX
1,140 GHS B10 Trip (raven)06/21/2021 09:49:39 X X GVEA X XX
1,139 NPC GT3 Trip06/20/2021 12:50:04 X X GVEA X XX
1,138 NPC Trip06/20/2021 06:28:07 X X GVEA X XX
1,137 69kV FWS-HPS Trip05/18/2021 14:03:33 X X GVEA X XX
1,136 FKS jogs ball mill05/18/2021 07:35:12 X X GVEA X XX
1,135 HLP ST2 Trip05/04/2021 04:31:24 X X GVEA X XX
1,134 HLP ST1 Trip05/03/2021 16:08:30 X X GVEA X XX
1,133 HLP ST1 Trip05/02/2021 12:20:00 X X GVEA X XX
1,132 HLP ST1 Trip04/28/2021 10:16:29 X X GVEA X XX
1,131 138 kV CSS to GHS Trip04/26/2021 17:20:29 X X GVEA X XX
*Has Sub Events
Note: Main Event and ALL Sub Events must be Responded To , for an Event to be considered "RESPONDED TO"
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Event – AK Intertie Trip at Douglas 1B1
N-1 Event
Date 6/3/2021
Time – 10:59:41
Purpose
This document describes the 6/3/2021 system disturbance with sequence of event data from Plants and
SCADA systems along with fault disturbance recordings of Railbelt generation. Actions for improving the
damping of future oscillations are summarized as well.
Introduction
On 6/3/2021 a fault occurred on the Alaska Intertie and the transmission line tripped open. Oscillations
started after the trip and lasted for several minutes, with large power swings being observed across the
Southern Intertie between Anchorage and the Kenai Peninsula.
Event
The precipitating event was a phase-to-ground fault of the Alaska Intertie between Teeland and Douglas
Substations. Douglas breaker 1B1 and Teeland breakers 538 and 5162 tripped open and an oscillation
began between the Anchorage and Kenai regions of the Railbelt. The initial power flow from Teeland to
Douglas was 72 MW.
The initial system frequency response to the high frequency swing was 6.5 MW/0.1Hz, which is low but
within a typical range of frequency response seen in recent years. The oscillations that followed lasted
until 11:03:49. The total time that the system was oscillating was three minutes and eight seconds. The
oscillation consisted primarily of two frequency modes: the first was about 0.15 Hz and the second was
about 0.9 Hz. The largest power swing was 223 MW peak-to-peak as measured from Quartz Creek to
Daves Creek, and this swing occurred in the 0.9 Hz mode.
The 0.9 Hz mode damped out first at about 11:02:36. The 0.15 Hz mode continued beyond 11:02:36 and
manual intervention by CEA Operators was used to dampen out this mode. The 0.15 Hz mode damped
out after droop was disabled on all three of the SPP CT units.
System Conditions
There were no abnormal transmission system conditions prior to the fault. The only abnormality in the
generation dispatch was that the Nikiski Plant in the HEA area was offline and Soldotna G1 was
operating. In the previous two disturbances where the 0.15 Hz mode was observed, the Nikiski Plant
was online and the Soldotna Plant was offline.
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Pre-Disturbance Generation Dispatch
Table 1. Generation Dispatch for the Railbelt South of Douglas
Unit MW Output Bus Voltage 1
(KV; line-line)
MW and KV
Source
SPP 11 36.829 MW 137.5 ITSS Tesla
SPP 12 37.319 MW 137.4 ITSS Tesla
SPP 13 35.971 MW 137.6 ITSS Tesla
SPP 10 34.788 MW 137.4 ITSS Tesla
Sullivan 9 38.932 MW 116.1 Plant 2A Unit 9
Tesla
Sullivan 10 38.390 MW 116.2 Plant 2A Unit 10
Tesla
Sullivan 11 25.242 MW 116.1 Plant 2A Unit 11
Tesla
Eklutna 1 14.375 MW 12.0 Eklutna Tesla
Eklutna 2 11.708 MW 11.9 Eklutna Tesla
Cooper 1 – At Quartz 6.984 MW 116.0 Quartz Creek Tesla
Cooper 2 Unit Offline N/A N/A
FIWF 1.432 MW 35.3 Fire Island Tesla
Bradley 1 49.29 MW 14.0 Bradley Plant DCS
Bradley 2 26.94 MW 14.0 Bradley Plant DCS
Soldotna G1 40.082 MW 116.4 – South
Bus
Soldotna Tesla
Nikiski Plant Offline 115.5 N/A
EGS Plant (5 units) 59.165 MW 117.0 EGS Tesla (sum of
GSUs)
SVC MVAR Output Bus Voltage (KV;
line-line)
Source
Teeland SVC -2.32 MVAR 138.2 CEA SCADA
Daves Creek SVC 6.40 MVAR 117.1 CEA SCADA
Soldotna SVC -10.70 MVAR See Soldotna G1 CEA SCADA -
MVAR
Table 2. System Loads (Excludes GVEA)
Utility System Load (MW) Source
CEA 256.25 MW CEA SCADA
MEA 91.07 MW CEA SCADA
HEA 62.15 MW CEA SCADA
1 Average of a, b, and c phase pre-disturbance. Converted from line-neutral to line-line assuming balanced
conditions. Some voltages taken from a nearby high voltage bus rather than the local regulated bus. Voltages
values not time-synchronized.
