electronically filed with rca...electronically filed with rca regulatory commission of alaska 701 w....

Chugach Electric Association, Inc. 5601 Electron Drive, P.O. Box 196300 Anchorage, Alaska 99519-6300 ● (907) 563-7494 Fax (907) 562-0027 ● (800) 478-7494

www.chugachelectric.com ● [email protected]

August 26, 2020 ELECTRONICALLY FILED WITH RCA Regulatory Commission of Alaska 701 W. 8th Avenue, Suite 300 Anchorage, Alaska 99501 Subject: Tariff Advice No. 495-8; Chugach Electric Association, Inc. Post-Acquisition

Combined Fuel and Purchased Power Rate Adjustments Proposed Methodology in Compliance with Order No. U-18-102(44)/U-19-020(39)/U-19-021(39)

Commissioners: Chugach Electric Association, Inc. (“Chugach”) hereby submits for Regulatory Commission of Alaska (“Commission”) for approval of the methodology submitted herein to establish unified fuel and purchased power rates for the combined service areas of Certificate of Public Convenience and Necessity (“CPCN”) Nos. 8 and 121. On May 28, 2020, the Commission issued Order No. U-18-102(44)/U-19-020(39)/U-19-021(39) (“Order 39”) approving Chugach’s acquisition of the Municipality of Anchorage (“MOA”) d/b/a Municipal Light & Power (“ML&P”), subject to conditions. A primary condition, as identified by Ordering Paragraph No. 30, states:

Within 90 days after the date of this order, Chugach Electric Association, Inc. shall submit, as a tariff advice filing, proposed tariff sheets establishing a methodology to calculate a unified cost of power adjustment for the combined Certificate of Public Convenience and Necessity No. 8 and Certificate of Public Convenience and Necessity No. 121 service areas.

Chugach submits the following tariff filing in compliance with the Alaska Public Utilities Regulatory Act and 3 AAC 48.200 – 3 AAC 48.430 and Sections 3 AAC 48.200 - 3 AAC 48.420 of the Alaska Administrative Code. TARIFF SHEET NUMBER CANCELS SHEET NUMBER SCHEDULE OR ORIGINAL REVISED ORIGINAL REVISED RULE NUMBER

94 161st Revision 94 160th Revision Fuel & Purchased 94.04 41st Revision 94.04 40th Revision Power Adjustment 94.05 52nd Revision 94.05 51st Revision Factors at G&T, 94.1 98th Revision 94.1 97th Revision Retail Primary,

94.1.1 37th Revision 94.1.1 36th Revision and 94.1.2 Original n/a n/a Retail Secondary

95 159th Revision 95 158th Revision Actual Fuel & 95.04 39th Revision 95.04 38th Revision Purchased Power

.. ~~ ------CHUGACH--

POWERING ALASKA'S FIJTIJRE

Commissioners August 26, 2020 Tariff Advice No. 495-8 of 9

95.05 49th Revision 95.05 48th Revision Cost

95.5 97th Revision 95.5 96th Revision Schedules 97 142nd Revision 97 141st Revision Purchase & Sales Q.F.

97.1.4 5th Revision 97.1.4 4th Revision Fuel & Purchased 97.5.2 5th Revision 97.5.2 4th Revision Power Adjustment

97.6.1 5th Revision 97.6.1 4th Revision Factors History Chugach is requesting Commission approval of the methodology identified herein to establish unified (CPCN Nos. 121 and 8) fuel rates, purchased power rates, and the Fire Island Wind Renewable Energy Adjustment Factor for retail deliveries at primary and secondary voltage.1 As this request is for methodological approval only, Chugach is not proposing any rate adjustments with this filing and does not request approval of the tariff sheets submitted herewith for inclusion in its tariff. Rather, the information submitted herein is used as the basis to establish the underlying methodology for determining fuel and purchased power rates as a combined system under CPCN Nos. 8 and 121. In this filing, all the attached tariff sheet have been marked “For Approval of Methodology Only” for clarity. Based on Commission approval of the proposed methodology in this filing, Chugach will submit its fuel and purchased power filing reflecting the acquisition of ML&P by November 17, 2020 for rates effective January 1, 2020. This filing is not for a new service, will not result in the termination of an existing service, conflict with any other schedule or rate contained in Chugach’s operating tariff, or in any other way adversely impact customers or the public. The service areas under CPCN Nos. 121 and 8 are designated in this filing as the North District and South District respectively. Approximately 113,225 retail metered locations and wholesale customer Seward Electric System (Seward) are impacted by this filing, with 31,225 retail metered locations in CPCN 121 and approximately 82,000 retail and wholesale metered locations in CPCN 8. On a preliminary basis, Chugach is projecting annual revenues of approximately $325 to $350 million for calendar-year 2021.2 Order 39 required Chugach to include in its quarterly fuel and purchased power rate adjustment process the Restricted Rate Reduction (“RRR”) account rebate and the Beluga River Unit (“BRU”) Contributed Capital surcharge and rebate, which were submitted to the Commission on August 26, 2020 under Tariff Advice Nos. 492-8 and 493-8, respectively. These two tariff filings request Commission approval of the methodology for these factors; however, once the methodology is approved, the tariff sheets and supporting exhibits for the calculation of the surcharge and rebates will be updated and submitted to the Commission as part of Chugach’s quarterly fuel and purchased power rate adjustment process. Chugach has included a new tariff sheet in this filing, attached as Tariff Sheet No. 94.1.2, that summarizes the quarterly RRR rebate surcharge, the BRU

1 Fuel and purchased power costs assigned to the City of Seward are recovered on an actual cost basis rather than on a rate basis. Chugach is not proposing any changes to this cost recovery approach. 2 The projections are preliminary and subject to change as Chugach is developing 2021 forecasts. When including the Restricted Rate Reduction rebate, the Beluga River Unit Contributed Capital surcharge and rebate, the combined BRU GTP and the combined fuel and purchased power rates, the estimated impact to a monthly residential customer bill based on 600 kWh is a reduction of approximately 6 to 9 percent. These estimated impacts will be updated in Chugach’s mid-November 2020 filing to the Commission.


Contributed Capital surcharge and rebate, and the combined system fuel and purchase power rates calculated herein. The surcharge, rebates and fuel and purchased power rates summarized on this sheet will not be implemented but instead are shown to illustrate how the information will be provided to the Commission in the future. For billing purposes, the RRR rebate, the BRU Contributed Capital surcharge and rebate, and the fuel and purchased power rates will be separate line items on each customer bill. Chugach has structured this filing in two sections. Section I presents the detailed methodology for establishing unified rates for the recovery of all fuel and purchased power costs. This section also includes a description of the changes within each exhibit and tariff sheet used to develop the rates. Section II summarizes how Chugach expects to transition from the recovery of fuel and purchased power costs as separate entities to the recovery of costs as a unified system, and how its initial combined fuel and purchased power rate recovery filing will be structured. Section I: Methodology for Establishing Unified Fuel and Purchased Power Rates As a combined system under CPCN Nos. 8 and 121, Chugach is proposing to continue the use of its established methodology for the recovery of fuel and purchased power costs. Chugach’s recovery of these costs is completed on an average cost basis, with rates reflecting deliveries at primary and secondary service. Three rate components are used for the recovery of these costs: the fuel rate, the purchased power rate, and the Fire Island Wind Renewable Energy Adjustment Factor. Chugach is proposing to adopt this rate and recovery structure for all retail customers on the combined system such that all customers served at primary voltages pay the same rate and all customers served at secondary voltages pay the same rate, regardless of location. The fuel rate includes the cost of natural gas, gas transportation and gas storage. The purchased power rate includes the cost of Bradley Lake purchases, purchases from other Railbelt utilities, and purchases from qualified facilities. The Fire Island Wind Renewable Energy Adjustment Factor provides recovery of the incremental cost of purchases from the Fire Island Wind project. In contrast, ML&P recovers its fuel and purchased power costs through a single Cost of Power Adjustment (“COPA”) factor, adjusted to reflect delivery at primary and secondary voltage. Explanation of Exhibits: Fuel and Purchased Power Cost Recovery Chugach has updated the exhibits used in the determination of its quarterly fuel and purchased power rates to reflect Chugach’s acquisition of ML&P and the resultant combined operations and recovery of fuel and purchased power costs on a unified basis. The cost and sales information used to develop unified rates are based on actual first quarter 2020 results and projections through third quarter 2020, with adjustments as noted.3 Below is an explanation of the changes made to each of Chugach’s exhibits used in its quarterly fuel and purchased power rate adjustment process, and the creation of a new exhibit that has information previously shown on an existing Chugach tariff sheet. • Exhibit 1 – Projections: Exhibit 1, pages 1 through 3, presents projections for system fuel

and purchased power expenses, and generation and purchased power requirements (MWh)

3 Municipal Light and Power COPA filing, Tariff Advice No. 377-121; Chugach fuel and purchased power rate adjustment process, Tariff Advice No. 489-8.


needed to meet the combined system load requirements. The projections in this exhibit are used in the rate determinations on Tariff Sheet Nos. 94 through 94.05.

As indicated above, under a system average cost methodology, Chugach has combined all fuel and purchased power costs and generation requirements to meet the combined system load of Chugach and ML&P.4 Chugach has modified this exhibit by incorporating the generation and purchased power requirements previously met by ML&P under CPCN 121. Specifically, Plant 1, 2 and 2A have been added to each fuel supply source; fuel storage and transportation costs have been combined, as have the costs and production levels associated with the BRU.5 Overall, combined expenses include natural gas purchases from Hilcorp, Furie, and other gas producers, gas transportation costs, gas storage costs, and purchases from Bradley Lake, and purchases from qualified facilities and other Railbelt utilities. Wheeling and economy energy sales transactions between Chugach and ML&P have been removed as these transactions will no longer exist, post-acquisition.

Development of the allocation factors shown on page 4 of Exhibit 1 have been expanded to include customers currently served under CPCN 121.

• Exhibit 2 – MWh Sales: Exhibit 2 presents MWh sales by retail and wholesale rate class for

the 12-months ended March 2020. Chugach has added the residential, small commercial, large commercial and lighting classes previously served under CPCN 121 to this exhibit. Also included are sales to Golden Valley Electric Association, Inc. (“GVEA”), Homer Electric Association, Inc. (“HEA”) and Matanuska Electric Association, Inc. (“MEA”). Economy energy sales transactions between Chugach and ML&P have been removed from this exhibit. This exhibit also calculates system losses using the prior 12-month period, based on MWh sales and generation / purchased power levels.

• Exhibit 3 – Generation: Exhibit 3 presents generation and purchased power levels for the

12-months ended March 2020. Chugach has added Plant 1, Plant 2 and Plant 2A, ML&P’s 30 percent interest in the Southcentral Power Project, and ML&P’s purchases from Bradley Lake, qualified facilities and the Eklutna Hydro Project to this exhibit. Transactions between Chugach and ML&P are excluded.

• Exhibit 4 – Natural Gas Usage (Mcf): Exhibit 4 presents the natural gas usage by unit for

each power plant. Chugach has added Plant 1, Plant 2 and Plant 2A to this exhibit, and has included both Chugach and ML&P gas in the reported figures for the Southcentral Power Project.

• Exhibit 5 – Wheeling, Economy Sales and Other Revenue: Exhibit 5 summarizes economy

sales transactions and other revenues that are applied as offsets to fuel and purchased power costs to be recovered by customers. For the acquisition, this exhibit has been modified to reflect ML&P economy transactions and water sales to Anchorage Water and Wastewater

4 ML&P currently has an interruptible gas contract with Hilcorp Alaska. Post-acquisition, Chugach’s purchases of gas from Hilcorp will be made under its existing contract approved by the Commission in Tariff Advice No. 481-8. 5 The methodology for determination of the BRU gas transfer price under Chugach’s ownership was filed with the Commission in Tariff Advice No. 494-8 on August 26, 2020.


Utility (“AWWU”). AWWU purchases water from Eklutna Lake under ML&P Rate Schedule 25 and Chugach will continue the existing credit methodology.

ML&P wheeling to GVEA is included in this exhibit, but in future filings, this category will become Chugach wheeling to GVEA. Economy sales transactions are shown on pages 2 through 5, and such transactions between Chugach and ML&P were removed from the exhibit.

• Exhibit 6 – Fuel and Purchased Power Expenses: Exhibit 6 presents a summary of monthly

fuel and purchased power costs for combined operations in the quarter. As explained below, the exhibit includes a fuel expense section and a purchased power expense section.

The fuel expense section identifies fuel purchased from each gas supplier and the generation facility where the fuel was used. For the acquisition, Chugach has added ML&P’s share of Cook Inlet Natural Gas Storage Alaska (“CINGSA”) (FSS and ISS), and fuel and transportation costs for Plant 1, Plant 2, and Plant 2A.

In the purchased power section, costs for energy transactions between Chugach and ML&P have been removed and the Bradley Lake and Intertie expenses were combined. Because Chugach treats the gas that it sends to other utilities for purchased generation as a purchased power expense, the gas sent to ML&P for power purchased has been added to plant 2A for each fuel source.

• Exhibit 7 – Balancing Account: Exhibit 7 provides the balancing account balances for fuel

and purchased power as of March 31, 2020, and projected balancing account balances through June 30, 2020. The actual and projected balancing account balances have been expanded to include the residential, small commercial, large commercial and lighting rate classes under CPCN 121.

• Exhibits 8 through 10 – Cost Assignment: Exhibits 8 through 10 allocate the fuel and

purchased power costs to the rate classes based on the allocators developed on page 1 of Exhibits 8, 9 and 10. Chugach has added the residential, small commercial, large commercial and lighting rate classes previously served under CPCN 121 to each exhibit. These exhibits also reflect the revenue offsets (economy margins, wheeling revenue, exchange revenues, etc.) of the combined system as presented on Exhibit 5. Chugach will update the loss factors to reflect the combined system with its annual update to the G&T and Distribution loss factors that will be submitted to the Commission as a tariff advice filing by March 15, 2021.

• Exhibit 11 – Gas in Storage: Exhibit 11 provides detailed information, over an 18-month

period, of the gas in storage at CINGSA. The calculations on this exhibit provide the cumulative totals for the volumes and value of gas in storage and the calculated weighted average cost of gas (“WACOG”) in storage.

Chugach does not have historical information regarding ML&P’s gas in storage. After the utilities have integrated, the fuel stored in CINGSA by both Chugach and ML&P will be combined and the new WACOG will be calculated. A new page has been added to this exhibit to provide volumes and average cost of gas in storage for ML&P on March 31, 2020.


• Exhibit 12 – Gas Volumes and rates by Power Plant (Projected and Actual): This is a new exhibit. This exhibit provides the detail for natural gas used at each power plant by fuel contract for both projected and actual usage that was formerly presented on Tariff Sheet Nos. 94, 95, and 95.5. Included in this exhibit is the detail of natural gas volumes and price by contract used to generate electricity, and projected to be used, for each power plant on the combined Chugach system (Plant 1, Plant 2 and Plant 2A have been added to this exhibit). This exhibit also includes fuel used, and projected to be used, at MEA’s Eklutna Generation Station (“EGS”) power plant under the Amended and Restated Operations Agreement for Power Pooling and Joint Dispatch.

• Reserved for November 2020 Filing - Exhibits 13 and 14: Exhibits 13 and 14 will be added

to Chugach’s fuel and purchased power rate adjustment filings beginning with the initial post-acquisition filing following close. The content of Exhibits 1 and 2 submitted to the Commission on August 26, 2020 under Tariff Advice No. 492-8 present the calculation of the rebate and balancing account activity for the North District Restricted Rate Reduction Account. These will be Exhibits 13 and 14 in future fuel purchased power rate adjustment filings, post-acquisition.

• Reserved for November 2020 Filing - Exhibits 15, 16 and 17: Exhibits 15 through 17 will

be added to Chugach’s fuel and purchased power rate adjustment filings beginning with the initial post-acquisition filing following close. The content of Exhibits 1 through 3 submitted to the Commission on August 26, 2020 under Tariff Advice No. 493-8 present the calculation of the surcharge and rebate and balancing account activity associated with the BRU Contributed Capital adjustment. These will be Exhibits 15 through 17 in future fuel purchased power rate adjustment filings, post-acquisition.

Explanation of Tariff Sheet Changes: Fuel and Purchased Power Cost Recovery Chugach has modified its tariff sheets to include actual and projected costs and revenues for combined operations. Each tariff sheet also includes text identifying the results as “Post-Acquisition,” and other necessary changes as described below. Chugach is not requesting Commission approval of any of the rates contained on these tariff sheets. Tariffs that contain rates for implementation will be submitted to the Commission by November 17, 2020 for rates effective January 1, 2021. The format of tariff sheets in this filing have been updated according to 3 AAC 48.330.

• Tariff Sheet No. 94: The projected costs and sales figures on this tariff sheet have been updated to reflect combined operations. Due to space limitations on this tariff sheet, the detail for projected natural gas for each power plant on the combined system has been moved to an exhibit and replaced with summarized projected gas expense by contract and class. The detail by power plant, which includes the addition of Plant 1, Plant 2, and Plant 2A, is now presented on Exhibit 12. Additional revisions to this tariff sheet include clarifying text changes. The sheet title now includes the words “Post Acquisition.” The line “Emergency Generator Fuel” has been revised to read, “Emergency Generator and Other Diesel Fuel,” and the line “CINGSA – FSS, ISS and Gas Withdrawn,” is now presented in two separate lines, “CINGSA – FSS/ISS Capacity and Withdrawal Fees” and “CINGSA – Gas Withdrawn.”


