Bonneville Power Administration Workshop Update

The Bonneville Power Administration conducted a workshop on August 4, 2020, focusing on load forecast updates, system firm critical outputs, guidelines for load forecast principles, and next steps for customers. The workshop highlighted the acceptance of load forecast updates from six customers, shared results of the updates, and outlined guidelines for future forecast adjustments. Customers were encouraged to submit change requests and participate in the discussion for further enhancements.

• Bonneville Power Administration
• Workshop Update
• Load Forecast
• System Firm Critical Output
• Guidelines

ashub Follow

Uploaded on Sep 17, 2024 | 0 Views

Download Presentation

Please find below an Image/Link to download the presentation.

The content on the website is provided AS IS for your information and personal use only. It may not be sold, licensed, or shared on other websites without obtaining consent from the author. Download presentation by click this link. If you encounter any issues during the download, it is possible that the publisher has removed the file from their server.

Presentation Transcript

1. B O N N E V I L L E P O W E R A D M I N I S T R A T I O N RHWM Process Workshop BP-22 Rate Period Draft Final Outputs August 4, 2020 WebEx: https://bpa.webex.com/bpa/j.php?MTID=m28747827 35fecd09b30ef10c4afd9ee2 Meeting Number: 199 280 9647 Meeting Password: 2FQvpr8YuQ3

2. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N RHWM Process Workshop Agenda Topic Presenter Introductions and Purpose of the Workshop Kathryn Patton Load Forecast Update Reed Davis Tier 1 System Firm Critical Output (T1SFCO): Hydro Study Results and Related RHWM Questions T1SFCO Study Results Peggy Racht Steve Bellcoff RHWM Augmentation Kathryn Patton Other Topics All Next Steps Kathryn Patton Predecisional. For discussion purposes only. 2

3. B O N N E V I L L E P O W E R A D M I N I S T R A T I O N Load Forecast Update for BP-22 RHWM Process 3 Predecisional. For discussion purposes only.

4. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N Load Forecast Updates Six customers have submitted comments for updates to their load forecasts. All six submittals met the update guidelines and have been accepted. All six load forecasts will be updated as requested. Aggregate results are an increase of ~11 aMW in 2022 and a decrease of ~2 aMW in 2023. Predecisional. For discussion purposes only. 4

5. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N Guidelines for Load Forecast Principles Guiding changes Communicate with us as soon as possible so your forecaster can review your additional information. This year we are a bit more flexible due to uncertainties around COVID-19. More likely to accept reasonable changes with identifiable COVID-19 links. Amounts of change are likely vary based on local economies. Amounts of change will likely vary up the maximum reduction we have seen identified worldwide. Only impacts customers with a non-zero AHWM . Continue to want to avoid subjective bias in results Make changes with a clearly identifiable cause and effect. Temporarily suspending some of the change criteria, those tied to modeling statistics and prior model performance. Incorporate highly probable information on new load and project additions. Include new loads/projects that have higher than 70% probability of occurring. Predecisional. For discussion purposes only. 5

6. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N Load Forecast Next Steps Customers provide notice of additional changes - ASAP, please. Submit forecast change request (including cause and amount) on BPA s public comment page: https://publiccomments.bpa.gov/OpenCommentListing.aspx Predecisional. For discussion purposes only. 6

7. B O N N E V I L L E P O W E R A D M I N I S T R A T I O N Hydro and T1SFCO Study Results

8. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N Firm Hydro Comparison to BP-20 RHWM The -275 aMW decrease in annual 1937 generation compared to BP20 RHWM is attributable to a change from Block Spill Pattern to 125% flex ( -160 aMW); the net CRSO EIS Preferred Alternative measures Implemented in FY22 & FY23 ( -110 aMW); and typical updates including water supply forecast and PNCA data updates ( -5 aMW) ( -275 aMW = -160 aMW - 110 aMW - 5 aMW ) Predecisional. For discussion purposes only. 8

9. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N Examining the FCRPS drop of 110 aMW Most FCRPS changes cause the T1SFCO to change about 2 aMW, up or down Summer Sliding Scale at Libby and Hungry Horse causes about 100 aMW drop in T1SFCO Libby and Hungry Horse 1937 drafts in BP-20 RHWM Libby and Hungry Horse 1937 drafts in BP-22 RHWM Predecisional. For discussion purposes only. 9

10. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N Firm Hydro Comparison to Recent Rate Case Predecisional. For discussion purposes only. 10

11. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N Historical T1SFCO Crosswalk 1937 Fed Hydro (aMW) 80 Yr Avg Fed Hydro (aMW) Spring Spill Operational Basis Summer Spill Operational Basis Approx Fish Ops Change (aMW) Approx Fish Ops Change (aMW) Sequential Delta Sequentia l Delta Rate Case (Avg of two FYs) BP16 RHWM1/ BP16 Final Proposal2/ BP18 RHWM3/ BP18 Final Proposal4/ BP20 RHWM5/ BP20 Initial Proposal6/ BP20 Final Proposal7/ BP22 RHWM8/ 2014 BiOp 2014 BiOp 6302 --- --- 8459 --- --- 2014 BiOp 2014 BiOp 6302 0 0 8410 - 49 0 2014 BiOp 2014 BiOp 6201 - 102 - 40 8425 15 -10 2014 BiOp 2014 BiOp 6210 9 0 8481 56 0 Block Spill Design Spill to 120% TDG Revise spill caps 125% Flex Spill Performance Standard Performance Standard Revise spill caps Performance Standard 6174 - 36 - 110 8343 - 138 - 110 5986 - 188 - 190 8166 - 177 - 170 6070 84 80 8278 112 110 5899 - 171 - 50 8172 - 106 - 100 Footnotes can be found in the Appendix, slide 25. Predecisional. For discussion purposes only. 11

12. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N Federal Tier 1 System Firm Critical Output Summary Federal Tier 1 System Firm Critical Output Projection - 2-Year Average RHWM Process for BP-22 Rate Period S210-RC-20200716-093322 A B C 2022 2023 Average T1SFCO Projections Energy in aMW 1. 2. Total Federal System Hydro Generation (TRM Table 3.1) 6,294 6,295 6,294 3. Total Designated Non-Federally Owned Resources (TRM Table 3.2) 1,154 1,018 1,086 4. Total Designated BPA Contract Purchases (TRM Table 3.3) 136 136 136 5. Total Designated System Obligations (TRM Table 3.4) -851 -848 -849.58 6. Federal Tier 1 System Firm Critical Output (sum of Lines 2-5) 6,733 6,601 6,667 12 Predecisional. For discussion purposes only.

13. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N HLH/LLH Modeling Change BPA identified an issue in the HOSS modeling process, due to the lack of a Light Load Hours purchase limit, as a result the model was over shaping energy into Heavy Load Hours What was found Model outputs included in the May workshop materials did not include a LLH market limit, As a result, the model unrealistically pushed more hydro generation into Heavy Load Hours. What was done Implemented a market depth limit of 1,000 aMW on Light Load Hours What does this change? Annual Average Energy = Zero change Monthly Average Energy = Zero change Heavy Load Hour Energy = 175 annual aMW reduction Light Load Hour Energy = 175 annual aMW increase Table represents Monthly reduction in HLH energy, increase in LLH energy in each month is equal HLH aMW Oct Nov Dec Jan Feb Mar Apr 1 Apr 16 May Jun Jul Aug 1 Aug 16 Sep Annual FY2022 -60 -162 -535 -524 -452 -241 -30 -54 0 0 -42 -54 -37 -18 -175 FY2023 -28 -140 -492 -548 -463 -218 -20 -53 -2 -2 -107 -60 -45 -50 -175 Change has no effect on the annual RHWM, but it does effect monthly/diurnal RT1SC values. Predecisional. For discussion purposes only. 13