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Table 3. Ambient Air Temperature
Location Ambient Air
Temperature
Source
SPP 53.06 F CEA SCADA
Sullivan CC 53.21 F CEA SCADA
Cooper Lake 47.10 F CEA SCADA
SCADA Sequence of Events
Time Source Event
06/03/21 10:59:41.637 CEA SCADA Teeland Teeland Bkr 538 Tripped
06/03/21 10:59:41.853 CEA SCADA DouglasA Douglas Bkr 1B1 Bkr Tripped
06/03/21 10:59:41.963 CEA SCADA Daves Creek Daves SVC Power Osc Damper Active
06/03/21 10:59:41.983 CEA SCADA Soldotna SVC Power Osc Damper Active
06/03/21 10:59:42.527 CEA SCADA Douglas Teeland Line Ground Fault Alarm
06/03/21 10:59:42.527 CEA SCADA Douglas Teeland Line C Phase Fault Alarm
06/03/21 10:59:47.058 CEA SCADA Bradley Lake Bradley Unit 1 Power Mode OFF
06/03/21 10:59:47.058 CEA SCADA Bradley Lake Bradley Unit 2 Power Mode OFF
06/03/21 10:59:47.058 CEA SCADA Bradley Lake Bradley Unit 1 Isolated Ctrl Mode ON
06/03/21 10:59:47.058 CEA SCADA Bradley Lake Bradley Unit 2 Isolated Ctrl Mode ON
06/03/21 11:00:29.114 CEA SCADA Bradley Lake Bradley Unit 1 Divider1 Mode ON
06/03/21 11:00:29.114 CEA SCADA Bradley Lake Bradley Unit 2 Divider1 Mode ON
06/03/21 11:01:13.000 Quartz Tesla (Approx Time) Oscillation Magnitude Starts Increasing
06/03/21 11:01:38.104 CEA SCADA Soldotna Soldotna Bkr 2326 Closed
06/03/21 11:01:55.690 CEA SCADA Soldotna Soldotna Bkr 2326 Tripped
06/03/21 11:01:59.411 CEA SCADA Soldotna Soldotna Bkr 2326 Closed
06/03/21 11:02:20.470 CEA SCADA Daves Creek Daves SVC Aux Power Stage 1 Alarm
06/03/21 11:02:28.553 CEA SCADA Daves Creek Daves SVC Power Osc Damper Block ON
06/03/21 11:02:28.790 CEA SCADA Daves Creek Daves SVC Power Osc Damper Block OFF
06/03/21 11:02:29.833 Quartz Tesla (Approx Time) 223 MW Power Swing First Peak
06/03/21 11:02:33.820 CEA SCADA SPP SPP12 ProBoost Relay Active
06/03/21 11:02:34.820 CEA SCADA SPP SPP12 ProBoost Relay Inactive
06/03/21 11:02:43.852 Soldotna Tesla (Approx Time) 0.9 Hz Mode Damped
06/03/21 11:03:16.000 GE Alarm (Estimate) SPP13 Droop Off
06/03/21 11:03:18.000 GE Alarm (Estimate) SPP11 Droop Off
06/03/21 11:03:22.000 GE Alarm (Estimate) SPP12 Droop Off
06/03/21 11:03:43.902 Soldotna Tesla (Approx Time) 0.15 Hz Mode Damped - Oscillation Over
06/03/21 11:03:54.164 CEA SCADA Soldotna Soldotna SVC Power Osc Damper Inactive
06/03/21 11:04:05.088 CEA SCADA Bradley Lake Bradley Unit 1 Divider1 Mode OFF
06/03/21 11:04:13.039 CEA SCADA Bradley Lake Bradley Unit 2 Divider1 Mode OFF
06/03/21 11:04:15.033 CEA SCADA Bradley Lake Bradley Unit 1 Divider1 Mode ON
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06/03/21 11:04:22.779 CEA SCADA Daves Creek Daves SVC Power Osc Damper Inactive
06/03/21 11:04:23.049 CEA SCADA Bradley Lake Bradley Unit 2 Divider1 Mode ON
06/03/21 11:05:49.053 CEA SCADA Bradley Lake Bradley Unit 1 Divider1 Mode OFF
06/03/21 11:06:31.048 CEA SCADA Bradley Lake Bradley Unit 1 Power Mode ON
Figure 1. Plot of Southern Tie Power (MW) with Key Events Shown
Tesla Analysis
Tesla disturbance fault recorder data was collected from CEA, MEA, and HEA recorders. The Tesla data
was exported, and timestamps were used to time synchronize the data for analysis. Tesla data is GPS
timestamped. Due to the length of the oscillation being longer than the recording window of the Teslas,