• Tariff Sheet No. 94.04: Changes to this tariff sheet includes text changes. The sheet title

now includes the words “Post Acquisition.” Additionally, the costs and sales figures now reflect combined operations.

• Tariff Sheet No. 94.05: Changes to this tariff sheet include text changes. The sheet title now includes the words “Post Acquisition.” Additionally, the costs and sales figures now reflect combined operations. Other text changes include the line that formerly read “e.3. Incremental Fire Island Wind Adjustment Factor: Predicted costs for the quarter beginning July 1, 2020,” has been broken into two lines. The first line now reads, “e.3. Incremental Fire Island Wind Adjustment Factor:” and the second line is, “Predicted costs for the quarter beginning July 1, 2020.” Additionally, the line that formerly read, “e.4. Summary of fuel and purchased power cost adjustment factors at G&T for rates effective July 1, 2020,” has been broken into two lines that read, “e.4. Summary of fuel and purchased power cost adjustment factors at G&T,” and “for rates effective July 1, 2020.”

• Tariff Sheet Nos. 94.1 and 94.1.1: The rates presented on these tariff sheets reflect

combined operations. Other changes to this tariff sheet include text changes. The sheet title now includes the words “Post Acquisition,” and “(b / c)” has been removed from the end of lines A. (d), B. (d) and C. (d) in section 5.

• Tariff Sheet No. 94.1.2: This new tariff sheet has been added to present the summary fuel, purchased power, Fire Island Wind Renewable Energy Adjustment Factor, Restricted Rate Reduction rebate, and BRU Contributed Capital rebate and surcharge rates for the North and South districts at primary and secondary delivery.

• Tariff Sheet No. 95: The costs and sales figures on this tariff sheet have been updated to reflect combined operations. Due to space limitations on this tariff sheet, the detail for actual natural gas for each power plant on the combined system has been moved to an exhibit and replaced with summarized actual gas expense by contract and class. The detail by power plant, which includes the addition of Plant 1, Plant 2, and Plant 2A, is now presented on Exhibit 12. Additionally, “Post Acquisition” has been added to the title of this sheet.

• Tariff Sheet and 95.04: The costs and sales figures on this tariff sheet have been updated to reflect combined operations. “Post Acquisition” has been added to the title of this sheet, and the line that formerly read “Wheeling Revenue,” has been revised to “Wheeling and Other Revenue.”

• Tariff Sheet and 95.05: Changes to this tariff sheet include text changes. The sheet title now includes the words “Post Acquisition.” Additionally, the costs and sales figures now reflect combined operations.

• Tariff Sheet No. 95.5: The costs and sales figures on this tariff sheet have been updated to reflect combined operations. This tariff sheet summarizes both actual recorded and


projected costs on a total and unit cost basis. Additionally, the detail for predicted and actual natural gas used, by power plant, has been relocated to Exhibit 12 and replaced with the summary totals of predicted and actual natural gas to be used by contract. The price per Mcf for BRU gas is a blended rate which is calculated based on the volumes and price for each district. Deleted lines include: the line “Gas Exchange Contributions (Tesoro and Furie)” and CINGSA – ISS Capacity and Withdrawal Fees.” A new line was added, “Emergency Generator and Diesel Fuel,” and the Text that previously read “CINGSA – FSS Capacity and Withdrawal Fess,” has been modified to read, “CINGSA – FSS and ISS Fees. Additionally, the sheet title has been revised to include the words, “Post Acquisition.”

• Tariff Sheet No. 97: Chugach has proposed the continued use of its established methodology to calculate avoided cost rates for purchases at primary and secondary voltages for customers in both the North District and South District. Chugach notes that the rates under CPCN 8 are available for non-utility generation containing a nameplate capacity of 200 kW or less, whereas the rates under CPCN 121 are available for non-utility generation of 100 kW or less. Post-acquisition, Chugach is proposing that the rate for purchases from qualified facilities be available for non-utility generation containing a nameplate capacity of 200 kW or less. The text change on this tariff sheet is the addition of the words, “Post Acquisition,” to the sheet title.

• Tariff Sheet Nos. 97.1.4, 97.5.2 and 97.6.1: The rates summarized on this sheet beginning January 1, 2021 include the combined operations for fuel, purchased power, and the Fire Island Wind Renewable Energy Adjustment Factor. New lines have been added to denote the transition point from separate entities to post acquisition results.

Section II: Transition to Unified Fuel and Purchased Power Rates Pursuant to Order 39, Chugach will submit its initial fuel and purchased power filing by November 17, 2020, for implementation of rates for actual billing on January 1, 2021. This first combined fuel and purchased power filing will serve primarily as a transitional filing and will include the tariff sheets and supporting exhibits for the RRR account rebate to North District customers, the BRU Contributed Capital surcharge to South District customers, the BRU Contributed Capital rebate to North District customers, and unified fuel and purchased power rates for the recovery of system fuel and purchased power costs. In mid-November 2020, Chugach will also submit its updated BRU gas transfer price. In recognition of the October 30, 2020 closing date, fuel and purchased power rates effective January 1, 2021 will be based on projected combined costs from October 30, 2020 through March 31, 2021 and estimated fuel and purchased power balancing account balances from Chugach and ML&P as of October 30, 2020. The balancing account balances will be reconciled with actual account balances once the costs and revenues through October 30, 2020 have been finalized. At a minimum, Chugach will include actual costs and revenues through September 30, 2020 under CPCN 8. Chugach has requested that ML&P provide actual costs and revenues through September 30, 2020. October 2020 balances for each utility will be estimated. Differences between estimated and actual costs and revenues will be factored into the balancing account in subsequent quarterly filing. The Chugach and ML&P balancing accounts will be combined and balances will be factored into the determination of unified system rates.

Commissioners Tariff Advice No. 495-8

August 26, 2020 of9

Following the mid-November 2020 filing, Chugach will submit subsequent fuel and purchased power rate adjustment filings on a quarterly basis consistent with its current operating tariff, which provides that the filings are to be submitted no later than 90-days after the end of each quarter.

Please contact Arthur Miller, Executive Vice President, Regulatory and External Affairs at 907-762-4 758 or arthur _ [email protected], if additional information is needed.

Sincerely,

CHU GACH ELECTRIC ASSOCIATION, INC.

-4tt~ t2:'~~D. Thibert

Chief Executive Officer P.O. Box 196300 Anchorage, Alaska 99519-6300 Telephone: 907-762-4517 Facsimile: 907-762-4514 lee_ [email protected]

Attachments

cc: Cory Borgeson, Interim Utility Manager, City of Seward John Burns, President and CEO, Golden Valley Electric Association, Inc. Anna Henderson, General Manager, Anchorage Municipal Light & Power Anthony Izzo, Chief Executive Officer, Matanuska Electric Association, Inc. Brad Janorschke, General Manager, Homer Electric Association, Inc. John Sims, President, ENSTAR Natural Gas Company Jon S. Dawson, for Providence Health & Services Robert J. Friedman for Federal Executive Agencies Curtis Thayer, Alaska Energy Authority Lew Craig, Regulatory Affairs & Public Advocacy Section (RAP A) Ethan Schutt, Alaska Native Tribal Consortium

RCA NO.: 8 161st

Sheet No. 94

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Sheet No. 94

FUEL AND PURCHASED POWER ADJUSTMENT FACTORS AT G&T POST ACQUISITION T

e.1. Fuel Adjustment Factor: Predicted Costs for the quarter beginning July 1, 2020

Total Retail Seward

Natural Gas Fuel Expense by Contract L

AIX Energy, LLC (4/2016-3/2024) $0 $0 $0 T

BRU $3,487,194 $3,392,545 $94,649

Cook Inlet Energy (2014-3/2023) $0 $0 $0

Furie (5/2017-33/2033) $0 $0 $0

Hilcorp Alaska, LLC (1/2015-3/2028) $12,985,458 $12,633,006 $352,452

Other Fuel Expenses

Emergency Generator and Other Diesel Fuel $0 $0 $0

CINGSA - FSS/ISS Capacity and Withdrawal Fees $1,488,033 $1,447,645 $40,388

CINGSA - Gas Withdrawn $40,590 $39,489 $1,102 T

Gas Transportation and Compression $1,886,733 $1,835,523 $51,210

Total Fuel and Transportation Expense $19,888,009 $19,348,208 $539,801

Less Credits

Economy Sales, Gas Exchange and Other Revenue ($104,100) ($101,275) ($2,825)

Wheeling Revenue ($487,602) ($474,367) ($13,235)

Subtotal ($591,702) ($575,642) ($16,060)

Net Fuel Expense $19,296,307 $18,772,566 $523,741

Generation & Purchases (MWh) 560,765.7 545,826.0 14,939.7

Cost per MWh at Generation $34.41 $34.39 $35.06

Projected Balances as of October 1, 2020 ($13,027,522) ($13,027,522) $0

Fuel Expense to be Recovered at G&T $6,268,785 $5,745,044 $523,741

Predicted Sales at G&T (MWh) 546,613.9 532,051.2 14,562.6

Fuel Adjustment Factor per kWh at G&T $0.01147 $0.01080 ----*

* Not calculated. Seward is billed for actual fuel and purchased power costs on a monthly basis.

L: The power plant natual gas usage by contract detail has been relocated to the new Exhibit 12,

and replaced with a summary of the natural gas predicted to be used by contract.

Tariff Advice No.: 495-8 Issued by:

Chugach Electric Association, Inc

P.O. Box 196300 Anchorage, Alaska 99519-6300

Chugach Electric Association, Inc.

Effective:

For Approval of Methodology Only

oae~o-.. CHUGACH

POWERING ALASKA'S FUTURE

RCA NO.: 8 41st Revision

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Revision


FUEL AND PURCHASED POWER ADJUSTMENT FACTORS AT G&T T

POST ACQUISITION (CONTINUED) T

e.2. Purchased Power Adjustment Factor: Predicted costs for the quarter beginning July 1, 2020

Description Total Retail Seward

Purchased Power Expense

Bradley Lake Purchases $3,532,789 $3,436,902 $95,887

Base FIW Renewable Resource Cost $1,002,980 $1,002,980 $0

Non-Utility Generation $0 $0 $0

Pooling Agreement - MEA $0 $0 $0

Other Purchases $129,257 $125,749 $3,508

Subtotal $4,665,026 $4,565,631 $99,395

Less Purchased Power Credits

Renewable Energy Certificates $0 $0 $0


Subtotal ($137,266) ($133,540) ($3,726)

Net Purchased Power Expense $4,527,760 $4,432,090 $95,670

Generation & Purchases (MWh) 560,766 545,826 14,940


Projected Balances as of October 1, 2020 $7,615,476 $7,615,476 $0

Purchased Power Expense to be Recovered $12,143,236 $12,047,566 $95,670


Purchased Power Adjustment Factor

per kWh at G&T $0.02222 $0.02264 ----*


Tariff Advice No.: 495-8 Issued by: Effective:

Chugach Electric Association, Inc


Sheet No. 94.04

Sheet No. 94.04


oae4!ft....._ CHUGACH·

POWERING AlASKA'S FUTURE

RCA NO.: 8 52nd

Revision Sheet No. 94.05

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Revision


FUEL AND PURCHASED POWER ADJUSTMENT FACTORS AT G&T T

POST ACQUISITION (CONTINUED)

e.3. Incremental Fire Island Wind Adjustment Factor:

Predicted costs for the quarter beginning July 1, 2020 T


Predicted FIW Purchases (MWh) 10,340.0 10,340.0 ----

Purchased Power Rate $97.00 $97.00 ----

Total FIW Purchased Power Cost $1,002,980 $1,002,980 ----

Chugach Avoided Energy Cost at G&T (MWh) $39.14 $39.14 ----

Estimated Cost Avoided Due to FIW Purchases $404,733 $404,733 ----

Fire Island Wind Cost Differential $598,247 $598,247 ----

Chugach Retail Generation & Purchases (MWh) 545,826.0 545,826.0 ----

Cost per MWh at Generation $1.10 $1.10 ----

Predicted Sales at G&T (MWh) 545,826.0 545,826.0 ----

FIW Adjustment Factor per kWh at G&T $0.00110 $0.00110 ----

e.4. Summary of fuel and purchased power cost adjustment factors at G&T T

for rates effective July 1, 2020 T

Fuel & Purch. Pwr Costs to be Recovered $24,422,314 $23,802,903 $619,410

Generation & Purchases (MWh) 560,765.7 545,826.0 14,939.7

Cost per MWh at Generation $43.55 $43.61 ----

Projected Balances as of October 1, 2020 ($5,412,046) ($5,412,046) $0

Total Costs Recovered at G&T $19,010,268 $18,390,857 $619,410


Fuel and Purchased Power Adjustment

Factor per kWh at G&T $0.03478 $0.03457 ---- *





Sheet No. 94.05


o,e• o ... CHUGACH·


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FUEL AND PURCHASED POWER COST ADJUSTMENT FACTORS T

POST ACQUISITION AT RETAIL DELIVERY: PRIMARY SERVICE T

e.5. Chugach retail fuel and purchased power adjustment factors for rates effective July 1, 2020

1. Total Chugach Retail Fuel and Purchased Power Cost Recovery $18,390,857

2. Retail Fuel Adjustment Factor per kWh at G&T $0.01080

3. Retail Purchased Power Adjustment Factor per kWh at G&T $0.02264

4. Fire Island Wind Adjustment Factor per kWh at G&T $0.00110

5. Chugach Retail Service at Primary Voltage

A. Fuel Adjustment Factor

a) Primary kWh Sales at G&T 65,486,962.0

b) Fuel Cost Recovery - Primary Voltage $707,259

c) Primary kWh Sales at Delivery 57,817,171.8

d) Fuel Adjustment Factor per kWh at Primary $0.01223 T

(Percent Primary Distribution Losses at G&T: 11.71%)

B. Purchased Power Adjustment Factor


b) Purchased Power Cost Recovery - Primary Voltage $1,482,625


d) Purchased Power Adj. Factor per kWh at Primary $0.02564 T

C. Fire Island Wind Renewable Energy Adjustment Factor


b) FIW Cost Differential - Primary Voltage $72,036


d) FIW Renewable Energy Adj. Factor per kWh at Primary $0.00125 T

D. Total Retail Service at Primary Voltage Delivery $0.03912





o,e♦.: a.-.

CHUGACH· POWERING ALASKA'S FUTURE ---------

RCA NO.: 8 37th

Revision Sheet No. 94.1.1

Canceling

36th




POST ACQUISITION AT RETAIL DELIVERY: SECONDARY SERVICE T

e.6. Chugach retail fuel and purchased power adjustment factors for rates effective July 1, 2020

6. Chugach Retail Service at Secondary Voltage

A. Fuel Adjustment Factor

a) Secondary kWh Sales at G&T 466,564,257.6

b) Fuel Cost Recovery - Secondary Voltage $5,038,894

c) Secondary kWh Sales at Delivery 408,852,527.8

d) Fuel Adjustment Factor per kWh at Secondary $0.01232 T

(Percent Secondary Distribution Losses at G&T: 12.37%)

B. Purchased Power Adjustment Factor

a) Predicted Secondary kWh Sales at G&T 466,564,257.6

b) Purchased Power Cost Recovery - Secondary Voltage $10,563,015

c) Predicted Secondary kWh Sales at Delivery 408,852,527.8

d) Purchased Power Adj. Factor per kWh at Secondary $0.02584 T

C. Fire Island Wind Renewable Energy Adjustment Factor

a) Predicted Secondary kWh Sales at G&T 466,564,257.6

b) FIW Cost Differential - Secondary Voltage $513,221

c) Predicted Secondary kWh Sales at Delivery 408,852,527.8

d) FIW Renewable Energy Adj. Factor per kWh at Secondary $0.00126 T

D. Total Retail Service at Secondary Voltage Delivery $0.03942





., . .. . !'A,..