14. B O N N E V I L L E P O W E R A D M I N I S T R A T I O N RHWM Augmentation

15. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N Extension of Tribal Augmentation BPA received comments from NRU, PPC, and WPAG that BPA should follow the procedures outlined in Section 13 and 14 of the Tiered Rate Methodology (TRM) to implement such a change. BPA concurs with this assessment on process and appreciates that the commenters did not express concern about the substance of the proposal. Making formal changes through the voting procedures of the TRM is a process hurdle that the Region has undertaken only once. Recognizing that this process is time-intensive, BPA is not proposing a formal change be evaluated during the current RHWM process. In the event that a written request is submitted to BPA, we remain open to proposing an extension of the expiration date for the load growth exception for New Tribal Utilities in section 4.1.6.4 of the TRM and exploring alternative approaches, consistent with the current TRM to best meet the needs of Tribal Utilities during the term of the Regional Dialogue Contracts. Predecisional. For discussion purposes only. 15

16. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N Next Steps Public comment period August 5 August 19, 2020. Please submit comments (including load forecast change requests) on BPA s public comment page: https://publiccomments.bpa.gov/OpenCommentListing.aspx RHWM draft final outputs are posted on the RHWM website: https://www.bpa.gov/Finance/RateCases/RHWM/Pages/Current%20 RHWM%20Process.aspx Deadline for written preservation of right to dispute is August 7, 2020. Republish RHWM process outputs (if any changes made due to public comments) by September 8, 2020. Publish final RHWM process outputs by September 30, 2020. Predecisional. For discussion purposes only. 16

17. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N Questions? Predecisional. For discussion purposes only. 17

18. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N Appendix Predecisional. For discussion purposes only. 18

19. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N BP-22 RHWM Timeline Action FY 20 Timing Public Workshop Present preliminary RHWM process outputs May 19 (Tuesday) Public comment period May 20 (Wednesday) June 3 (Wednesday) Second Public Workshop (if necessary) June 23 (Tuesday) Calculate draft final RHWM outputs July FORMAL PROCESS BEGINS Public Workshop Present draft final RWHM outputs August 4 (Tuesday) Draft final RHWM outputs published August 5 (Wednesday) Public comment period August 5 (Wednesday) August 19 (Wednesday) Deadline for written preservation of right to dispute August 7 (Friday) Republish RHWM Outputs (if changes made due to public comments) September 8 (Tuesday) Deadline for dispute notice September 18 (Friday) Publish final RWHM process outputs September 30 (Wednesday) 19 Predecisional. For discussion purposes only.

20. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N Hydro Study Typical Updates Pacific Northwest Coordination Agreement (PNCA) Project Data Update based on 2019 PNCA data, with latest Coulee pumping data from 2020 PNCA submittal Canadian Operations Update based on the 2022 Assured Operating Plan (AOP22) completed under the Columbia River Treaty. AOP22 provides the same Canadian Operation for FY20 FY24. Project Outages Update based on the latest long term maintenance and capital program forecasts from PGAF. This will use the same methodology as the last rate case. Reserves Update FCRPS reserve assumptions consistent with Generation Inputs forecasts. Loads Update based on latest forecasts produced by KSL and aggregated by PGPR in LORA. Predecisional. For discussion purposes only. 20

21. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N Updates from CRSO EIS Preferred Alternative Water Supply Forecast Include the Corps Water Supply Forecast, uses consistent forecasting methodology Project Operations Update Flood Risk Management inputs based on new Water Supply Forecast Minimum Operating Pool at John Day raised April-May to disrupt salmonid predators Implement sliding scale summer draft at Libby and Hungry Horse Allow Dworshak to draft slightly deeper for hydropower (winter/early-spring) Set lower Grand Coulee September and October targets to maintain power flexibility Updates affecting Hydro availabilities obtained from PGAF Contingency reserves can include unused turbine capacity (Lower Snake, Lower Columbia projects) Allow turbine operation within and above 1% of peak efficiency Allow each Lower Snake project to carry up to 5% reserves during fish passage season Updates Affecting H/K values of plant data input Installation of fish-friendly turbines at IHR (slightly increases H/K) Predecisional. For discussion purposes only. 21

22. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N Spill Updated with 2020 125% Flex Spill Spring Spill Season Begins - Lower Snake Projects: April 3, Lower Columbia Projects: April 10 125% Flex Spill: LWG, LGS, LMN, IHR, MCN, BON (with 150 kcfs max spill) - applies 125% TDG spill caps (16 hrs), Performance Standard Spill (8 hrs) 120% Flex Spill: JDA - applies 120% TDG spill caps (16 hrs), Performance Standard Spill (8 hrs) TDA 40% Performance Standard Spill (24 hrs) Summer Spill Season Begins Lower Snake Projects: June 21, Lower Columbia Projects: June 16 Performance Standard Spill at all eight projects Ends August 14, and transitions into reduced spill amounts through August 31 Predecisional. For discussion purposes only. 22

23. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N Examining the FCRPS drop of 110 aMW Most FCRPS changes cause the T1SFCO to change about 2 aMW, up or down Fish friendly turbines at Ice Harbor Deeper draft and changing flexibility at Dworshak Relaxing Minimum Operating Pool on four Lower Snake projects Adjusting Minimum Operating Pool at John Day Summer Sliding Scale at Libby and Hungry Horse causes about 100 aMW drop in T1SFCO Predecisional. For discussion purposes only. 23

24. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N Sliding Scale Changes Summer Draft Targets Libby and Hungry Horse continue to be drafted deeper in the summer during dry years, providing more water for downstream uses Sliding Scale changes September draft targets Previous September draft targets based on the system-wide volume water forecasts at The Dalles Current Sliding Scale draft targets based on Linear interpolation between draft points Volume water forecast triggers based on 30 year record of NOAA April- August water volumes from 1981 - 2010 The May forecast of the local volume water forecasts (local water supply forecasts can be quite different than the system-wide forecasts) These refinements cause substantially less summer drafts at both Libby and Hungry Horse during dry years (like 1937) Predecisional. For discussion purposes only. 24

25. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N Footnotes on T1SFCO Crosswalk 1/ FY17 included Spring Maximum Transport of fish in 8 driest years at Lower Granite, Little Goose and Lower Monumental, hence there was no Spring Spill at those projects. Studies revised the Early August Spill Curtailment dates. 2/ No spill operational changes, but hydro plant availabilities were revised. 3/ Removed Spring Maximum Transport assumption, increasing spill and reducing generation in 1937 and seven other water years. Revised Early August Spill Curtailment dates by one to four days on Lower Snake projects, extending the Summer Spill season. 4/ No spill operational changes, but revised hydro plant availabilities and H/K tables at Chief Joe. 5/ Included Spring Block Spill Design, alternating between a four week Gas Cap Spill Block and Performance Standard Spill, significantly increases Spring spill. August Spill Curtailment Dates were not forced to be sequential on Lower Snake projects, and generally decreases Summer spill. Spill cap updates generally increase spill during both Spring and Summer. Included modeling refinements to more closely match current operations. 6/ Spill to 115%/120% TDG gas cap whenever possible in Spring (FY 2018 Maximum Spill Operation). Removes August Spill Curtailment, spilling to the end of August. 7/ Included revised spill caps, based on data collected during the 2018 spill season that reflects spilling to the 115%120% TDG as much as possible in the Spring. 8/ Includes 2020 125% Flexible Spill Operation, and modeling updates to reflect direction of FCRPS. Summer spill ends on August 14, transitions into small spill amounts through end of August. Predecisional. For discussion purposes only. 25

26. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N T1SFCO Difference Between BP-22 RHWM Process and BP-20 Final RHWM Federal Tier 1 System Firm Critical Output Projection - 2-Year Average RHWM Process for BP-22 Rate Period RHWM Process for BP-22 Rate Period (FY 2022-23) RHWM Process for BP-20 Rate Period (FY 2020-21) Difference 2-Year Average T1SFCO 2-Year Average Comparison (Energy in aMW) Component Details T1SFCO Resource Differences Hydro generation forecasts were reduced due to the following: l Spill Change (about -160 aMW): Block Spill pattern to 125% Flex Spill Operation l CRSO PA Measures (about -110): Libby/Hungry Horse Sliding Scale, Grand Coulee variable draft limits, etc 1. Total Federal System Hydro Generation (TRM Table 3.1) 6,294 6,567 -273 Non Federally owned resource changes: l Foote Creek I contract acquisition terminated in 2019 (-3.6 aMW) l Foote Creek iV contract acquisition expires 10/1/2020 (-2 aMW) l Klondike I contract acquisition expires 4/2022 (-4.2 aMW) l Condon Wind contract acquisition expires 9/30/2022 (-5.9 aMW) 2. Total Designated Non Federally Owned Resources (TRM Table 3.2) 1,086 1,102 -16 3. Total Designated BPA Contract Purchases (TRM Table 3.3) 136 138 -1 T1SFCO Load/Obligation Differences Contract purchase changes: l BPA/BCHA Canadian Entitlement Return (+8.1 aMW) l Slice Transmission loss Returns (-8.6 aMW) 4. Total Designated System Obligations (TRM Table 3.4) -850 -851 2 5. Federal Tier 1 System Firm Critical Output (2-year average) 6,667 6,955 -288 Predecisional. For discussion purposes only. 26

27. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N T1SFCO Change Over Time 2012 RHWM 2014 RHWM 2016 RHWM 2018 RHWM 2020 RHWM 2022 RHWM T1SFCO 7,135 7,058 6,924 6,879 6,955 6,667 T1SFCO Change Over Time 7,500 7,400 7,300 7,200 7,100 7,000 6,900 6,800 6,700 6,600 6,500 2012 RHWM 2014 RHWM 2016 RHWM 2018 RHWM 2020 RHWM 2022 RHWM Predecisional. For discussion purposes only. 27

28. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N Federal System Hydro Generation Used in T1SFCO Calculation Federal System Hydro Generation for use in the T1SFCO Calculation RHWM Process for BP-22 Rate Period TRM Table 3.1 S210-RC-20200716-093322 A B C 2022 2023 Average Regulated Hydro 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. Libby 11. Little Goose 12. Lower Granite 13. Lower Monumental 14. McNary 15. The Dalles Albeni Falls Bonneville Chief Joseph Dworshak Grand Coulee Hungry Horse Ice Harbor John Day 22.0 371.5 1,109.2 140.2 1,928.3 73.5 107.6 694.7 165.3 109.8 106.8 108.9 414.6 592.6 23.4 371.6 1,109.2 140.2 1,928.3 73.5 107.6 695.2 165.3 109.8 106.7 108.9 414.6 592.3 22.7 371.6 1,109.2 140.2 1,928.3 73.5 107.6 694.9 165.3 109.8 106.8 108.9 414.6 592.5 Predecisional. For discussion purposes only. 28

29. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N Federal System Hydro Generation Used in T1SFCO Calculation (cont.) Federal System Hydro Generation for use in the T1SFCO Calculation RHWM Process for BP-22 Rate Period TRM Table 3.1 S210-RC-20200716-093322 A B C 2022 2023 Independent Hydro Average 16. 17. Anderson Ranch 18. Big Cliff 19. Black Canyon 20. Boise River Diversion 21. Chandler 22. Cougar 23. Cowlitz Falls 24. Detroit 25. Dexter 26. Foster 27. Green Peter 28. Green Springs - USBR 29. Hills Creek 30. Idaho Falls - City Plant (expires 9/30/2016) 31. Idaho Falls - Lower Plants #1 & #2 (expires 9/30/2016) 32. Idaho Falls - Upper Plant (expires 9/30/2016) 33. Lookout Point 34. Lost Creek 35. Minidoka 36. Palisades 37. Roza 12.2 10.0 6.2 1.2 6.1 19.1 26.5 41.8 9.3 12.4 27.2 7.3 17.9 12.2 10.0 6.2 1.2 6.1 19.1 26.5 41.8 9.3 12.4 27.2 7.3 17.9 12.2 10.0 6.2 1.2 6.1 19.1 26.5 41.8 9.3 12.4 27.2 7.3 17.9 36.2 30.1 10.7 67.4 6.9 36.2 30.1 10.7 67.4 6.9 36.2 30.1 10.7 67.4 6.9 38. Total Tier 1 Federal System Hydro Generation 6,293.6 6,294.4 6,295.2 29 Predecisional. For discussion purposes only.

30. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N Designated Non-Federally Owned Resources Used in T1SFCO Calculation Designated Non-Federally Owned Resources for use in the T1SFCO Calculation RHWM Process for BP-22 Rate Period TRM Table 3.2 S210-RC-20200716-093322 A B C 2022 2023 Average Project 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. Georgia-Pacific Paper (Wauna) (Acquisition Expired 4/5/2016) 11. Klondike I (expires 4/2022) 12. Stateline Wind Project (expires 12/2026) 13. White Bluffs Solar (expired in 1996) Ashland Solar Project (expires 5/31/2020) Columbia Generating Station Condon Wind Project (expires 9/30/2022) Dworshak/Clearwater Small Hydropower Foote Creek 1 (early termination in 2019) Foote Creek 2 (expired 2014) Foote Creek 4 (Acquisition Expires 10/1/2020) Fourmile Hill Geothermal (Not included) 1,116.0 11.7 993.7 1,054.8 11.7 2.6 2.6 2.6 0.0 0.0 0.0 2.9 21.2 2.9 21.2 21.2 Total Designated Non-Federally Owned Resources 14. 1,154.4 1,017.5 1,086.0 Predecisional. For discussion purposes only. 30

31. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N Designated BPA Contract Purchases Used in T1SFCO Calculation Designated BPA Contract Purchases for use in the T1SFCO Calculation RHWM Process for BP-22 Rate Period TRM Table 3.3 S210-RC-20200716-093322 A B C D 2022 2023 Average Contract Purchases Contract # 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. PASA to BPA S/N/X(expired 4/30/2015) 11. PASA to BPA Xchg Nrg(expired 4/30/2015) 12. RVSD to BPA Pk Repl (expired 4/30/2016) 13. RVSD to BPA Seas Xchg(expired 4/30/2016) 14. RVSD to BPA Xchg Nrg(expired 4/30/2016) 15. PPL to BPA SNX (Spring Return)(expired 6/1/2014) 16. PPL to BPA SPX (Summer Return)(expired 6/1/2014) Priest Rapids CER for Canada Rock Island #1 CER for Canada Rock Reach CER for Canada Wanapum CER for Canada Wells CER for Canada BCHP to BPA PwrS BCHP to BPA LCA (settled financially) PASA to BPA Pk Repl(expired 4/30/2015) 97PB-10099 97PB-10102 97PB-10103 97PB-10100 97PB-10101 99PB-22685 99PB-22685 94BP-93658 94BP-93658 94BP-93658 94BP-93958 94BP-93958 94BP-93958 94BP-94332 94BP-94332 29.1 17.1 37.1 27.9 24.0 1.0 29.1 17.1 37.1 27.9 24.0 1.0 29.1 17.1 37.1 27.9 24.0 1.0 17. Total Designated BPA Contract Purchases 136.3 136.3 136.3 31 Predecisional. For discussion purposes only.

32. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N Designated BPA System Obligations Used in T1SFCO Calculation Designated BPA System Obligations for use in the T1SFCO Calculation RHWM Process for BP-22 Rate Period TRM Table 3.4 (Negative numbers indicate obligations) S210-RC-20200716-093322 A B C D 2022 2023 Average System Obligation Contract # 1. 14-03-17506; 14-03-49151 Ibp-4512; 14-03-001-12160 14-03-73152 EW-78-Y-83-00019 14-03-49151 EW-78-Y-83-00019 14-03-49151 14-03-63656 14-03-32210 14-03-49151 10GS-75345 DE-MS79-88BP92591 99PB-22685 99EO-40003 12PG-10002 2. BPA to BRCJ Chief Joseph -8.7 -8.7 -8.7 3. BPA to BRCB Columbia Basin Project -137.9 -137.9 -137.9 4. 5. 6. 7. 8. 9. 10. BPA to BRTD The Dallas Reclamation Project 11. BPA to BRTV Tualatin Project 12. BPA to BRUB Umatilla Basin Project 13. BPA to BRYK Yakima Project 14. BPA to BCHP LCA (settled financially) 15. BPA to BCHA Can Ent 16. BPA to BCHA NTSA BPA to BRCR Crooked River Project BPA to BROP Owyhee Project BPA to BRRP Rathdrum Prairie Project BPA to BRSID Southern Idaho Projects BPA to BRSIN Spokane Indian Develop. BPA to BRSV Spokane Valley -0.7 -1.4 -0.8 -19.9 -0.3 -0.7 -1.9 -0.8 -2.1 -1.7 0.0 -454.3 -10.2 -0.7 -1.4 -0.8 -19.9 -0.3 -0.7 -1.9 -0.8 -2.1 -1.7 0.0 -454.3 -10.3 -0.7 -1.4 -0.8 -19.9 -0.3 -0.7 -1.9 -0.8 -2.1 -1.7 0.0 -454.3 -10.3 32 Predecisional. For discussion purposes only.

33. B B O O N N N N E E V V I I L L L L E E P P O O W W E E R R A A D D M M I I N N I I S S T T R R A A T T I I O O N N Designated BPA System Obligations Used in T1SFCO Calculation (cont.) Designated BPA System Obligations for use in the T1SFCO Calculation RHWM Process for BP-22 Rate Period TRM Table 3.4 (Negative numbers indicate obligations) S210-RC-20200716-093322 A B C D 2022 2023 Average System Obligation Contract # 1. 17. BPA to BHEC 2012PSC (expired 6/30/2017) 18. BPA to PASA C/N/X (expired 4/30/2015) 19. BPA to PASA S/N/X (expired 4/30/2015) 20. BPA to RVSD C/N/X (expired 4/30/2016) 21. BPA to RVSD Seas Xchg (expired 4/30/2016) Federal Intertie Losses (Calculated: 3.0% of Intertie Sales Table 2.12.5 lines 18-21) 23. BPA to AVWP WP3 S (expires 6/30/2019) 24. BPA to PPL SNX (Spring Delivery) (expired 6/1/2014) 25. BPA to PPL SPX (Summer Delivery) (expired 6/1/2014) 26. BPA to PSE WP3 S (expired 6/30/2017) 27. BPA to PSE Upper Baker 2 28. BPAP to BPAT (Dittmer/Substation Service) 29. Federal Power Trans. Losses 30. Slice Transmission Loss Returns 97PB-10051 94BP-93658 94BP-93658 94BP-93958 94BP-93958 22. n/a 0.0 0.0 0.0 85BP-92186 94BP-94332 94BP-94332 85BP-92185 09PB-12126 09PB-12128 n/a n/a -1.3 -9.4 -227.9 28.9 -1.3 -9.4 -223.9 28.4 -1.3 -9.4 -225.9 28.6 Total Designated System Obligations 31. -851.3 -847.9 -849.6 Predecisional. For discussion purposes only. 33