multiple recordings were produced by each Tesla recorder.
Appendix A shows plots of each generator’s output during the oscillation. The largest active power
swing (MW, peak to peak amplitude) for each unit is shown in the table below. The largest swing for
each unit were close to the time that the 223 MW swing was observed between Daves Creek and Quartz
Creek. From the table below, it’s clear that the highest participants in the oscillation were SPP 10 and
Sullivan 11 in the Anchorage area and Bradley in the Kenai area. SPP 10 and Sullivan 11 are known to
participate in the 0.9 Hz oscillation based on the 2019 Siemens Oscillation Study. Bradley is a radially
connected power plant and is often referred to as the ‘southern end’ of the Railbelt. Under these
conditions, it is expected that these units have high participation.
Table 4. Reference List of Largest MW Swings.
Unit Largest MW Swing
(Peak-Peak)
SPP 11 14.5 MW
SPP 12 13.5 MW
SPP 13 15.2 MW
SPP 10 83.0 MW
Sullivan 9 15.6 MW
Sullivan 10 16.8 MW
Sullivan 11 32.8 MW
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Eklutna 1 7.6 MW
Eklutna 2 6.8 MW
Cooper 1 (At Quartz) 10.1 MW
Bradley 1 57.3 MW
Bradley 2 68.7 MW
Soldotna G1 42.3 MW
EGS Plant (5 units) 27.7 MW
One damping control system issue that was demonstrated in this event was the adverse operation of
the Soldotna SVC. The Soldotna SVC is equipped with a power oscillation damper (POD) system that is
intended to increase damping for oscillations across the Southern Tie. The Daves Creek SVC has a POD as
well. The Soldotna POD has been observed to respond in the opposite direction as would be expected,
and this may be a source of instability for the system. Chugach is currently managing a project to tune
the Soldotna and Daves Creek SVC PODs, and this issue will be resolved in September 2021.
Figure 2. Southern Tie Flow (MW) and Soldotna SVC MVARs. SVC output is expected to lead MW oscillations by about 90
degrees, however here it appears to be lagging.
Results
The 0.15 Hz and the 0.9 Hz modes are analyzed independently of each other as there is not an indication
that they are directly related to each other. The 0.15 Hz oscillation has been studied and is considered a
control mode of oscillation. The 0.9 Hz mode has also been studied and is considered an interarea mode
of oscillation. This analysis will discuss these modes separately. It should be noted that while these
modes may not be directly related to each other, they do add to each other in the power swings and
exacerbate the overall system impact.
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The 0.15 Hz mode was observed during this disturbance, and all units connected to the system are
observed to have participated in this mode. The magnitude of power swings in this mode were relatively
small. This oscillation is unstable without operator intervention, meaning that it does not dampen out
unless operators intervene. In this event, and in previous 0.15 Hz oscillation events, the action that is
correlated to the damping of this mode was droop being turned off on all three of the SPP combustion
turbines. In addition to SPP’s participation in this mode, Bradley also participated in this mode. From
Plant data, Bradley’s participation can be traced back to divider response.