CHUGACH· POWERINGALASKA'SFUTURE _______ _

RCA NO.: 8 Original Sheet No. 94.1.2

Canceling

Sheet No. 94.1.2


FUEL AND PURCHASED POWER COST ADJUSTMENT FACTORS POST ACQUISITION N

WITH BRU CONTRIBUTED CAPTIAL AND RRR REBATE ADJUSTMENTS

South District North District

Primary Secondary Primary Secondary

Fuel Rate $0.01223 $0.01232 $0.01223 $0.01232

Purchased Power Rate $0.02564 $0.02584 $0.02564 $0.02584

FIW Adj Factor $0.00125 $0.00126 $0.00125 $0.00126

Subtotal $0.03912 $0.03942 $0.03912 $0.03942

BRU Contributed Capital $0.01684 $0.01684 ($0.02004) ($0.02004)

Subtotal $0.05596 $0.05626 $0.01908 $0.01938

RRR Rebate --- ($0.01365) ($0.01365)

Total per kWh Rate $0.05596 $0.05626 $0.00542 $0.00572 N





., ......... CHUGACH·

POWERING ALASKA'S FU7URE

RCA NO.: 8 159th

Revision Sheet No. 95

Canceling

158th



FUEL AND PURCHASED POWER COST ADJUSTMENT FACTORS POST ACQUISITION T

f. 1. Actual fuel costs for the quarter ending March 31, 2020


Fuel Adjustment Factor Balance as of December 31, 2019 ($1,156,946) ($1,156,946) $0

Fuel Balance for Quarter Ending March 31, 2020 L

BRU $2,398,761 $2,334,273 $64,488 T

AIX Energy, LLC (4/2016-3/2024) $0 $0 $0



Furie (5/2017 - 3/2033) $0 $0 $0

Emergency Generator and Diesel Fuel $23,120 $22,506 $614

CINGSA - FSS/ISS Capacity and Withdrawal Fees $666,434 $648,427 $18,006

CINGSA - Gas Withdrawn $6,103,557 $5,940,133 $163,424 T


Adjustment $2,175 $2,115 $60


Less Credits

Economy Sales, Gas Exchange and Other Revenue ($468,608) ($456,119) ($12,488)



Subtotal ($996,359) ($969,716) ($26,643)

Net Fuel Expense $21,348,265 $20,774,901 $573,364



Total Fuel Cost Recovery $27,142,512 $26,569,147 $573,364

Quarter Balance ($5,794,246) ($5,794,247) $0







.,...,, .• _ .... CffUGACff·


RCA NO.: 8 39th


Canceling

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f.2. Actual purchased power costs for the quarter ending March 31, 2020


Purchased Power Adjustment Factor

Balance as of December 31, 2019 $2,745,038 $2,745,038 $0


Bradley Lake Purchases $2,888,462 $2,819,433 $69,029

FIW Renewable Resource Expense $1,243,198 $1,243,198 $0

Non-Utility Generation $713 $694 $19


Other Purchases $340,875 $331,719 $9,155

Subtotal $4,473,248 $4,395,045 $78,203


Renewable Energy Certificates $0 $0 $0

Wheeling and Other Revenue ($237,498) ($231,115) ($6,383) T

Subtotal ($237,498) ($231,115) ($6,383)

Net Purchased Power Expense $4,235,750 $4,163,930 $71,820



Purchased Power Cost Recovery $3,860,071 $3,788,251 $71,820

Quarter Balance $375,679 $375,679 $0

Tariff Advice No.: 495-8 Issued by: Issued by: Effective:




.,...., ..... CHUGACH·

POWERING ALASKA ·s FUrURE

RCA NO.: 8 49th


Canceling

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f.3. Summary of Actual Fuel and Purchased Power Cost Adjustment Factor Balances


Fuel and Purchased Power Balance

as of December 31, 2019 $1,588,092 $1,588,092 $0

Balance for Quarter Ending March 31, 2020

Fuel and Purchased Power Costs $25,584,016 $24,938,831 $645,185

Generation & Purchases (MWh) 631,206,428 614,654,169 16,552,259


Fuel and Purchased Power Recovery $31,002,583 $30,357,398 $645,185

Balance for Quarter Ended March 31, 2020 ($5,418,567) ($5,418,567) $0

Cumulative Balance at Quarter Ended

March 31, 2020 ($3,830,475) ($3,830,475) $0

Tariff Advice No.: 495-8 Issued by: Issued by: Effective:




............ CHUGACH·


RCA NO.: 8 97th


Canceling

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SUMMARY OF ACTUAL AND PROJECTED FUEL AND PURCHASED POWER COSTS

POST ACQUISITION T

March 2020 September 2020

Description Volume 1

Unit Cost Total Cost Volume Unit Cost Total Cost

Fuel Expense L

BRU 1,055,003 $2.27 $2,398,761 1,320,907 $2.64 $3,487,194 T

AIX Energy, LLC (4/2016-3/2024) 0 $0.00 $0 0 $0.00 $0

Hilcorp Alaska, LLC (1/2015-3/2028) 1,554,723 $7.46 $11,599,326 1,733,706 $7.49 $12,985,458

Cook Inlet Energy (2014-3/2023) 0 $0.00 $0 0 $0.00 $0

Furie (5/2017 - 3/2033) 0 $0.00 $0 0 $0.00 $0 T

CINGSA - FSS and ISS Fees ---- $0.00 $666,434 ---- $0.00 $1,488,033 D, T

CINGSA - Gas Withdrawn 785,526 $7.77 $6,103,557 5,224 $7.77 $40,590

Emergency Generator and Diesel Fuel ---- $0.00 $23,120 0 $0.00 $0 D, N

Gas Transportation and Compression 0 $0.00 $1,551,252 0 $0.00 $1,886,733

Adjustment 0 $0.00 $2,175 0 $0.00 $0

Subtotal 3,395,252 $6.58 $22,344,624 3,059,837 $6.50 $19,888,009


Bradley Lake Purchases, MWh 93,234 $30.98 $2,888,462 54,610 $64.69 $3,532,789

Total FIW Renewable Resource Exp. 12,816 $97.00 $1,243,198 10,340 $97.00 $1,002,980 T

Non-Utility Generation 12 $61.82 $713 12 $35.00 $420

Other Purchases, MWh 2,398 $142.15 $340,875 64,992 $1.98 $128,837

Subtotal 108,459 $41.24 $4,473,248 129,954 $35.90 $4,665,026

Total Fuel & Purch. Power Expense ---- ---- $26,817,872 ---- ---- $24,553,035



D: Deleted the lines include: the line entitled "Gas Exchange Contributions (Tesoro and Furie),

and "CINGSA - ISS Capacity and Withdrawal Fees."




Actual - Quarter Ended Projected - Quarter Ended

1 Fuel volumes from invoices.


.,....,, .• _ ... CHUGACH·

POWERING ALASKA ·s FUrURE ---------

RCA NO.: 8 142nd


Canceling

141st



POST ACQUISITION PURCHASE AND SALES RATES FOR QUALIFIED T

COGENERATION, SMALL POWER PRODUCTION, AND STANDBY/ BUYBACK FACILITIES

Available in all territory served by Chugach, or as required pursuant to contractual arrangements under

wholesale power sales agreement. Applicable to qualified cogeneration, small power production and

standby/buyback facilities of 200 kW or less. The type of service shall be single or three phase 60 hertz

at Chugach's standard voltages.

Chugach reserves the right to limit the number of retail customers receiving service under the terms of

this schedule to one per substation circuit. Chugach further reserves the right to reduce the buyback

rates for costs associated with the integration of the energy produced by the qualifying facility into

the Chugach system. Integration costs are project specific and determined through the completion of

an integration study completed by Chugach.

Monthly Rates

Power sales supplied by Chugach to the customer to meet its electric requirements will be priced at

the applicable rates. The rate paid by Chugach to the customer for kWh supplied by the customer to

Chugach is the average avoided cost calculated as follows:

1. Fuel and purchased power expense, excluding Bradley Lake and

Fire Island Wind, predicted for next quarter in the determination

of fuel and purchased power rates. $19,348,208

2. Non-fuel O&M expense $44,507

3. Balancing Account as of March 31, 2020 $14,744

4. Total Avoided Cost Included in Rate $19,407,459

5. kWh Sales at G&T predicted for next quarter: 495,815,690

6. Avoided Cost per kWh at G&T (L4) / L5 $0.03914

7. Avoided Cost at Retail Primary Voltage

a) Retail Primary kWh Sales at G&T 65,486,962

(Percent Primary Distribution Losses at G&T: 11.71%)

b) Retail Primary kWh Sales at Delivery 57,817,172

c) Avoided Costs per kWh at Retail Primary (L6 x L7a / L7b) $0.04433

8. Avoided Cost at Retail Secondary Voltage

a) Retail Secondary kWh Sales at G&T 466,564,258

(Percent Secondary Distribution Losses at G&T: 12.37%)

b) Retail Secondary kWh Sales at Delivery 408,852,528

c) Avoided Costs per kWh at Retail Secondary (L6 x L8a / L8b) $0.04467

These rates will change concurrently with fuel adjustment factor revisions and general rate revisions.


Chugach Electric Association, Inc.P.O. Box 196300 Anchorage, Alaska 99519-6300


Os♦♦$_ .._

CHUGACH· POWERING ALASKA ·s FUrURE

RCA NO.: 8 5th


Canceling

4th



FUEL AND PURCHASED POWER COST ADJUSTMENT FACTOR HISTORY

(SERVICE AT TRANSMISSION DELIVERY, RETAIL)

Chugach Retail (Rate per kWh)

Purchased FIW

For Rates Effective Total Fuel Power Adjustment Factor

October 1, 2019 $0.06178 $0.05868 $0.00132 $0.00178

November 1, 2019 $0.06172 $0.05862 $0.00132 $0.00178

January 1, 2020 $0.06692 $0.05799 $0.00655 $0.00238

April 1, 2020 $0.06679 $0.03845 $0.02657 $0.00177

July 1, 2020 $0.06085 $0.03874 $0.02031 $0.00180

Post Acquisition: N

October 1, 2020 $0.03454 $0.01080 $0.02264 $0.00110 N





.,..,.., ... _ .... CHUGACH·


RCA NO.: 8 5th


Canceling

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(SERVICE AT CHUGACH RETAIL DELIVERY)

Primary Voltage (Rate per kWh)

Purchased FIW T

For Rates Effective Total Fuel Power Adjustment Factor T

October 1, 2019 $0.06720 $0.06382 $0.00144 $0.00194

November 1, 2019 $0.06714 $0.06376 $0.00144 $0.00194

January 1, 2020 $0.06862 $0.05946 $0.00672 $0.00244

April 1, 2020 $0.06822 $0.03927 $0.02714 $0.00181

July 1, 2020 $0.06805 $0.04333 $0.02271 $0.00201

Post Acquisition: N

October 1, 2020 $0.03912 $0.01223 $0.02564 $0.00125 N





Os♦•& . .... CHUGACH·


RCA NO.: 8 5th


Canceling

4th




(SERVICE AT CHUGACH RETAIL SECONDARY VOLTAGE DELIVERY)

Secondary Voltage (Rate per kWh)

Purchased FIW T

For Rates Effective Total Fuel Power Adjustment Factor T

October 1, 2019 $0.06770 $0.06430 $0.00145 $0.00195

November 1, 2019 $0.06764 $0.06424 $0.00145 $0.00195

January 1, 2020 $0.06913 $0.05990 $0.00677 $0.00246

April 1, 2020 $0.06873 $0.03957 $0.02734 $0.00182

July 1, 2020 $0.06857 $0.04365 $0.02289 $0.00203

Post Acquisition: N

October 1, 2020 $0.03942 $0.01232 $0.02584 $0.00126 N





., ......... CHUGACH·


EXHIBIT 01


Fuel and Purchased Power Rate Adjustment Filing: Tariff Advice No. 495-8

Projected Fuel & Purchased Power Costs: July through September 2020

Projections for Quarter Jul-20 Aug-20 Sep-20

Description Qtr Expense $ / Mcf Mcf MWh Expense Mcf MWh Expense Mcf MWh Expense Mcf MWh

Beluga River Unit Natural Gas

1

Power Plants

Southcentral Power Project $446,456 $2.64 169,112 21,502 $121,319 45,954 5,852 $150,876 57,150 7,298 $174,261 66,008 8,352

Beluga Power Plant $0 $2.64 0 0 $0 0 0 $0 0 0 $0 0 0

IGT $0 $2.64 0 0 $0 0 0 $0 0 0 $0 0 0

Plant 1 $0 $2.64 0 0 $0 0 0 $0 0 0 $0 0 0

Plant 2 $0 $2.64 0 0 $0 0 0 $0 0 0 $0 0 0

Plant 2A $3,040,739 $2.64 1,151,795 222,361 $862,668 326,768 76,579 $1,027,385 389,161 76,189 $1,150,686 435,866 69,593

Subtotal $3,487,194 1,320,907 243,863 $983,986 372,722 82,431 $1,178,261 446,311 83,487 $1,324,947 501,874 77,945

Hilcorp Alaska, LLC (1/2015-3/2023)2

Southcentral Power Project $11,011,588 $7.49 1,470,172 187,800 $3,691,229 492,821 61,564 $3,724,388 497,248 61,579 $3,595,971 480,103 64,657


IGT Power Plant $0 $7.49 0 0 $0 0 0 $0 0 0 $0 0 0

Plant 1 $0 $7.49 0 0 $0 0 0 $0 0 0 $0 0 0

Plant 2 $0 $7.49 0 0 $0 0 0 $0 0 0 $0 0 0

Plant 2A $1,973,870 $7.49 263,534 0 $1,225,259 163,586 0 $733,945 97,990 0 $14,665 1,958 0

Subtotal $12,985,458 $7.49 1,733,706 187,800 $4,916,488 656,407 61,564 $4,458,333 595,238 61,579 $3,610,637 482,061 64,657

EGS (Pool)

Southcentral Power Project $0 $0.00 0 0 $0 0 0 $0 0 0 $0 0 0


IGT Power Plant $0 $0.00 0 0 $0 0 0 $0 0 0 $0 0 0

Plant 1 $0 $0.00 0 0 $0 0 0 $0 0 0 $0 0 0

Plant 2 $0 $0.00 0 0 $0 0 0 $0 0 0 $0 0 0

Plant 2A $0 $0.00 0 0 $0 0 0 $0 0 0 $0 0 0

Total Fuel from other Sources $0 0 0 $0 0 0 $0 0 0 $0 0 0

AIX



IGT Power Plant $0 $0.00 0 0 $0 0 0 $0 0 0 $0 0 0

Plant 1 $0 $0.00 0 0 $0 0 0 $0 0 0 $0 0 0

Plant 2 $0 $0.00 0 0 $0 0 0 $0 0 0 $0 0 0

Plant 2A $0 $0.00 0 0 $0 0 0 $0 0 0 $0 0 0

Subtotal $0 0 0 $0 0 0 $0 0 0 $0 0 0

Cook Inlet



IGT Power Plant $0 $0.00 0 0 $0 0 0 $0 0 0 $0 0 0

Plant 1 $0 $0.00 0 0 $0 0 0 $0 0 0 $0 0 0

Plant 2 $0 $0.00 0 0 $0 0 0 $0 0 0 $0 0 0

Plant 2A $0 $0.00 0 0 $0 0 0 $0 0 0 $0 0 0

Subtotal $0 0 0 $0 0 0 $0 0 0 $0 0 0

Exhibit 1

8/26/2020 12:06 PM

Exhibit 1

Page 1 of 4

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Furie



IGT Power Plant $0 $0.00 0 0 $0 0 0 $0 0 0 $0 0 0

Plant 1 $0 $0.00 0 0 $0 0 0 $0 0 0 $0 0 0

Plant 2 $0 $0.00 0 0 $0 0 0 $0 0 0 $0 0 0

Plant 2A $0 $0.00 0 0 $0 0 0 $0 0 0 $0 0 0

Total Fuel from other Sources $0 0 0 $0 0 0 $0 0 0 $0 0 0

Fuel Storage (CINGSA)

FSS - Res/Capacity Costs $1,382,283 ---- ---- ---- $460,761 ---- ---- $460,761 ---- ---- $460,761 ---- ----

ISS - Monthly Capacity Cost $105,750 $0 0 ---- $35,250 0 ---- $35,250 0 ---- $35,250 0 ----

Subtotal $1,488,033 $496,011 $496,011 $496,011

Fuel Withdrawn from Storage

CINGSA Gas Withdrawn $0 $7.7700 0 ---- $0 ---- $0 ---- $0 ----

Southcentral Power Project $40,590 ---- 5,224 17,753 $4,444 572 7,661 $33,178 4,270 2,286 $2,968 382 7,806

Beluga Power Plant $0 ---- 0 0 $0 0 0 $0 0 0 $0 0 0

IGT Power Plant $0 ---- 0 0 $0 0 0 $0 0 0 $0 0 0

Plant 1 $0 ---- 0 0 $0 0 0 $0 0 0 $0 0 0

Plant 2 $0 ---- 0 0 $0 0 0 $0 0 0 $0 0 0

Plant 2A $0 ---- 0 0 $0 0 0 $0 0 0 $0 0 0

Subtotal $40,590 $7.77 5,224 17,753 $4,444 572 7,661 $33,178 4,270 2,286 $2,968 382 7,806

Total CINGSA Cost $1,528,623 5,224 17,753 $500,455 572 7,661 $529,189 4,270 2,286 $498,979 382 7,806

Total Gas Supply to Power Plants (Firm and Non-Firm)

Direct from Suppliers $16,472,652 ---- 3,054,613 431,663 $5,900,475 1,029,129 143,995 $5,636,594 1,041,549 145,066 $4,935,584 983,935 142,602

Direct from CINGSA $1,528,623 ---- 5,224 17,753 $500,455 572 7,661 $529,189 4,270 2,286 $498,979 382 7,806

Total Fuel Expense $18,001,276 $5.88 3,059,837 449,416 $6,400,930 1,029,701 151,656 $6,165,783 1,045,819 147,352 $5,434,563 984,317 150,408

Gas Transportation (Firm and Non-Firm)

SPP, BPP and IGT $1,187,859 ---- ---- ---- $372,247 ---- ---- $408,710 ---- ---- $406,902 ---- ----

Plants 1, 2 and 2A $698,874 ---- ---- ---- $264,256 ---- ---- $239,390 ---- ---- $195,228 ---- ----

Subtotal $1,886,733 $636,503 $648,100 $602,130

Total Gas Transport Expense $1,886,733 $636,503 $648,100 $602,130

Total Fuel and Transport Exp. $19,888,009 $6.50 3,059,837 449,416 $7,037,433 1,029,701 151,656 $6,813,883 1,045,819 147,352 $6,036,693 984,317 150,408

Cost per MWh $44.25 $46.40 $46.24 $40.14

Less Fuel Credits

Economy Fuel Costs $0 ---- ---- ---- $0 ---- ---- $0 ---- ---- $0 ---- ----

Economy Margins $0 ---- ---- ---- $0 ---- ---- $0 ---- ---- $0 ---- ----

Wheeling Revenue ($487,602) ---- ---- ---- ($162,456) ---- ---- ($162,717) ---- ---- ($162,429) ---- ----

Pooling Agreement - MEA $0 ---- ---- ---- $0 ---- ---- $0 ---- ---- $0 ---- ----

Exchange Credits ($104,100) ---- ---- ---- ($34,700) ---- ---- ($34,700) ---- ---- ($34,700) ---- ----

Subtotal ($591,702) ($197,156) ($197,417) ($197,129)

Exhibit 1

8/26/2020 12:06 PM

Exhibit 1

Page 2 of 4

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Net Fuel & Transportation Costs $19,296,307 $6.31 3,059,837 449,416 $6,840,277 1,029,701 151,656 $6,616,466 1,045,819 147,352 $5,839,564 984,317 150,408

Cost per MWh $42.94 $45.10 $44.90 $38.82


Bradley Lake Purchases $3,532,789 ---- ---- 54,610 $1,189,408 ---- 19,071 $1,172,006 ---- 17,849 $1,171,375 ---- 17,690

Fire Island Wind $1,002,980 $97.00 ---- 10,340 $222,130 $97.00 2,290 $394,402 $97.00 4,066 $386,448 $97.00 3,984

Qualified Facility Purchases $420 ---- ---- 12 $105 3 $175 5 $140 4

GVEA $0 ---- 0 0 $0 0 0 $0 0 0 $0 0 0

HEA $0 ---- 0 0 $0 0 0 $0 0 0 $0 0 0

Pooling Agreement - MEA $2,726 ---- 262 30 $1,362 131 15 $1,364 131 15 $0 0 0

Subtotal $4,538,915 262 64,992 $1,413,005 131 21,379 $1,567,947 131 21,935 $1,557,963 0 21,678

Other Expenses

Alaska Intertie Expense $126,111 ---- ---- ---- $42,037 ---- ---- $42,037 ---- ---- $42,037 ---- ----

Subtotal $126,111 0 $42,037 0 $42,037 0 $42,037 0

Total Purchased Power Expense $4,665,026 ---- ---- 64,992 $1,455,042 ---- 21,379 $1,609,984 ---- 21,935 $1,600,000 ---- 21,678


Wheeling Revenue ($137,266) ---- ---- ---- ($45,733) ---- ---- ($45,807) ---- ---- ($45,726) ---- ----

Subtotal ($137,266) ---- ---- ---- ($45,733) ---- ---- ($45,807) ---- ---- ($45,726) ---- ----

Net Purchased Power Expense $4,527,760 ---- ---- 64,992 $1,409,309 ---- 21,379 $1,564,177 ---- 21,935 $1,554,274 ---- 21,678

Average at Generation ($/MWh) $69.7 $65.9 $71.3 $71.7

Net Fuel & PP Expense $23,824,067 ---- ---- 514,408 $8,249,586 ---- 173,035 $8,180,643 ---- 169,287 $7,393,838 ---- 172,086

Average at Generation ($/MWh) $46.3 $47.7 $48.3 $43.0

Plus:

Cooper Lake $240,978 ---- ---- 12,618 $80,326 ---- 5,037 $80,326 ---- 3,966 $80,326 ---- 3,615

Eklutna3

$59,421 ---- ---- 33,740 $19,867 ---- 10,833 $19,867 ---- 12,083 $19,687 ---- 10,823

Subtotal $59,421 ---- ---- 46,358 ---- ---- 15,870 ---- ---- 16,049 ---- ---- 14,438

Total MWh Requirements ---- ---- ---- 560,766 ---- ---- 188,906 ---- ---- 185,336 ---- ---- 186,5241 The BRU Gas Transfer Price is the combined system rate as filed in Tariff Advide No. 494-8.

2 Post-acquisition, Chugach will purchase gas from Hilcorp Alaksa, LLC, under the gas contract amendment included in Tariff Advice No. 481-8.

3 Additionally, ML&P’s share of projected Eklutna generation has been adjusted down by 36 percent in accordance with the Eklutna Purchased Power Agreement

Exhibit 1

8/26/2020 12:06 PM

Exhibit 1

Page 3 of 4

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South District Retail

1 North District Retail

2Wholesale

Alloc. System Retail Total Small Total Small

Factor Description Allocation Total Total South Residential General LGS-P LGS-S Lighting North Residential General LGS-P LGS-S Lighting Seward

EE_01 Energy - All Percent 100.00% 97.34% 51.54% 21.45% 5.24% 2.45% 22.31% 0.11% 45.80% 4.63% 3.38% 9.53% 28.15% 0.10% 2.66%

MWh - Generation 560,766 545,826 289,023 120,277 29,360 13,713 125,084 589 256,803 25,942 18,938 53,469 157,875 579 14,940

Losses - G&T 1.0259 1.0259 1.0259 1.0259 1.0259 1.0259 1.0259 1.0259 1.0259 1.0259 1.0259 1.0259 1.0259 1.0259 1.0259

MWh - Transmission 546,614 532,051 281,729 117,241 28,619 13,367 121,927 575 250,322 25,287 18,460 52,120 153,891 564 14,563

Losses - Distribution 62,313 62,313 32,996 13,731 3,352 1,566 14,280 67 29,318 2,962 2,162 6,104 18,024 66 ----

MWh - Primary1

469,738 469,738 248,733 103,510 25,267 11,802 107,647 507 221,004 22,325 16,298 46,015 135,868 498 ----

Losses - Pri to Sec 3,068 3,068 1,765 771 188 ---- 802 4 1,303 166 121 ---- 1,012 4 ----

MWh - Secondary 408,853 408,853 235,167 102,739 25,079 ---- 106,845 503 173,686 22,159 16,177 ---- 134,856 494 ----

EE_02 Energy - Retail Percent 100.00% 100.00% 52.95% 22.04% 5.38% 2.51% 22.92% 0.11% 47.05% 4.75% 3.47% 9.80% 28.92% 0.11% ----

MWh 545,826 545,826 289,023 120,277 29,360 13,713 125,084 589 256,803 25,942 18,938 53,469 157,875 579 ----

EE_03 Fire Island Wind Percent 100.00% 100.00% 52.95% 22.04% 5.38% 2.51% 22.92% 0.11% 47.05% 4.75% 3.47% 9.80% 28.92% 0.11% ----

Generation MWh 10,340 10,340 5,475 2,278 556 260 2,370 11 4,865 491 359 1,013 2,991 11 ----

EE_04 Energy, Excl. Percent 100.00% 97.29% 51.51% 21.44% 5.23% 2.44% 22.29% 0.11% 45.77% 4.62% 3.38% 9.53% 28.14% 0.10% 2.71%

Fire Island Wind MWh 550,426 535,486 283,548 117,998 28,804 13,454 122,714 578 251,938 25,450 18,579 52,456 154,885 568 14,940

1 Chugach losses between primary and secondary delivery are 0.7504 percent as measured from secondary (Docket U-06-134). Chugach used its line loss factors for ML&P's sales data in this filing

.

Chugach will update the combined system loss factors with its Generation and Transmission Loss Factor update to be filed in June 2020.2 ML&P sales by rate class projections were derived by taking the total projected sales from their COPA filing and allocating this amount across the rate classes based on the percentage of actual sales

reported by rate class. Going forward, these projections will be based on Chugach’s forecast for sales from the North and South Districts.

Losses: Total Percent

Retail 79,156 14.5%

Transmission 377 2.5%

System 79,533 14.2%

Exhibit 1

8/26/2020 12:06 PM

Exhibit 1

Page 4 of 4

EXHIBIT 02



Chugach Retail, Wholesale and Economy MWh Sales and System Losses

Description Apr-19 May-19 Jun-19 Jul-19 Aug-19 Sep-19 Oct-19 Nov-19 Dec-19 Jan-20 Feb-20 Mar-20 Total

South Retail

Residential (101) 36,346 34,607 32,069 34,923 33,917 34,186 38,621 41,149 48,943 55,346 44,356 45,498 479,960

Small General (201) 8,648 8,324 7,859 8,323 8,492 8,138 9,516 9,941 11,104 12,329 10,620 10,389 113,683

LGS-Sec > 1000 kW (308) 1,420 2,020 1,839 1,912 1,978 2,106 1,348 1,952 1,540 1,941 1,707 1,878 21,640

LGS-Sec < 1000 kW (301) 31,542 32,100 31,826 34,650 34,909 31,797 32,854 32,031 34,297 36,484 32,463 32,207 397,161

LGS-Sec Standby (311) 15 17 75 156 37 42 51 93 135 333 145 110 1,209

LGS-Pri > 1000 kW (306) 1,237 1,319 1,259 1,298 1,261 1,314 1,338 1,179 1,256 1,323 1,157 1,229 15,169

LGS-Pri < 1000 kW (307, 312) 800 835 924 1,040 999 827 835 821 901 988 851 888 10,708

LGS-Pri < 1000 kW (304) 1,786 1,865 2,020 2,275 2,405 2,052 1,980 1,940 2,030 2,016 1,861 1,919 24,149

LGS-Pri > 1000 kW (310) 234 158 142 143 154 145 158 340 844 875 427 349 3,968

Lighting 165 120 88 106 154 194 259 298 338 310 242 200 2,473

South Retail Subtotal 82,193 81,365 78,101 84,826 84,306 80,799 86,960 89,745 101,387 111,945 93,828 94,666 1,070,120

North Retail

151 - 44000 - Residential R/11 9,462 8,778 8,113 8,259 8,434 8,382 8,855 9,737 10,065 12,123 13,505 11,609 117,323

251 - 44210 - Small Comm R/21 6,886 6,286 5,899 5,981 6,156 6,169 6,089 6,994 6,954 7,732 8,753 7,808 81,708

351 - 44230 - LC Secondary R/22 40,577 39,716 41,355 45,079 44,835 43,055 40,782 41,050 38,751 40,586 45,494 42,193 503,472

352 - 44242 - LC Primary R/23 5,305 5,327 5,667 6,004 6,080 3,896 7,414 5,379 5,341 5,311 5,914 3,861 65,498

361 - 44250 - Intrptble Sec R/27 0 17 170 179 0 202 0 230 0 0 0 0 798

381 - 44253 - Ssnl Svc Sec R/31 3 11 42 69 63 44 3 1 2 2 2 2 244

382 - 44253 - Ssnl Svc Sec R/32 10 21 19 29 64 77 70 66 11 11 15 12 404

383 - 44253 - Ssnl Svc Sec R/33 4 4 5 12 15 16 10 7 5 5 5 4 91

385 - 44254 - Ssnl Svc Prim R/35 1 1 3 16 17 17 8 1 0 0 0 0 63

R/700 FORT RICHARDSON 2,338 2,077 2,784 1,737 1,394 1,372 1,939 2,691 3,204 3,328 2,840 2,797 28,500

R/750,770,780 ELMENDORF 9,694 8,894 8,691 8,574 8,889 8,924 9,275 10,102 10,348 11,154 10,845 9,891 115,281

501 - 44400 - MLP Street Lights 397 260 194 134 158 268 342 439 498 351 294 237 3,571

North Retail Subtotal 74,678 71,393 72,942 76,074 76,104 72,423 74,787 76,696 75,176 80,601 87,668 78,412 916,953

Wholesale

SES 4,580 4,856 4,646 5,075 5,261 4,463 4,348 4,483 4,854 5,887 5,032 5,205 58,689

Subtotal 4,580 4,856 4,646 5,075 5,261 4,463 4,348 4,483 4,854 5,887 5,032 5,205 58,689

Exhibit 2 thru 5

8/26/2020 12:06 PM

Exhibit 02

Page 1 of 2



Chugach Retail, Wholesale and Economy MWh Sales and System Losses


Economy Sales

GVEA 22,654 21,601 9,387 1,309 2,251 0 4,801 7,639 6,153 3,172 673 0 79,640

HEA / AEEC 113 67 195 0 0 0 0 0 0 0 0 0 375

MEA (Pooling Agreement) 0 0 0 0 0 0 0 0 0 0 0 0 0

MEA (Economy) 4,279 3,862 3,255 5,035 4,420 899 5,780 4,102 727 4,003 3,191 1,443 40,996

Subtotal 27,046 25,530 12,837 6,344 6,671 899 10,581 11,741 6,880 7,175 3,864 1,443 121,011

System Total 188,496 183,145 168,526 172,319 172,342 158,583 176,676 182,664 188,297 205,608 190,392 179,726 2,166,774

Calculation of Retail Loss Factors based on Twelve Months' Activity

Retail

Description MWh Source Description MWh Loss Factor Source

Net MWh Generation & Purchased Power 2,304,962.5 Exhibit 3, page 2 Retail MWh Sales at Generation 2,244,713.8 2,304,962.5 - 60,248.7

Wholesale MWh Sales 58,688.7 Wholesale Delivery/1000 Retail MWh Sales 1,987,073.6 Retail Delivery

Calendar Adjustment1

66,399.1 SCADA Data Adjustment

G&T Loss Factor (at Delivery) 2.6580% Tariff Sheet 103.5 Losses 191,241.1 2,244,713.8 - 1,987,073.6

Wholesale G&T Losses 1,560 58,688.7 * 2.66% Retail Loss Factor based at Delivery 12.97% 191,241.1 / 1,987,073.6

Wholesale MWh Sales at Generation 60,248.7 58,688.7 + 1,559.9 Retail Loss Factor at Generation 8.52% 191,241.1 / 2,244,713.8

1 ML&P does not adjust sales for calendar periods. This adjustment is a true-up between reported sales and SCADA data.

Exhibit 2 thru 5

8/26/2020 12:06 PM

Exhibit 02

Page 2 of 2

EXHIBIT 03



Generation & Purchased Power (MWh)


Beluga Power Plant

Unit No. 1 0.0 1.6 43.2 114.8 64.5 163.0 108.1 0.0 0.0 0.0 69.8 206.9 771.8

Unit No. 2 26.9 0.0 0.0 0.8 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 27.7

Unit No. 3 3,509.6 0.0 4,135.0 6,197.0 13.3 1,312.4 108.1 8,917.4 6,058.9 3,284.0 582.9 914.5 35,033.1

Unit No. 5 691.2 0.0 188.4 897.7 3,546.3 2,051.6 12,392.7 3,499.3 0.0 0.0 0.0 0.0 23,267.3

Unit No. 6 0.0 0.0 0.0 78.4 0.0 0.0 0.0 0.0 0.0 0.0 0.0 4.9 83.4

Unit No. 7 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 70.1 0.0 0.0 5.8 75.9

Unit No. 8 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Gross Generation 4,227.7 1.6 4,366.6 7,288.8 3,624.1 3,527.0 12,609.0 12,416.6 6,128.9 3,284.0 652.7 1,132.1 59,259.1

Station Service (508.8) (364.8) (259.2) (345.6) (220.8) (264.0) (470.4) (638.4) (595.2) (696.0) (624.0) (652.8) (5,640.0)

Net Generation 3,718.9 (363.2) 4,107.4 6,943.2 3,403.3 3,263.0 12,138.6 11,778.2 5,533.7 2,588.0 28.7 479.3 53,619.1

Southcentral Power Project

Unit No. 10 20,720.2 25,645.7 23,424.5 23,608.7 24,766.3 24,627.7 21,373.3 23,103.2 26,418.4 25,191.8 23,885.6 25,526.8 288,292.3

Unit No. 11 22,024.2 25,193.0 23,756.6 25,120.0 24,693.2 25,443.5 25,695.3 20,692.1 29,997.8 30,776.5 27,106.1 27,771.7 308,270.0

Unit No. 12 22,943.5 25,312.2 23,837.0 24,849.1 24,944.6 24,268.5 19,989.3 28,033.9 29,895.5 29,674.6 26,965.3 27,594.1 308,307.6

Unit No. 13 20,694.2 25,330.0 23,626.6 24,924.2 24,487.8 25,258.7 23,708.0 27,707.4 29,820.6 30,561.6 26,896.9 27,538.8 310,554.8

Gross Generation 86,382.1 101,480.9 94,644.6 98,501.9 98,891.9 99,598.4 90,766.0 99,536.7 116,132.2 116,204.6 104,854.0 108,431.3 1,215,424.6

Station Service (2,524.8) (2,865.0) (2,860.5) (2,978.6) (3,027.1) (2,886.5) (2,724.5) (2,773.6) (3,021.4) (3,027.9) (2,815.1) (2,950.2) (34,455.2)

Net Generation 83,857.3 98,615.9 91,784.1 95,523.3 95,864.8 96,711.9 88,041.5 96,763.1 113,110.8 113,176.7 102,038.9 105,481.1 1,180,969.4

IGT

Unit No. 1 0.0 3.8 0.0 0.0 220.6 0.0 202.4 241.4 23.8 39.0 0.0 215.7 946.7

Unit No. 2 0.0 3.3 0.0 0.0 0.0 0.0 56.7 74.5 0.0 0.0 0.0 104.6 239.2

Gross Generation 0.0 7.2 0.0 0.0 220.6 0.0 259.1 315.9 23.8 39.0 0.0 320.4 1,185.9