The 0.9 Hz mode was the more severe mode in this particular event in terms of the magnitude of power
swings that occurred. The 0.9 Hz mode is very commonly seen for system events such as AK Intertie
trips, and it is the result of interarea power swings between machines on the system. Typically, an
oscillation in the 0.9 Hz mode will naturally dampen out in less than 30 seconds. This event is concerning
in that the oscillation initially started to dampen, however it did not completely dampen, and then it
started to increase in magnitude. The abnormal increase in magnitude indicates that a system change
likely occurred during the event, and the closed preceding event to the increase in magnitude was the
activation of Bradley’s divider mode. Data was collected for Bradley divider position and it is clear that
there was participation in both oscillation modes from the Bradley dividers, however this alone is
unlikely to be the only cause of the negative damping seen in this event.
Conclusion
The June 3rd oscillation was the third occurrence of a 0.15 Hz oscillation caused by an Alaska Intertie trip.
Furthermore, large power swings between Anchorage and the Kenai areas occurred at a frequency of
0.9 Hz. The presence of both oscillation mode indicates a source of insecurity for the Railbelt, and
preventative measures should be taken to address the oscillations by increasing oscillation damping.
Recommendations
There are several projects with study work already completed that would benefit the Railbelt in terms of
oscillation damping. The power oscillation damper (POD) tuning at the Soldotna and Daves Creek SVCs is
already scheduled for September of 2021. Furthermore, HEA is soliciting RFPs for the tuning of the
power system stabilizers at Bradley Lake Hydro Plant and their other plants. Both the SVC POD project
and the Bradley PSS tuning are expected to help dampen oscillations over a range of modes, including
the 0.9 Hz mode. It is advised to proceed with the various oscillation tuning projects recommended by
the 2019 Siemens Power Technologies International (SPTI) study.
Study work has also been performed for the 0.15 Hz oscillation, which was first observed on June 4,
2020. According to a study performed by Siemens Power Technologies International (SPTI), the SPP
governors have a high participation in the 0.15 Hz oscillation. The Bradley Lake governor was excluded
from the SPTI study, however the data from this event shows that the Bradley dividers did participate in
the oscillation. It is recommended to further study the SPP governor and the Bradley Lake divider
controls to evaluate how to reduce the 0.15 Hz control system oscillation.
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Appendix A – Tesla Recordings of Online Generation
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Effective 7/1/21 YTD Actuals as a OVER
Approved % of Total (UNDER)
FY22 Budget YTD Budget YTD Actuals Annual Budget YTD Variance
REVENUES
GVEA 1,703,854 283,976 334,877 19.7%50,901
CEA 225,259 37,543 137,065 60.8%99,522
MEA 361,596 60,266 96,388 26.7%36,122
INTEREST / CAPITAL CREDITS - - 12 0.0%12
TOTAL REVENUES 2,290,709 381,785 568,341 24.8%186,557
EXPENSES
FERC 562 - Station Operation Expenses
GVEA - Substation Electricity Usage 8,000 1,333 739 9.2%(595)
8,000 1,333 739 9.2%(595)
FERC 566 - Miscellaneous Transmission Expense
GVEA - Private Line Telephone Service for AKI SCADA 18,000 3,000 926 5.1%(2,074)
AEA - Cell Phone Comm. Svc for Weather Monitoring (Verizon)12,000 2,000 2,004 16.7%4
AEA - SLMS Support and Intertie Ground Patrol 100,000 16,667 - 0.0%(16,667)
130,000 21,667 2,930 2.3%(18,736)
FERC 567 - Transmission Expenses - Rents
AEA - Rents - Alaska Railroad 700 117 - 0.0%(117)