Station Service (56.2) (56.2) (3.4) (57.6) (42.6) (45.6) (66.3) (81.6) (48.6) (142.5) (98.1) (97.8) (796.6)

Net Generation (56.2) (49.1) (3.4) (57.6) 178.0 (45.6) 192.8 234.3 (24.8) (103.5) (98.1) 222.6 389.3

Cooper Lake

Unit No. 1 1,008.7 0.0 0.0 0.0 0.0 0.0 0.0 10.1 2,854.1 2,072.0 711.1 4,531.7 11,187.6

Unit No. 2 2,997.6 859.5 5,251.5 6,619.6 555.8 4,517.4 4,477.6 3,084.2 2,392.1 3,993.3 4,537.6 4,457.5 43,743.6

Gross Generation 4,006.3 859.5 5,251.5 6,619.6 555.8 4,517.4 4,477.6 3,094.3 5,246.2 6,065.3 5,248.7 8,989.2 54,931.3

Station Service (102.6) (79.0) (60.0) (61.5) (63.9) (60.3) (99.2) (15.1) (208.0) (93.4) (67.4) (99.5) (1,009.6)

Net Generation 3,903.7 780.5 5,191.5 6,558.1 492.0 4,457.1 4,378.4 3,079.3 5,038.2 5,971.9 5,181.2 8,889.7 53,921.6

Exhibit 2 thru 5

8/26/2020 12:06 PM

Exhibit 03

Page 1 of 3





Eklutna

Eklutna Hydro 28,898.4 27,324.3 25,759.7 15,678.1 17,987.9 18,347.4 19,521.9 18,952.9 18,675.5 20,234.7 18,301.8 20,044.6 249,727.3

Gross Generation 28,898.4 27,324.3 25,759.7 15,678.1 17,987.9 18,347.4 19,521.9 18,952.9 18,675.5 20,234.7 18,301.8 20,044.6 249,727.3

Station Service1

(13.1) (13.0) (12.2) (13.2) (13.1) (13.8) (16.5) (16.8) (19.0) (23.3) (18.8) (18.5) (191.1)

Net Generation 28,885.3 27,311.4 25,747.5 15,665.0 17,974.8 18,333.6 19,505.4 18,936.2 18,656.4 20,211.5 18,283.0 20,026.1 249,536.2

Plant 1

Unit No. 3 2,100.0 470.7 711.1 1,183.9 536.3 1,968.1 1,602.2 264.9 111.0 262.9 201.7 850.2 10,263.0

Unit No. 4 1,201.5 162.2 2.2 33.6 8.3 13.7 294.3 0.0 1.3 67.2 0.0 0.0 1,784.3

Gross Generation 3,301.5 632.9 713.3 1,217.5 544.6 1,981.8 1,896.5 264.9 112.3 330.1 201.7 850.2 12,047.3

Station Service (73.9) (43.8) (37.6) (63.6) (47.7) (90.0) (1,181.3) (34.2) (41.4) (45.1) (36.6) (49.9) (1,745.0)

Net Generation 3,227.6 589.1 675.7 1,153.9 496.9 1,891.8 715.2 230.7 70.9 285.0 165.1 800.3 10,302.3

Plant 2

Unit No. 7 217.5 1,791.1 0.0 0.0 11.1 441.0 350.7 416.3 224.4 861.6 67.4 3,765.0 8,146.0

Unit No. 8 0.0 0.0 0.0 0.0 28.0 0.0 28.5 219.3 10.5 77.4 0.0 0.0 363.6

Gross Generation 217.5 1,791.1 0.0 0.0 39.1 441.0 379.2 635.6 234.9 939.0 67.4 3,765.0 8,509.6

Station Service (550.9) (572.0) (527.0) (573.8) (601.8) (596.8) (381.0) (349.0) (399.8) (423.9) (282.6) (386.7) (5,645.3)

Net Generation (333.5) 1,219.1 (527.0) (573.8) (562.7) (155.8) (1.9) 286.6 (164.9) 515.1 (215.3) 3,378.2 2,864.3

Plant 2A

Unit No. 9 22,393.9 15,951.0 16,071.8 22,052.9 14,703.7 11,845.5 23,835.4 20,100.1 16,594.5 23,717.1 20,906.3 10,698.4 218,870.6

Unit No. 10 25,312.3 18,735.3 16,500.7 14,292.6 24,146.1 23,003.7 22,099.4 23,535.8 21,526.2 22,801.1 12,143.6 11,426.0 235,522.7

Unit No. 11 15,571.0 10,903.5 10,031.9 10,923.3 11,500.3 4,287.5 14,125.3 13,767.6 11,379.6 14,665.5 9,019.8 5,388.7 131,564.0

Gross Generation 63,277.2 45,589.8 42,604.5 47,268.8 50,350.0 39,136.7 60,060.1 57,403.5 49,500.2 61,183.7 42,069.7 27,513.1 585,957.3

Station Service (1,791.6) (1,661.2) (1,668.3) (1,793.5) (1,824.6) (1,264.1) (1,810.0) (1,777.4) (1,778.4) (2,222.3) (1,553.9) (1,464.8) (20,610.0)

Net Generation 61,485.6 43,928.6 40,936.1 45,475.3 48,525.4 37,872.6 58,250.1 55,626.1 47,721.8 58,961.4 40,515.9 26,048.3 565,347.3

Total Central Station Generation

Gross Generation 190,310.6 177,687.3 173,340.1 176,574.8 172,213.9 167,549.7 189,969.3 192,620.5 196,054.0 208,280.4 171,395.9 171,045.9 2,187,042.4

Station Service (5,621.8) (5,654.9) (5,428.2) (5,887.3) (5,841.5) (5,221.0) (6,749.1) (5,686.0) (6,111.8) (6,674.3) (5,496.5) (5,720.2) (70,092.8)

Net Generation 184,688.8 172,032.3 167,912.0 170,687.4 166,372.4 162,328.6 183,220.1 186,934.5 189,942.2 201,606.1 165,899.5 165,325.7 2,116,949.6

Exhibit 2 thru 5

8/26/2020 12:06 PM

Exhibit 03

Page 2 of 3





Purchased Power

Bradley Lake

Bradley Lake 15,036.0 31,774.0 21,602.0 21,716.0 20,638.0 0.0 0.0 0.0 13,062.0 31,688.0 30,288.0 29,826.0 215,630.0

Bradley Lake - SES 365.5 517.3 320.9 303.9 314.5 35.6 24.8 0.0 298.1 492.2 484.0 455.3 3,612.1

Total 15,401.5 32,291.3 21,922.9 22,019.9 20,952.5 35.6 24.8 0.0 13,360.1 32,180.2 30,772.0 30,281.3 219,242.1

Other Purchases

Chugach (1.0) 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 (1.0)

GVEA 373.0 7.0 65.0 242.0 41.0 6,121.0 3,453.0 5,206.0 3,972.0 851.0 868.0 679.0 21,878.0

HEA / AEEC 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

MEA (incl. Power Pool) 373.0 7.0 65.0 242.0 41.0 6,121.0 3,453.0 5,206.0 3,972.0 851.0 868.0 679.0 21,878.0

Total 745.0 14.0 130.0 484.0 82.0 12,242.0 6,906.0 10,412.0 7,944.0 1,702.0 1,736.0 1,358.0 43,755.0

Qualified Facilities (QF)

Fire Island Wind 3,676.8 5,132.9 1,458.7 1,321.7 1,203.2 2,533.2 5,145.3 6,211.3 6,122.7 4,397.8 5,161.3 3,257.1 45,622.0

Other QF 96.5 84.4 39.8 28.9 59.0 78.5 2.1 1.2 3.4 2.6 4.6 4.3 405.2

Total 3,773.3 5,217.3 1,498.4 1,350.6 1,262.2 2,611.6 5,147.4 6,212.5 6,126.1 4,400.4 5,165.9 3,261.4 46,027.2

Total Purchased Power 19,919.8 37,522.6 23,551.3 23,854.5 22,296.7 14,889.2 12,078.3 16,624.5 27,430.2 38,282.6 37,673.9 34,900.7 309,024.3

Total Generation and

Purchased Power 204,608.6 209,554.9 191,463.3 194,541.9 188,669.1 177,217.8 195,298.4 203,559.0 217,372.4 239,888.7 203,573.4 200,226.4 2,425,973.9

Less Economy Sales2 (27,046.0) (25,530.4) (12,837.0) (6,344.0) (6,671.0) (899.0) (10,581.0) (11,741.0) (6,880.0) (7,175.0) (3,864.0) (1,443.0) (121,011.4)

Total Net Generation

and Purchased Power 177,562.6 184,024.5 178,626.3 188,197.9 181,998.1 176,318.8 184,717.4 191,818.0 210,492.4 232,713.7 199,709.4 198,783.4 2,304,962.5

1 The station service presented is only Chugach’s portion because ML&P data does not break out station service for Eklutna Hydro generation.

2 Economy transactions between Chugach and ML&P have been removed; however, the MWh's are included to provide a representative total for system generation

Exhibit 2 thru 5

8/26/2020 12:06 PM

Exhibit 03

Page 3 of 3

EXHIBIT 04



Summary of Natural Gas (Mcf) Usage

Generating Unit Apr-19 May-19 Jun-19 Jul-19 Aug-19 Sep-19 Oct-19 Nov-19 Dec-19 Jan-20 Feb-20 Mar-20 Totals


Unit No. 11 216,516 253,415 241,659 255,478 252,788 255,444 254,304 202,076 287,887 294,907 262,235 271,638 3,048,348

Unit No. 12 225,930 255,001 242,682 253,900 255,533 245,499 197,496 272,752 286,528 283,429 260,728 270,364 3,049,841

Unit No. 13 205,596 254,716 241,647 255,824 252,560 255,964 236,748 272,143 288,694 292,746 260,527 270,439 3,087,604

Subtotal 648,042 763,132 725,988 765,201 760,881 756,906 688,548 746,972 863,110 871,083 783,489 812,440 9,185,792

Beluga Power Plant 1

Unit No. 1 0 59 945 2,880 3,798 4,144 2,497 0 0 0 1,455 5,152 20,930

Unit No. 2 893 0 0 36 0 0 0 0 0 0 0 0 929

Unit No. 3 52,405 0 70,976 102,886 671 21,745 2,445 143,079 100,722 56,392 12,534 15,515 579,369

Unit No. 5 0 0 0 0 0 0 0 0 0 0 0 0 0

Unit No. 6 11,054 0 3,333 16,392 74,640 36,239 194,760 55,842 0 0 0 1 392,261

Unit No. 7 0 0 0 0 0 0 0 0 0 0 0 261 261

Station Service 1

10,990 10 12,851 21,146 0 0 0 0 0 56 583 276 45,911

Subtotal 75,342 69 88,104 143,339 79,108 62,129 199,703 198,922 100,722 56,448 14,572 21,205 1,039,661

IGT

Unit No. 1 0 113 0 0 12 0 4,336 4,353 525 618 0 3,935 13,891

Unit No. 2 0 1 0 0 11 35 857 1,330 0 0 0 1,361 3,596

Subtotal 0 114 0 0 24 35 5,193 5,683 525 618 0 5,296 17,487

Plant 1

Unit No. 3 23,815 6,028 8,732 14,753 7,484 26,462 21,560 3,823 1,654 2,941 3,050 9,321 129,623

Unit No. 4 20,103 3,056 18 950 301 176 7,067 0 0 146 0 0 31,817

Subtotal 43,918 9,084 8,750 15,703 7,785 26,638 28,627 3,823 1,654 3,087 3,050 9,321 161,440

Plant 2

Unit No. 7 3,136 24,197 0 0 240 6,431 4,574 5,810 815 12,495 919 59,472 118,089

Unit No. 8 2 0 0 0 779 125 717 2,938 338 1,331 0 1 6,231

Subtotal 3,138 24,197 0 0 1,019 6,556 5,291 8,748 1,153 13,826 919 59,473 124,320

Plant 2A

Unit No. 9 231,003 170,149 173,413 235,957 154,918 129,559 250,901 213,670 179,782 252,578 226,728 118,202 2,336,860

Unit No. 10 261,279 19,754 184,040 152,948 254,561 241,770 223,540 245,821 229,517 238,151 134,843 127,756 2,313,980

Subtotal 492,282 189,903 357,453 388,905 409,479 371,329 474,441 459,491 409,299 490,729 361,571 245,958 4,650,840

Total System Natural Gas 1,262,722 986,498 1,180,296 1,313,148 1,258,296 1,223,593 1,401,802 1,423,638 1,376,462 1,435,790 1,163,601 1,153,693 15,179,541 1 Includes fuel for pre-heating and waste incineration.

Exhibit 2 thru 5

8/26/2020 12:07 PM

Exhibit 04

Page 1 of 1

EXHIBIT 05



Summary of Economy Energy Sales, Wheeling Transactions, and other Revenues

(Supporting Documents Provided in Attachment A)

Fuel and Purchased Power Revenue Offsets: JANUARY - MARCH, 2020

January 2020 February 2020 March 2020 Quarter Total

Description kWh Revenue kWh Revenue kWh Revenue kWh Revenue

Bradley Lake Wheeling

Chugach to GVEA 12,698,000 $113,012 12,820,000 $114,098 8,748,000 $77,857 34,266,000 $304,967

Chugach to MEA 5,298,000 $47,152 4,157,000 $36,997 3,987,000 $35,484 13,442,000 $119,634

HEA to GVEA 0 $0 0 $0 0 $0 0 $0

Subtotal 17,996,000 $160,164 $16,977,000 $151,095 $12,735,000 $113,342 $47,708,000 $424,601

Other Wheeling

Chugach to GVEA 3,132,000 $39,338 663,000 $8,327 0 $0 3,795,000 $47,665

Chugach to HEA 0 $0 0 $0 0 $0 0 $0

MEA to GVEA 57,000 $716 531,000 $6,669 0 $0 588,000 $7,385

Chugach to MEA (Wheeling & Power Pool) 3,982,000 $50,014 3,729,000 $46,836 4,513,000 $56,683 12,224,000 $153,533

Subtotal 7,171,000 $90,068 $4,923,000 $61,833 $4,513,000 $56,683 $16,607,000 $208,584

Total Wheeling 25,167,000 $250,232 21,900,000 $212,928 17,248,000 $170,025 64,315,000 $633,185

Total Economy Sales Revenue 7,175,000 $275,858 3,864,000 $75,749 1,443,000 $11,031 12,482,000 $362,638

Purchased Power Offset - Other Revenue

Renewable Energy Certificates $0 $0 $0 $0

AWWU (Eklutna Water)1

$44,791 $40,423 $46,849 $132,064

Subtotal $44,791 $40,423 $46,849 $132,064

Fuel Offset - Exchange Revenue

Tesoro Exchange Credits $28,530 $27,053 $27,344 $82,927

KBPL Exchange Credits $23,042 $0 $0 $23,042

Subtotal $51,572 $27,053 $27,344 $105,969

Total Fuel & Purchased Power Offsets $622,453 $356,154 $255,249 $1,233,856

1Calculation of Revenue offset for AWWU water sales

Water Sales converted to kWh 1,320,499 1,191,722 1,381,168 3,893,389

at Primary Delivery $0.03392 $0.03392 $0.03392

Water Sales Revenue $44,791 $40,423 $46,849 $132,0641 Rate at primary delivery is the rate that was in effect first quarter 2020. Alaska Water and Waste Utility (AWWU) purchases water from Eklutna Lake through ML&P under Schedule 25 of ML&P's Tariff.

The calculation of the revenues from the sale of water to AWWU, presented on page 1 of Exhibit 5, is based on water sales converted to kWh’s multiplied by the primary fuel rate in effect. The calculation

methodology is the same methodology used in ML&P’s COPA filing on Attachment No. 4.1 on lines 24 through 26

Exhibit 2 thru 5

8/26/2020 1:26 PM

Exhibit 5

Page 1 of 3

I I I I



Summary of Economy Energy Sales & Wheeling Transactions


ECONOMY ENERGY SALES: JANUARY - MARCH, 2020

Total Fuel Natural Gas Variable O&M Economy

Description kWh Sold Revenue / kWh Cost / kWh Total Revenue (Mcf) Fuel Cost O&M Margin

January 2020

GVEA

Energy Sales 3,172,000 $0.079 $0.035 $249,238 0 $111,326 $7,169 $130,743

Capacity / Spin 0 $0.000 $0.000 $0 0 $0 $0 $0

Cooper Lake & Misc. 0 ---- ---- $0 0 $0 $0 $0

Subtotal 3,172,000 $0.079 $0.035 $249,238 0 $111,326 $7,169 $130,743

HEA

Energy Sales 0 $0.000 $0.000 $0 0 $0 $0 $0

Capacity / Spin 0 $0.000 $0.000 $0 0 $0 $0 $0

Subtotal 0 $0.000 $0.000 $0 0 $0 $0 $0

MEA

Pool Transactions

Energy Sales 4,003,000 $0.000 $0.000 $42,811 0 $5,324 $9,047 $28,440

Capacity / Spin 0 $0.000 $0.000 $25 0 $0 $0 $25

FIW to MEA 0 $0.000 $0.000 $0 0 $0 $0 $0

Subtotal 4,003,000 $0.000 $0.000 $42,836 0 $5,324 $9,047 $28,465

Total Economy 7,175,000 $292,074 $0 $116,650 $16,216 $159,208

February 2020

GVEA

Energy Sales 673,000 $0.076 $0.036 $51,280 0 $24,119 $1,521 $25,640

Capacity / Spin 0 $0.000 $0.000 $0 0 $0 $0 $0

Cooper Lake & Misc. 0 ---- ---- $0 0 $0 $0 $0

Subtotal 673,000 $0.076 $0.036 $51,280 0 $24,119 $1,521 $25,640

HEA

Energy Sales 0 $0.000 $0.000 $0 0 $0 $0 $0

Capacity / Spin 0 $0.000 $0.000 $75 0 $0 $0 $75

Subtotal 0 $0.000 $0.000 $75 0 $0 $0 $75

MEA

Pool Transactions 0 $0.000 $0.000 $0 0 $0 $0 $0

Economy Energy Sales 3,191,000 $0.000 $0.000 $33,093 0 $4,299 $7,212 $21,582

Capacity / Spin 0 $0.000 $0.000 $35 $0 $0 $0 $35

FIW to MEA 0 $0.000 $0.000 $0 0 $0 $0 $0

Subtotal 3,191,000 $0.000 $0.000 $33,128 0 $4,299 $7,212 $21,617

Total Economy 3,864,000 $84,482 $0 $28,418 $8,733 $47,332

Exhibit 2 thru 5

Exhibit 5

Page 2 of 3

I I I I I I I I



Summary of Economy Energy Sales & Wheeling Transactions


ECONOMY ENERGY SALES: JANUARY - MARCH, 2020

Total Fuel Natural Gas Variable O&M Economy

Description kWh Sold Revenue / kWh Cost / kWh Total Revenue (Mcf) Fuel Cost O&M Margin

March 2020

GVEA

Economy Energy Sales 0 $0.000 $0.000 $0 0 $0 $0 $0

Capacity / Spin 0 $0.000 $0.000 $0 0 $0 $0 $0

Cooper Lake & Misc. 0 ---- ---- $0 0 $0 $0 $0

Subtotal 0 $0.000 $0.000 $0 0 $0 $0 $0

HEA


Capacity / Spin 0 $0.000 $0.000 $0 0 $0 $0 $0

Subtotal 0 $0.000 $0.000 $0 0 $0 $0 $0

MEA

Pool Transactions 0 $0.000 $0.000 $0 0 $0 $0 $0


Capacity / Spin 0 $0.000 $0.000 $175 $0 $0 $0 $175

FIW to MEA 0 $0.000 $0.000 $0 0 $0 $0 $0

Subtotal 1,443,000 $0.000 $0.000 $14,292 0 $1,979 $3,261 $9,052

Total Economy 1,443,000 $14,292 $0 $1,979 $3,261 $9,052

Total for Quarter Ended March 31, 2020

GVEA


Capacity / Spin 0 $0.000 $0.000 $0 0 $0 $0 $0

Cooper Lake & Misc. 0 ---- ---- $0 0 $0 $0 $0

Subtotal 3,845,000 $0.078 $0.035 $300,517 0 $135,445 $8,690 $156,383

HEA


Capacity / Spin 0 $0.000 $0.000 $75 0 $0 $0 $75

Subtotal 0 $0.000 $0.000 $75 0 $0 $0 $75

MEA


Capacity / Spin 0 $0.000 $0.000 $235 0 $0 $0 $235

FIW to MEA 0 $0.000 $0.000 $0 0 $0 $0 $0

Subtotal 8,637,000 $0.010 $0.001 $90,256 0 $11,601 $19,520 $59,134

Quarter Total 12,482,000 $0.089 $0.037 $390,848 0 $147,046 $28,210 $215,592

Exhibit 2 thru 5

Exhibit 5

Page 3 of 3

I I I I I I I I

EXHIBIT 06



Quarter Ended March 31, 2020

Jan-20 Feb-20 Mar-20

Description Account Number Account Description Attachment B Attachment C Attachment D Total

Fuel Expense

AIX

Southcentral Power Project 54720-651-00-7410 PROD - FUEL; GAS/SPP - AIX $0 $0 $0 $0

Beluga Power Plant 54720-652-00-7410 PROD - FUEL; GAS/BPP - AIX $0 $0 $0 $0

IGT Power Plant 54720-653-00-7410 PROD - FUEL; GAS/IGT - AIX $0 $0 $0 $0

Plant 1 54720-655-00-7411 PROD - FUEL; GAS/PLANT 1 - AIX $0 $0 $0 $0

Plant 2 54720-656-00-7411 PROD - FUEL; GAS/PLANT 2 - AIX $0 $0 $0 $0

Plant 2A 54720-657-00-7412 PROD - FUEL; GAS/PLANT 2A - AIX $0 $0 $0 $0

Gas Adjustment(s) 54720-654-00-7410 PROD - FUEL; GAS/AIX ADJ $0 $0 $0 $0

Subtotal $0 $0 $0 $0

BRU

Southcentral Power Project 54720-143-00-7410 PROD - FUEL; GAS/BELUGA RIVER UNIT $119,810 $125,578 $142,188 $387,576

Beluga Power Plant 54720-143-00-7410 PROD - FUEL; GAS/BELUGA RIVER UNIT $11,459 $4,416 $5,923 $21,798

IGT Power Plant 54720-143-00-7410 PROD - FUEL; GAS/BELUGA RIVER UNIT $137 $0 $1,565 $1,702

Plant 1 54720-143-00-7410 PROD - FUEL; GAS/BELUGA RIVER UNIT $0 $0 $0 $0

Plant 2 54720-143-00-7410 PROD - FUEL; GAS/BELUGA RIVER UNIT $0 $0 $0 $0

Plant 2A 54720-143-00-7410 PROD - FUEL; GAS/BELUGA RIVER UNIT $693,350 $629,693 $664,641 $1,987,685

Gas Adjustment 54720-143-00-7410 PROD - FUEL; GAS/BELUGA RIVER UNIT $0 $0 $0 $0

Subtotal $824,756 $759,687 $814,317 $2,398,761

Cook Inlet Energy, LLC

Southcentral Power Project 54720-617-00-7410 PROD - FUEL; GAS/SPP - CIE $0 $0 $0 $0

Beluga Power Plant 54720-659-00-7410 PROD - FUEL; GAS/BPP - CIE $0 $0 $0 $0

IGT Power Plant 54720-660-00-7410 PROD - FUEL; GAS/IGT - CIE $0 $0 $0 $0

Plant 1 54720-661-00-7411 PROD - FUEL; GAS/PLANT 1 - CIE $0 $0 $0 $0

Plant 2 54720-662-00-7411 PROD - FUEL; GAS/PLANT 2 - CIE $0 $0 $0 $0

Plant 2A 54720-663-00-7412 PROD - FUEL; GAS/PLANT 2A - CIE $0 $0 $0 $0

Gas Adjustment(s) 54720-664-00-7412 PROD - FUEL; GAS/CIE ADJ $0 $0 $0 $0


Exhibit 6

8/26/2020 12:08 PM

Exhibit 6

Page 1 of 4






Furie

Southcentral Power Project 54720-566-00-7410 PROD - FUEL; GAS/SPP - FURIE $0 $0 $0 $0

Beluga Power Plant 54720-567-00-7410 PROD - FUEL; GAS/BPP - FURIE $0 $0 $0 $0

IGT Power Plant 54720-562-00-7410 PROD - FUEL; GAS/IGT - FURIE $0 $0 $0 $0

Plant 1 54720-563-00-7410 PROD - FUEL; GAS/PLANT 1 - FURIE $0 $0 $0 $0

Plant 2 54720-564-00-7410 PROD - FUEL; GAS/PLANT 2 - FURIE $0 $0 $0 $0

Plant 2A 54720-565-00-7410 PROD - FUEL; GAS/PLANT 2A - FURIE $0 $0 $0 $0

Gas Adjustment(s) 54720-568-00-7410 PROD - FUEL; GAS/FURIE OPERATING ADJ $0 $0 $0 $0


Hilcorp Alaska, LLC (1/2015-3/2023)

Southcentral Power Project 54720-613-00-7410 PROD - FUEL; GAS/SPP GAS - HILCORP $2,870,580 $3,009,599 $3,378,667 $9,258,846

Beluga Power Plant - Native 54720-500-00-7410 PROD - FUEL; GAS/BELUGA GAS - HILCORP $278,535 $106,470 $142,808 $527,813

IGT Power Plant 54720-539-00-7410 PROD - FUEL; GAS/IGT GAS - HILCORP $3,203 $0 $37,965 $41,168

Plant 1 54720-546-00-7410 PROD - FUEL; GAS/PLANT 1 GAS - HILCORP $0 $0 $0 $0

Plant 2 54720-547-00-7410 PROD - FUEL; GAS/PLANT 2 GAS - HILCORP $0 $0 $0 $0

Plant 2A 54720-548-00-7410 PROD - FUEL; GAS/PLANT 2A GAS - HILCORP $928,051 $569,833 $273,615 $1,771,499

Gas Adjustment(s) 54720-500-00-7410 PROD - FUEL; GAS/BELUGA GAS - HILCORP $0 $0 $2,175 $2,175

Subtotal $4,080,369 $3,685,902 $3,835,230 $11,601,501

CINGSA - Gas Withdrawn from Storage

Southcentral Power Project 54720-245-00-7410 PROD - FUEL; GAS/SPP CINGSA $1,264,352 $616,635 $375,520 $2,256,507

Beluga Power Plant- Native 54720-245-00-7410 PROD - FUEL; GAS/BPP CINGSA $173,268 $31,973 $40,444 $245,685

IGT 54720-245-00-7410 PROD - FUEL; GAS/IGT CINGSA $1,262 $0 $5,831 $7,093

Plant 1 54720-245-00-7410 PROD - FUEL; GAS/PLANT 1 CINGSA $0 $0 $0 $0

Plant 2 54720-245-00-7410 PROD - FUEL; GAS/PLANT 2 CINGSA $0 $0 $0 $0

Plant 2A 54720-245-00-7410 PROD - FUEL; GAS/PLANT 2A CINGSA $1,349,872 $1,012,360 $760,836 $3,123,068

Inventory Adjustment(s) 54720-245-00-7410 PROD - FUEL; GAS/CINGSA ADJ $139,448 $203,826 $127,929 $471,204

Subtotal $2,928,203 $1,864,794 $1,310,560 $6,103,557

Exhibit 6

8/26/2020 12:08 PM

Exhibit 6

Page 2 of 4






CINGSA - Storage and Withdrawal Fees

FSS, ISS and Withdrawal 54721-245-00-7410 Fuel Storage Fixed Cost/CINGSA FEES $20,208 $334,039 $312,187 $666,434

Subtotal 54721-245-00-7410 $20,208 $334,039 $312,187 $666,434

Other Fuel Purchases

Diesel Fuel (Plant 1) 54720-501-00-7410 PROD - FUEL/PLANT 1 DIESEL $22,439 $681 $0 $23,120

Emergency Generator Fuel 54720-502-00-7410 PROD - FUEL/EMERG GEN FUEL $0 $0 $0 $0

Subtotal $22,439 $681 $0 $23,120

Total Fuel Expense $7,875,975 $6,645,103 $6,272,294 $20,793,372

Natural Gas Transportation Expense

ENSTAR: To IGT 54750-477-00-7410 PROD - FUEL TRANSPORT/IGT - ENSTAR $3,403 $2,903 $7,842 $14,148

ENSTAR: To SPP 54750-615-00-7410 PROD - FUEL TRANSPORT/SPP - ENSTAR $305,479 $289,845 $296,397 $891,720

ENSTAR: To Plants 1, 2, 2A 54750-549-00-7410 PROD - FUEL TRANSPORT/1-2-2A - ENSTAR $86,122 $61,141 $53,889 $201,152

Harvest- KBPL 54750-648-00-7410 PROD - FUEL TRANSPORT/KBPL $184,153 $128,316 $131,764 $444,232

Total Natural Gas Transportation $579,156 $482,204 $489,891 $1,551,252

Total Gas Transportation Expense $579,156 $482,204 $489,891 $1,551,252

Total Fuel and Gas Transportation Expense $8,455,131 $7,127,307 $6,762,186 $22,344,624

Exhibit 6

8/26/2020 12:08 PM

Exhibit 6

Page 3 of 4







Bradley Lake - Chugach 55500-070-00-7410 PURCHASED POWER/BRADLEY LAKE $692,390 $918,838 $918,838 $2,530,066

Bradley Lake - Battle Creek 55500-070-00-7410 PURCHASED POWER/BRADLEY LAKE $86,867 $86,867 $86,867 $260,601

Bradley Lake -Transmission 55500-070-00-7410 PURCHASED POWER/BRADLEY LAKE/HEA $7,358 $7,358 $34,119 $48,835

Bradley Lake - Seward 55500-072-00-7410 PURCHASED POWER/BRADLEY LAKE- SEWARD $16,320 $16,320 $16,320 $48,960

Bradley Lake Total $802,935 $1,029,383 $1,056,144 $2,888,462

Renewable Generation Purchases

Qualified Facility Purchases 55500-131-00-7410 PURCHASED POWER/QUALIFIED FACILITIES $156 $231 $327 $713

Fire Island Wind LLC 55500-141-00-7410 PURCHASED POWER/FIRE ISLAND WIND $426,586 $500,672 $315,939 $1,243,198

Subtotal $426,742 $500,903 $316,266 $1,243,911

Purchases from Other Plants

CINGSA- Gas to EGS 55500-655-00-7410 PURCHASED POWER/EGS $13,556 $7,016 $4,381 $24,952

Hilcorp Gas to EGS 55500-655-00-7410 PURCHASED POWER/EGS $37,493 $43,500 $36,578 $117,570

BRU-Non Contract to EGS 55500-143-00-7410 PURCHASED POWER/EGS $1,574 $1,812 $1,528 $4,914

Subtotal $52,622 $52,327 $42,487 $147,436

Other Purchases

MEA Spin 55500-061-00-7410 PURCHASED POWER/MEA $0 $22,128 $0 $22,128

GVEA 55500-062-00-7410 PURCHASED POWER/GVEA $2,125 $3,640 $2,490 $8,255

HEA 55500-063-00-7410 PURCHASED POWER/HEA $0 $0 $0 $0

MEA - EGS 55500-655-00-7410 PURCHASED POWER/MEA-EGS $21,711 $0 $17,334 $39,045

Alaska Intertie Expense 55610-065-00-7410 PURCHASED POWER/INTERTIE $41,337 $41,337 $41,337 $124,011

Subtotal $65,173 $67,105 $61,161 $193,439

Total Purchased Power Expense $1,347,472 $1,649,718 $1,476,059 $4,473,248

Total Fuel, Transportation & Purchased Power Expense $9,802,603 $8,777,025 $8,238,244 $26,817,8721 Includes both Chugach gas and non-fuel O&M paid to ML&P and MEA.