MEA - Talkeetna Storage 7,200 1,200 1,200 16.7%-
MEA - Equipment Rental - - 102 0.0%102
7,900 1,317 1,302 16.5%(15)
FERC 570 - Maintenance of Station Equipment
GVEA - Perform Maintenance - Healy, Cantwell, Goldhill 74,340 12,390 2,347 3.2%(10,043)
GVEA - SCADA Maintenance Healy, Cantwell, Gold Hill 5,000 833 - 0.0%(833)
GVEA - Healy and Goldhill Digital Fault Recorders 90,000 15,000 - 0.0%(15,000)
GVEA - Gold Hill SVC Cooling 65,000 10,833 460 0.7%(10,373)
GVEA - Cantwell Install Breakers or Load Break Switches 266,000 44,333 - 0.0%(44,333)
GVEA - Perform Maintenance, repaint Reactors Gold Hill SVC Yard 80,000 13,333 - 0.0%(13,333)
CEA - Teeland Substation Communication - - 1,256 0.0%1,256
CEA - Teeland Substation 85,000 14,167 39,842 46.9%25,675
665,340 110,890 43,905 6.6%(66,985)
FERC 571 - Maintenance of Overhead Lines
GVEA - Northern Maintenance 78,000 13,000 38,419 49.3%25,419
GVEA - Northern ROW Clearing 73,000 12,167 - 0.0%(12,167)
MEA - Special Patrols [Incl Helicopter Inspections]5,000 833 - 0.0%(833)
MEA - Southern Maint (Incl Ground and Climbing Inspect)200,000 33,333 44,966 22.5%11,633
MEA - Southern ROW Clearing 150,000 25,000 40,373 26.9%15,373
MEA - Equipment Repair and Replacement 640,000 106,667 - 0.0%(106,667)
1,146,000 191,000 123,758 10.8%(67,242)
FERC 924 - Property Insurance
AK Intertie - Insurance 35,650 5,942 10,759 30.2%4,817
35,650 5,942 10,759 30.2%4,817
Intertie Operating Costs Total 1,992,890 332,148 183,392 9.2%(148,756)
FERC 920 - AEA Administrative Costs
Personal Services, Travel and Other Costs 100,000 16,667 14,317 14.3%(2,350)
100,000 16,667 14,317 14.3%(2,350)
FERC 920 - IMC Administrative Costs
IMC Administrative Costs (Audit, meetings, legal)17,500 2,917 5,234 29.9%2,317
17,500 2,917 5,234 29.9%2,317
FERC 566 - Miscellaneous Transmission Expense
Misc. System Studies 200,000 33,333 35,579 17.8%2,245
200,000 33,333 35,579 17.8%2,245
Intertie Administration Costs Total 317,500 52,917 55,129 17.4%2,212
TOTAL EXPENSE 2,310,390 385,065 238,521 10.3%(146,544)
SURPLUS (SHORTAGE)(19,681) (3,280) 329,820 -1675.8%333,100
Alaska Intertie FY22 Budget to Actuals Status Report for the Period July 1, 2021 through August 31, 2021
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Alaska Intertie FY22 Budget to Actuals Status Report for the Period July 1, 2021 through August 31, 2021
Budgeted Usage Actual Usage to Date
GVEA MEA CEA ML&P TOTAL GVEA MEA CEA ML&P TOTAL
MONTH MWH MWH MWH MWH MWH MONTH MWH MWH MWH MWH MWH
Jul 6,000 2,107 - - 8,107 Jul 4,815 1,863 - - 6,678
Aug 8,000 2,004 - - 10,004 - Aug 12,415 1,905 - - 14,320
Sep 7,000 1,884 - - 8,884 Sep - - - - -
Oct 10,000 1,711 - - 11,711 Oct - - - - -
Nov 8,000 1,715 - - 9,715 Nov - - - - -
Dec 9,000 2,040 - - 11,040 Dec - - - - -
Jan 10,000 2,454 - - 12,454 Jan - - - - -
Feb 10,000 2,008 - - 12,008 Feb - - - - -
Mar 6,000 1,855 - - 7,855 Mar - - - - -
Apr 12,000 1,750 - - 13,750 Apr - - - - -
May 10,000 2,011 - - 12,011 May - - - - -
Jun 6,000 2,002 - - 8,002 Jun - - - - -
TOTAL 102,000 23,541 - - 125,541 TOTAL 17,230 3,768 - - 20,998
INTERTIE PROJECTED ENERGY USAGE TO DATE (MWH)18,111 INTERTIE ACTUAL ENERGY USAGE TO DATE (MWH) 20,998
Budgeted Operating Costs for the period 332,148$ Actual Operating Costs for the period 183,392$
(based on amended budget)
Budgeted Usage Revenue for the period 161,550$ Actual (Billed) Usage Revenue for the period 187,302$
(budgeted rate x projected usage)(budgeted rate x actual usage)
Estimated Budgeted Energy Rate per MWH 15.31$
(based on to date budgeted costs and usage)
Annual Budgeted Energy Rate (Billed Rate)8.92$ Projected Actual Energy Rate per MWH 7.29$
(based on minimum contract value)(based on to date actual costs and usage)
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