Exhibit 6

8/26/2020 12:08 PM

Exhibit 6

Page 4 of 4

EXHIBIT 07



Fuel & Purchased Power Balancing Account Summary


South District North District1

Description System Total South Total Residential Small General LGS-P LGS-S Lighting North Total Residential Small General LGS-P LGS-S Lighting Seward

F&PP Balance Forward as of December 31, 2019

Fuel Expense ($1,156,946) $338,934 ($887,973) ($131,963) $176,198 $1,190,034 ($7,362) ($1,495,880) ($200,269) ($138,381) ($375,912.02) ($771,416) ($9,903) $0

Purchased Power Expense $2,745,038 $2,745,038 $1,109,341 $310,897 $96,108 $1,259,375 ($30,683) $0 $0 $0 $0 $0 $0 $0

Cumulative Balance $1,588,092 $3,083,972 $221,368 $178,934 $272,306 $2,449,409 ($38,045) ($1,495,880) ($200,269) ($138,381) ($375,912) ($771,416) ($9,903) $0

Jan-20

Fuel

Debit $7,912,281 $4,480,802 $2,216,079 $493,672 $206,731 $1,551,917 $12,403 $3,221,402 $485,393 $309,606 $786,598 $1,625,770 $14,035 $210,077

Credit $10,886,895 $8,300,482 $4,379,430 $943,670 $316,934 $2,642,859 $17,590 $2,376,336 $358,650 $228,752 $577,369 $1,201,199 $10,365 $210,077

Month Balance ($3,819,680) ($3,819,680) ($2,163,351) ($449,997) ($110,202) ($1,090,942) ($5,187) $845,066 $126,743 $80,854 $209,230 $424,570 $3,670 $0

Cumulative Balance ($4,976,626) ($3,480,746) ($3,051,324) ($581,960) $65,996 $99,092 ($12,549) ($650,814) ($73,526) ($57,527) ($166,683) ($346,846) ($6,233) $0

Purchased Power

Debit $1,267,869 $726,180 $359,148 $80,007 $33,504 $251,511 $2,010 $522,076 $78,665 $50,176 $127,480 $263,480 $2,275 $19,613

Credit $978,405 $571,947 $350,280 $73,731 $41,607 $103,470 $2,859 $386,845 $58,385 $37,239 $93,990 $195,544 $1,687 $19,613

Month Balance $289,464 $154,233 $8,868 $6,276 ($8,103) $148,041 ($849) $135,230 $20,280 $12,937 $33,490 $67,936 $587 $0

Cumulative Balance $3,034,502 $2,899,271 $1,118,209 $317,173 $88,005 $1,407,416 ($31,532) $135,230 $20,280 $12,937 $33,490 $67,936 $587 $0

F&PP Balancing Account Total

Debit $9,180,150 $5,206,982 $2,575,227 $573,679 $240,235 $1,803,428 $14,413 $3,743,478 $564,058 $359,782 $914,078 $1,889,250 $16,310 $229,690

Credit $11,865,300 $8,872,429 $4,729,710 $1,017,400 $358,541 $2,746,329 $20,449 $2,763,181 $417,035 $265,991 $671,359 $1,396,744 $12,052 $229,690

Month Balance ($2,685,150) ($3,665,447) ($2,154,483) ($443,721) ($118,306) ($942,901) ($6,036) $980,296 $147,023 $93,791 $242,719 $492,506 $4,257 $0

Cumulative Balance ($1,097,058) ($581,475) ($1,933,115) ($264,787) $154,000 $1,506,508 ($44,081) ($515,584) ($53,246) ($44,589) ($133,193) ($278,910) ($5,645) $0

Feb-20

Fuel

Debit $6,851,728 $3,449,833 $1,631,409 $390,604 $156,846 $1,262,074 $8,900 $3,219,079 $496,734 $321,951 $715,492 $1,674,101 $10,799 $182,817

Credit $8,681,791 $6,063,856 $3,035,415 $703,785 $255,463 $2,055,401 $13,792 $2,435,118 $376,316 $243,904 $538,490 $1,268,137 $8,272 $182,817

Month Balance ($1,830,063) ($2,614,023) ($1,404,005) ($313,180) ($98,618) ($793,327) ($4,892) $783,960 $120,419 $78,048 $177,002 $405,964 $2,527 $0

Cumulative Balance ($6,806,689) ($6,094,769) ($4,455,330) ($895,141) ($32,622) ($694,235) ($17,442) $133,146 $46,892 $20,521 $10,320 $59,119 ($3,705) $0

Exhibit 7 Exhibit 07

Page 1 of 4

I I







Purchased Power

Debit $1,569,143 $798,568 $377,639 $90,417 $36,307 $292,145 $2,060 $745,153 $114,984 $74,525 $165,622 $387,521 $2,500 $25,423

Credit $1,571,384 $974,761 $504,341 $111,489 $39,355 $316,717 $2,859 $571,201 $88,272 $57,212 $126,312 $297,464 $1,940 $25,423

Month Balance ($2,241) ($176,193) ($126,702) ($21,072) ($3,048) ($24,572) ($799) $173,952 $26,712 $17,313 $39,310 $90,057 $559 $0

Cumulative Balance $3,032,260 $2,723,078 $991,507 $296,101 $84,956 $1,382,844 ($32,331) $309,182 $46,993 $30,251 $72,799 $157,993 $1,147 $0

Total

Debit $8,420,871 $4,248,400 $2,009,048 $481,021 $193,152 $1,554,218 $10,960 $3,964,231 $611,718 $396,476 $881,114 $2,061,622 $13,299 $208,239

Credit $10,253,175 $7,038,617 $3,539,756 $815,274 $294,818 $2,372,117 $16,651 $3,006,319 $464,587 $301,116 $664,802 $1,565,601 $10,213 $208,239

Month Balance ($2,790,217) ($2,790,217) ($1,530,707) ($334,253) ($101,666) ($817,899) ($5,691) $957,912 $147,131 $95,361 $216,312 $496,021 $3,087 $0

Cumulative Balance ($3,887,275) ($3,371,691) ($3,463,823) ($599,040) $52,334 $688,609 ($49,772) $442,328 $93,885 $50,771 $83,119 $217,112 ($2,559) $0

Mar-20

Fuel

Debit $6,584,257 $3,504,524 $1,684,912 $384,721 $161,179 $1,266,301 $7,411 $2,899,261 $429,895 $289,142 $608,277 $1,563,179 $8,768 $180,471

Credit $7,573,826 $5,188,080 $2,315,085 $551,991 $260,732 $2,048,227 $12,045 $2,205,275 $327,496 $220,241 $460,290 $1,190,570 $6,677 $180,471

Month Balance ($989,569) ($1,683,556) ($630,172) ($167,270) ($99,553) ($781,926) ($4,634) $693,986 $102,399 $68,901 $147,986 $372,609 $2,091 $0

Cumulative Balance ($7,796,259) ($7,778,325) ($5,085,502) ($1,062,411) ($132,175) ($1,476,161) ($22,076) $827,133 $149,291 $89,422 $158,306 $431,728 ($1,614) $0

Purchased Power

Debit $1,398,738 $750,813 $360,977 $82,423 $34,531 $271,294 $1,588 $621,141 $92,101 $61,946 $130,318 $334,897 $1,878 $26,784

Credit $1,310,282 $799,412 $356,731 $85,056 $40,167 $315,612 $1,847 $484,085 $71,889 $48,346 $101,039 $261,345 $1,466 $26,784

Month Balance $88,457 ($48,599) $4,247 ($2,633) ($5,635) ($44,318) ($259) $137,056 $20,212 $13,601 $29,278 $73,553 $413 $0

Cumulative Balance $3,120,717 $2,674,479 $995,754 $293,468 $79,321 $1,338,527 ($32,590) $446,238 $67,204 $43,851 $102,078 $231,545 $1,560 $0

Total

Debit $7,982,995 $4,255,337 $2,045,890 $467,144 $195,710 $1,537,595 $8,999 $3,520,402 $521,996 $351,088 $738,595 $1,898,077 $10,647 $207,255

Credit $8,884,107 $5,987,492 $2,671,815 $637,047 $300,899 $2,363,838 $13,892 $2,689,359 $399,386 $268,586 $561,330 $1,451,915 $8,142 $207,255

Month Balance ($901,112) ($1,732,155) ($625,926) ($169,903) ($105,189) ($826,244) ($4,893) $831,043 $122,610 $82,502 $177,265 $446,161 $2,504 $0

Cumulative Balance ($4,788,387) ($5,103,846) ($4,089,749) ($768,943) ($52,854) ($137,635) ($54,666) $1,273,371 $216,495 $133,273 $260,384 $663,273 ($54) $0


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Quarter Ending Balance at March 31, 2020

Fuel

Debit $21,348,265 $11,435,159 $5,532,400 $1,268,998 $524,756 $4,080,292 $28,713 $9,339,742 $1,412,022 $920,699 $2,110,367 $4,863,050 $33,603 $573,364

Credit $27,142,512 $19,552,418 $9,729,929 $2,199,445 $833,129 $6,746,487 $43,427 $7,016,729 $1,062,462 $692,897 $1,576,149 $3,659,907 $25,314 $573,364

Quarter Balance ($5,794,247) ($8,117,259) ($4,197,529) ($930,448) ($308,373) ($2,666,195) ($14,714) $2,323,013 $349,560 $227,802 $534,218 $1,203,143 $8,288 $0

Purchased Power

Debit $4,235,750 $2,275,561 $1,097,764 $252,847 $104,342 $814,950 $5,658 $1,888,369 $285,750 $186,648 $423,420 $985,898 $6,653 $71,820

Credit $3,860,071 $2,346,120 $1,211,352 $270,276 $121,129 $735,798 $7,565 $1,442,131 $218,546 $142,796 $321,342 $754,353 $5,093 $71,820

Quarter Balance $375,679 ($70,559) ($113,587) ($17,429) ($16,787) $79,152 ($1,907) $446,238 $67,204 $43,851 $102,078 $231,545 $1,560 $0

Total

Debit $25,584,016 $13,710,720 $6,630,164 $1,521,845 $629,098 $4,895,241 $34,371 $11,228,111 $1,697,773 $1,107,347 $2,533,787 $5,848,949 $40,256 $645,185

Credit $31,002,583 $21,898,538 $10,941,281 $2,469,722 $954,258 $7,482,285 $50,992 $8,458,860 $1,281,008 $835,693 $1,897,491 $4,414,260 $30,407 $645,185

Quarter Balance ($5,418,567) ($8,187,818) ($4,311,117) ($947,877) ($325,160) ($2,587,044) ($16,621) $2,769,251 $416,764 $271,654 $636,296 $1,434,689 $9,848 $0

Balance Forward as of March 31, 2020

Fuel Expense ($6,951,193) ($7,778,325) ($5,085,502) ($1,062,411) ($132,175) ($1,476,161) ($22,076) $827,133 $149,291 $89,422 $158,306 $431,728 ($1,614) $0

Purchased Power Exp $3,120,717 $2,674,479 $995,754 $293,468 $79,321 $1,338,527 ($32,590) $446,238 $67,204 $43,851 $102,078 $231,545 $1,560 $0


1 The beginning balance is allocated across rate classes based on percentage of sales. The allocation of monthly fuel and purchased power cost and recovery lines are based on the percentage of costs between fuel

and purchased power as calculated in Exhibits 8 through 10.


Page 3 of 4

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South District North District Wholesale

Description System Total Total South Residential Small General LGS-P LGS-S Lighting Total North Residential Small General LGS-P LGS-S Lighting Seward

Balance Forward as of March 31, 2020

Fuel Expense ($6,951,193) ($7,778,325) ($5,085,502) ($1,062,411) ($132,175) ($1,476,161) ($22,076) $827,133 $149,291 $89,422 $158,306 $431,728 ($1,614) $0

Purchased Power Exp $3,120,717 $2,674,479 $995,754 $293,468 $79,321 $1,338,527 ($32,590) $446,238 $67,204 $43,851 $102,078 $231,545 $1,560 $0


Projected Q2 2019

Fuel

Debit $20,826,662 $11,015,303 $4,582,372 $1,118,570 $526,383 $4,765,522 $22,455 $9,012,520 $909,003 $663,589 $1,887,631 $5,532,013 $20,284 $798,839

Credit $26,902,991 $14,788,227 $6,154,070 $1,502,227 $701,734 $6,400,039 $30,157 $11,315,925 $1,255,363 $916,439 $1,476,217 $7,639,894 $28,013 $798,839

Quarter Balance ($6,076,329) ($3,772,924) ($1,571,699) ($383,656) ($175,350) ($1,634,517) ($7,702) ($2,303,405) ($346,360) ($252,850) $411,414 ($2,107,880) ($7,729) $0

Purchased Power

Debit $8,940,568 $4,778,567 $1,987,886 $485,249 $228,351 $2,067,339 $9,741 $3,909,736 $394,336 $287,873 $818,876 $2,399,852 $8,799 $252,265

Credit $4,445,809 $2,278,694 $948,282 $231,478 $108,104 $986,183 $4,647 $1,914,850 $193,439 $141,214 $398,648 $1,177,232 $4,316 $252,265

Quarter Balance $4,494,758 $2,499,873 $1,039,605 $253,771 $120,247 $1,081,156 $5,094 $1,994,886 $200,897 $146,659 $420,228 $1,222,619 $4,483 $0

Projected Q2 Balance

Debit $29,767,230 $15,793,869 $6,570,258 $1,603,819 $754,735 $6,832,861 $32,196 $12,922,257 $1,303,338 $951,462 $2,706,508 $7,931,865 $29,083 $1,051,104

Credit $31,348,801 $17,066,921 $7,102,352 $1,733,705 $809,838 $7,386,222 $34,804 $13,230,776 $1,448,802 $1,057,653 $1,874,866 $8,817,126 $32,329 $1,051,104

Quarter Balance ($1,581,571) ($1,273,052) ($532,094) ($129,886) ($55,103) ($553,361) ($2,607) ($308,519) ($145,463) ($106,191) $831,642 ($885,261) ($3,246) $0

Projected Balance Forward

Fuel Expense ($13,027,522) ($11,551,249) ($6,657,201) ($1,446,067) ($307,526) ($3,110,678) ($29,778) ($1,476,272) ($197,069) ($163,428) $569,720 ($1,676,153) ($9,343) $0

Purch Pwr Exp $7,615,476 $5,174,351 $2,035,358 $547,238 $199,568 $2,419,683 ($27,496) $2,441,124 $268,101 $190,510 $522,306 $1,454,165 $6,042 $0

Projected Balance ($5,412,046) ($6,376,898) ($4,621,843) ($898,829) ($107,958) ($690,996) ($57,273) $964,852 $71,032 $27,082 $1,092,026 ($221,988) ($3,300) $0


System Total Total South Residential Small General LGS-P LGS-S Lighting Total North Residential Small General LGS-P LGS-S Lighting Seward

Projected Q2 kWh Sales 468,279,338 246,968,610 102,739,068 25,078,910 11,801,780 106,845,396 503,456 207,789,472 20,957,640 15,299,484 43,520,558 127,544,134 467,656 13,521,256

Fuel Adjustment Factor ---- ---- $0.05990 $0.05990 $0.05946 $0.05990 $0.05990 ---- $0.05990 $0.05990 $0.03392 $0.05990 $0.05990 ----

Fuel Cost Recovery $26,902,991 $14,788,227 $6,154,070 $1,502,227 $701,734 $6,400,039 $30,157 $11,315,925 $1,255,363 $916,439 $1,476,217 $7,639,894 $28,013 $798,839

Purch. Pwr Adj. Factor ---- ---- $0.00677 $0.00677 $0.00672 $0.00677 $0.00677 ---- $0.00677 $0.00677 $0.00672 $0.00677 $0.00677 ----

Purch Pwr Cost Recovery $3,328,211 $1,671,387 $695,543 $169,784 $79,308 $723,343 $3,408 $1,404,559 $141,883 $103,578 $292,458 $863,474 $3,166 $252,265

Fire Island Wind ---- ---- $0.00246 $0.00246 $0.00244 $0.00246 $0.00246 ---- $0.00246 $0.00246 $0.00244 $0.00246 $0.00246 ----

Purch Pwr Cost Recovery $1,117,598 $607,307 $252,738 $61,694 $28,796 $262,840 $1,239 $510,292 $51,556 $37,637 $106,190 $313,759 $1,150 ----

Total F&PP Rate ---- ---- $0.06913 $0.06913 $0.06862 $0.06913 $0.06913 ---- $0.06913 $0.06913 $0.04308 $0.06913 $0.06913 ----

Projected Q2 2019 Revenue $31,348,801 $17,066,921 $7,102,352 $1,733,705 $809,838 $7,386,222 $34,804 $13,230,776 $1,448,802 $1,057,653 $1,874,866 $8,817,126 $32,329 $1,051,104

Exhibit 7

8/26/2020 12:08 PM

Exhibit 07

Page 4 of 4

EXHIBIT 08



Fuel & Purchased Power Cost Assignment:January-20


Allocation Total South Large General Service Total North Large General Service

Factor Description System Total Total Retail Retail Residential SGS LGS-P LGS-S Lighting Retail Residential SGS LGS-P LGS-S Lighting Seward

EE_1_01 Energy - All 100.0000% 97.4032% 56.6649% 28.0248% 6.2430% 2.6144% 19.6258% 0.1568% 40.7383% 6.1383% 3.9153% 9.9474% 20.5597% 0.1775% 2.5968%

kWh - Generation 232,713,669 226,670,457 131,866,857 65,217,636 14,528,430 6,083,962 45,671,831 364,998 94,803,599 14,284,773 9,111,491 23,149,039 47,845,257 413,039 6,043,212

Losses - G&T 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580

kWh - G&T 226,688,294 220,801,552 128,452,588 63,529,035 14,152,263 5,926,438 44,489,305 355,548 92,348,964 13,914,915 8,875,578 22,549,669 46,606,458 402,345 5,886,742

Losses - Distrib 26,998,306 26,998,306 15,706,422 7,767,954 1,730,455 724,650 5,439,889 43,474 11,291,884 1,701,433 1,085,253 2,757,240 5,698,762 49,196 ----

kWh - Primary 1

193,803,246 193,803,246 112,746,166 55,761,081 12,421,808 5,201,788 39,049,416 312,073 81,057,080 12,213,481 7,790,325 19,792,429 40,907,696 353,148 ----

Losses - Pri to Sec 1,257,308 1,257,308 801,002 415,315 92,519 ---- 290,844 2,324 456,306 90,967 58,023 ---- 304,685 2,630 ----

kWh - Secondary 167,551,721 167,551,721 106,743,376 55,345,766 12,329,289 ---- 38,758,572 309,749 60,808,345 12,122,514 7,732,302 ---- 40,603,011 350,518 ----

EE_1_02 Energy - Retail 100.0000% 100.0000% 58.1756% 28.7720% 6.4095% 2.6841% 20.1490% 0.1610% 41.8244% 6.3020% 4.0197% 10.2126% 21.1078% 0.1822% ----

226,670,457 226,670,457 131,866,857 65,217,636 14,528,430 6,083,962 45,671,831 364,998 94,803,599 14,284,773 9,111,491 23,149,039 47,845,257 413,039 ----

EE_1_03 Energy - Including 100.0000% 97.4032% 56.6649% 28.0248% 6.2430% 2.6144% 19.6258% 0.1568% 40.7383% 6.1383% 3.9153% 9.9474% 20.5597% 0.1775% 2.5968%

SES 232,713,669 226,670,457 131,866,857 65,217,636 14,528,430 6,083,962 45,671,831 364,998 94,803,599 14,284,773 9,111,491 23,149,039 47,845,257 413,039 6,043,212

EE_1_04 Bradley Lake 100.0000% 97.4032% 56.6649% 28.0248% 6.2430% 2.6144% 19.6258% 0.1568% 40.7383% 6.1383% 3.9153% 9.9474% 20.5597% 0.1775% 2.5968%

Generation 32,180,190 31,344,520 18,234,857 9,018,447 2,009,025 841,304 6,315,608 50,473 13,109,663 1,975,332 1,259,958 3,201,103 6,616,154 57,116 835,669

EE_1_05 Energy, Excluding 100.0000% 97.4032% 56.6649% 28.0248% 6.2430% 2.6144% 19.6258% 0.1568% 40.7383% 6.1383% 3.9153% 9.9474% 20.5597% 0.1775% 2.5968%

Bradley Lake 200,533,479 195,325,937 113,632,000 56,199,189 12,519,405 5,242,658 39,356,223 314,525 81,693,936 12,309,441 7,851,533 19,947,936 41,229,103 355,923 5,207,543

EE_1_06 Fire Island Wind 100.0000% 100.0000% 58.1756% 28.7720% 6.4095% 2.6841% 20.1490% 0.1610% 41.8244% 6.3020% 4.0197% 10.2126% 21.1078% 0.1822% ----

Generation 4,397,790 4,397,790 2,558,440 1,265,332 281,876 118,039 886,111 7,082 1,839,350 277,149 176,778 449,130 928,279 8,014 ----

EE_1_07 Energy, Excl. B/L 100.0000% 97.3449% 56.6310% 28.0081% 6.2393% 2.6128% 19.6140% 0.1568% 40.7139% 6.1347% 3.9130% 9.9415% 20.5474% 0.1774% 2.6551%

& FIW 196,135,689 190,928,147 111,073,560 54,933,857 12,237,529 5,124,619 38,470,112 307,443 79,854,586 12,032,292 7,674,755 19,498,806 40,300,824 347,909 5,207,543 1 Losses between primary and secondary delivery are 0.7504 percent as measured from secondary (U-06-134).

Total Percent

Fuel Expense (Net of Econ) $8,338,481 86.0884% Losses: Total Percent

Generation - Purch Pwr Exp $1,347,472 13.9116% Retail 34,124,519 15.1%

Fuel & PP Expense $9,685,953 100.0000% System 34,280,989 14.7%

Exhibit 8 thru 10

Exhibit 8

Page 1 of 5

I



Fuel & Purchased Power Cost Assignment:

January-20

Allocation South District North District Wholesale

Description Factor System Total Total South Residential SGS LGS-P LGS-S Lighting Total North Residential SGS LGS-P LGS-S Lighting Seward

Fuel Expense

BRU (Chugach)

Southcentral Power Proj EE_1_07 $119,810 $67,850 $33,557 $7,475 $3,130 $23,500 $188 $48,779 $7,350 $4,688 $11,911 $24,618 $213 $3,181

Beluga Power Plant EE_1_07 $11,459 $6,489 $3,209 $715 $299 $2,248 $18 $4,665 $703 $448 $1,139 $2,354 $20 $304

IGT Power Plant EE_1_07 $137 $78 $38 $9 $4 $27 $0 $56 $8 $5 $14 $28 $0 $4

Plant 1 EE_1_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2 EE_1_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2A EE_1_07 $693,350 $392,651 $194,194 $43,260 $18,116 $135,994 $1,087 $282,290 $42,535 $27,131 $68,929 $142,466 $1,230 $18,409

Gas Adjustment(s) EE_1_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Subtotal $824,756 $467,068 $230,998 $51,459 $21,549 $161,768 $1,293 $335,791 $50,596 $32,273 $81,993 $169,466 $1,463 $21,898


Southcentral Power Proj EE_1_07 $2,870,580 $1,625,638 $803,995 $179,105 $75,002 $563,036 $4,500 $1,168,727 $176,101 $112,325 $285,378 $589,830 $5,092 $76,216

Beluga Power Plant EE_1_07 $278,535 $157,737 $78,012 $17,379 $7,278 $54,632 $437 $113,403 $17,087 $10,899 $27,691 $57,232 $494 $7,395

IGT Power Plant EE_1_07 $3,203 $1,814 $897 $200 $84 $628 $5 $1,304 $196 $125 $318 $658 $6 $85

Plant 1 EE_1_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2 EE_1_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2A EE_1_07 $928,051 $525,564 $259,929 $57,904 $24,248 $182,028 $1,455 $377,846 $56,933 $36,314 $92,262 $190,691 $1,646 $24,640


Subtotal $4,080,369 $2,310,753 $1,142,833 $254,587 $106,612 $800,325 $6,396 $1,661,279 $250,317 $159,664 $405,649 $838,411 $7,238 $108,337

Furie Alaska, LLC

Southcentral Power Proj EE_1_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Beluga Power Plant EE_1_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0


Plant 1 EE_1_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2 EE_1_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2A EE_1_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0


Subtotal $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Exhibit 8 thru 10

Exhibit 8

Page 2 of 5

I I

I







Plant 1 EE_1_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2 EE_1_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2A EE_1_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0


Subtotal $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

AIX




Plant 1 EE_1_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2 EE_1_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2A EE_1_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0


Subtotal $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Gas Withdrawn from Storage

Southcentral Power Proj EE_1_07 $1,264,352 $716,015 $354,121 $78,887 $33,035 $247,990 $1,982 $514,768 $77,564 $49,474 $125,695 $259,792 $2,243 $33,569


IGT EE_1_07 $1,262 $715 $354 $79 $33 $248 $2 $514 $77 $49 $126 $259 $2 $34

Plant 1 EE_1_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2 EE_1_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2A EE_1_07 $1,349,872 $764,446 $378,073 $84,223 $35,269 $264,764 $2,116 $549,586 $82,810 $52,820 $134,197 $277,364 $2,394 $35,840

Inventory Adjustment(s) EE_1_07 $139,448 $78,971 $39,057 $8,701 $3,643 $27,351 $219 $56,775 $8,555 $5,457 $13,863 $28,653 $247 $3,702

Subtotal $2,928,203 $1,658,270 $820,134 $182,700 $76,508 $574,339 $4,590 $1,192,187 $179,636 $114,580 $291,107 $601,670 $5,194 $77,746

CINGSA - Capacity and Withdrawal Fees

FSS and ISS EE_1_07 $20,208 $11,444 $5,660 $1,261 $528 $3,964 $32 $8,227 $1,240 $791 $2,009 $4,152 $36 $537

Subtotal $20,208 $11,444 $5,660 $1,261 $528 $3,964 $32 $8,227 $1,240 $791 $2,009 $4,152 $36 $537


Diesel Fuel EE_1_07 $22,439 $12,707 $6,285 $1,400 $586 $4,401 $35 $9,136 $1,377 $878 $2,231 $4,611 $40 $596

Emergency Generator EE_1_07 0.00 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Subtotal $22,439 $12,707 $6,285 $1,400 $586 $4,401 $35 $9,136 $1,377 $878 $2,231 $4,611 $40 $596

Total Fuel $7,875,975 $4,460,242 $2,205,910 $491,407 $205,783 $1,544,796 $12,346 $3,206,620 $483,166 $308,185 $782,989 $1,618,310 $13,971 $209,113

Exhibit 8 thru 10

Exhibit 8

Page 3 of 5

I I




Fuel Transportation EE_1_07 $579,156 $327,982 $162,211 $36,135 $15,132 $113,596 $908 $235,797 $35,529 $22,662 $57,577 $119,002 $1,027 $15,377

Subtotal $579,156 $327,982 $162,211 $36,135 $15,132 $113,596 $908 $235,797 $35,529 $22,662 $57,577 $119,002 $1,027 $15,377

Total Fuel and Transportation Expense $8,455,131 $4,788,224 $2,368,121 $527,543 $220,915 $1,658,392 $13,253 $3,442,418 $518,695 $330,848 $840,566 $1,737,311 $14,998 $224,490

Less Fuel Credits

Economy Fuel Costs EE_1_07 ($116,650) ($66,060) ($32,671) ($7,278) ($3,048) ($22,880) ($183) ($47,493) ($7,156) ($4,564) ($11,597) ($23,969) ($207) ($3,097)

Economy Margins EE_1_07 ($159,208) ($90,161) ($44,591) ($9,934) ($4,160) ($31,227) ($250) ($64,820) ($9,767) ($6,230) ($15,828) ($32,713) ($282) ($4,227)

EGS (Pool) EE_1_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Wheeling Revenue EE_1_07 ($215,421) ($121,995) ($60,335) ($13,441) ($5,628) ($42,253) ($338) ($87,706) ($13,215) ($8,429) ($21,416) ($44,263) ($382) ($5,720)

Exchange Credits EE_1_07 ($51,572) ($29,205) ($14,444) ($3,218) ($1,347) ($10,115) ($81) ($20,997) ($3,164) ($2,018) ($5,127) ($10,597) ($91) ($1,369)

Subtotal ---- ($542,850) ($307,422) ($152,042) ($33,870) ($14,184) ($106,475) ($851) ($221,016) ($33,302) ($21,242) ($53,967) ($111,542) ($963) ($14,413)

Net Fuel and Transportation ---- $7,912,281 $4,480,802 $2,216,079 $493,672 $206,731 $1,551,917 $12,403 $3,221,402 $485,393 $309,606 $786,598 $1,625,770 $14,035 $210,077

Average at Generation ---- $0.03400 $0.01977 $0.03398 $0.03398 $0.03398 $0.03398 $0.03398 $0.03398 $0.03398 $0.03398 $0.03398 $0.03398 $0.03476

Average at Delivery ---- ---- $0.04776 $0.04996 $0.04649 $0.04812 $0.04523 $0.05125 $0.04004 $0.02292 $0.08919 $0.08295 $0.00031


Bradley Lake Purchases EE_1_04 $716,068 $405,759 $200,677 $44,704 $18,721 $140,534 $1,123 $291,714 $43,955 $28,036 $71,230 $147,222 $1,271 $18,595

Bradley Lake - Battle Creek EE_1_02 $86,867 $50,535 $24,993 $5,568 $2,332 $17,503 $140 $36,332 $5,474 $3,492 $8,871 $18,336 $158 $0

Fire Island Wind EE_1_02 $426,586 $248,169 $122,737 $27,342 $11,450 $85,953 $687 $178,417 $26,883 $17,148 $43,566 $90,043 $777 $0

Qualified Generation EE_1_07 $156 $88 $44 $10 $4 $31 $0 $63 $10 $6 $15 $32 $0 $4

Purchases from Other Plants EE_1_07 $52,622 $29,800 $14,738 $3,283 $1,375 $10,321 $82 $21,424 $3,228 $2,059 $5,231 $10,812 $93 $1,397

Other Purchases EE_1_07 $65,173 $36,908 $18,254 $4,066 $1,703 $12,783 $102 $26,535 $3,998 $2,550 $6,479 $13,391 $116 $1,730

Subtotal ---- $1,347,472 $771,260 $381,443 $84,974 $35,584 $267,124 $2,135 $554,485 $83,548 $53,291 $135,394 $279,836 $2,416 $21,727


Wheeling Revenue EE_1_07 ($34,811) ($19,714) ($9,750) ($2,172) ($910) ($6,828) ($55) ($14,173) ($2,136) ($1,362) ($3,461) ($7,153) ($62) ($924)

AWWU Water Sales EE_1_07 ($44,791) ($25,366) ($12,545) ($2,795) ($1,170) ($8,785) ($70) ($18,236) ($2,748) ($1,753) ($4,453) ($9,203) ($79) ($1,189)

Renewable Energy Credits EE_1_02 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 0

Subtotal ($79,603) ($45,080) ($22,295) ($4,967) ($2,080) ($15,613) ($125) ($32,409) ($4,883) ($3,115) ($7,914) ($16,356) ($141) ($2,114)

Net Purchased Pwr Expense $1,267,869 $726,180 $359,148 $80,007 $33,504 $251,511 $2,010 $522,076 $78,665 $50,176 $127,480 $263,480 $2,275 $19,613

Average at Generation ---- $0.00545 $0.00551 $0.00551 $0.00551 $0.00551 $0.00551 $0.00551 $0.00551 $0.00551 $0.00551 $0.00551 $0.00325


Total Net Fuel & Purch. Pwr Exp. $9,180,150 $5,206,982 $2,575,227 $573,679 $240,235 $1,803,428 $14,413 $3,743,478 $564,058 $359,782 $914,078 $1,889,250 $16,310 $229,690

Average at Generation ---- ---- $0.03949 $0.03949 $0.03949 $0.03949 $0.03949 $0.03949 $0.03949 $0.03949 $0.03949 $0.03949 $0.03801


Exhibit 8 thru 10

Exhibit 8

Page 4 of 5

I I



Fuel & Purchased Power Recovery Billed $10,671,663 $7,678,792 $3,777,379 $835,009 $367,264 $2,678,690 $20,449 $2,763,181 $417,035 $265,991 $671,359 $1,396,744 $12,052 $229,690

F&PP Billed & Calculated Variance $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00

Billing Cycle Energy (Unadjusted)

kWh Billed 197,774,963 111,130,977 54,641,472 12,079,014 5,352,148 38,748,594 309,749 80,600,774 $12,122,514 $7,732,302 19,792,429 40,603,011 $350,518 6,043,212

Fuel Dollars Billed $9,626,686 $6,653,428 $3,273,038 $723,520 $318,239 $2,321,041 $17,590 $2,763,181 $417,035 $265,991 $671,359 $1,396,744 $12,052 $210,077

$ / kWh - - $0.05990 $0.05990 $0.05946 $0.05990 $0.05990 - $0.03440 $0.03440 $0.03392 $0.03440 $0.03440 -

Purchased Power Dollars Billed $771,702 $752,089 $369,923 $81,775 $35,966 $262,328 $2,097 $0 $0 $0 $0 $0 $0 $19,613

$ / kWh - - $0.00677 $0.00677 $0.00672 $0.00677 $0.00677 - $0.00000 $0.00000 $0.00000 $0.00000 $0.00000 -

Renewable Adj Dollars Billed $273,275 $273,275 $134,418 $29,714 $13,059 $95,322 $762 $0 $0 $0 $0 $0 $0 -

$ / kWh - - $0.00246 $0.00246 $0.00244 $0.00246 $0.00246 - $0.00000 $0.00000 $0.00000 $0.00000 $0.00000 -

Reverse Prior Month's Accruals

Accrued kWh 38,872,035 38,872,035 17,837,327 3,939,700 399,540 16,695,468 - 0 0 0 0 0 - -

Accrued Fuel Dollars $1,580,413 $1,580,413 $725,266 $160,188 $16,121 $678,838 - $0 $0 $0 $0 $0 - -

$ / kWh - - $0.04066 $0.04066 $0.04035 $0.04066 - - $0.04119 $0.04119 $0.04061 $0.04119 - -

Accrued Purchased Power Dollars $887,769 $887,769 $407,405 $89,983 $9,058 $381,324 - $0 $0 $0 $0 $0 - -

$ / kWh - - $0.02284 $0.02284 $0.02267 $0.02284 - - $0.00000 $0.00000 $0.00000 $0.00000 - -

Accrued Renewable Adj Dollars $62,969 $62,969 $28,896 $6,382 $643 $27,047 - $0 $0 $0 $0 $0 - -

$ / kWh - - $0.00162 $0.00162 $0.00161 $0.00162 - - $0.00000 $0.00000 $0.00000 $0.00000 - -

Accrue Current Month's Unbilled Sales

Unbilled kWh 53,882,760 53,882,760 30,578,584 6,349,550 249,180 16,705,446 - 0 0 0 0 0 - -

Unbilled Fuel Dollars $3,227,468 $3,227,468 $1,831,657 $380,338 $14,816 $1,000,656 - $0 $0 $0 $0 $0 - -

$ / kWh - - $0.05990 $0.05990 $0.05946 $0.05990 - - $0.03440 $0.03440 $0.03392 $0.03440 - -

Unbilled Purchased Power Dollars $364,774 $364,774 $207,017 $42,986 $1,674 $113,096 - $0 $0 $0 $0 $0 - -

$ / kWh - - $0.00677 $0.00677 $0.00672 $0.00677 - - $0.00000 $0.00000 $0.00000 $0.00000 - -

Unbilled Renewable Adj Dollars $132,547 $132,547 $75,223 $15,620 $608 $41,095 - $0 $0 $0 $0 $0 - -

$ / kWh - - $0.00246 $0.00246 $0.00244 $0.00246 - - $0.00000 $0.00000 $0.00000 $0.00000 - -

Total Fuel & Purch. Pwr. Recovery

Current Month kWh Sales at Delivery 212,785,688 126,141,702 67,382,729 14,488,864 5,201,788 38,758,572 309,749 80,600,774 12,122,514 7,732,302 19,792,429 40,603,011 350,518 6,043,212

Current Month Fuel Cost Recovery $11,273,740 $8,300,482 $4,379,430 $943,670 $316,934 $2,642,859 $17,590 $2,763,181 $417,035 $265,991 $671,359 $1,396,744 $12,052 $210,077

Current Month Purch. Power Recovery $248,707 $229,094 $169,535 $34,779 $28,583 ($5,901) $2,097 $0 $0 $0 $0 $0 $0 $19,613

Current Month Renewable Adj Recovery $342,853 $342,853 $180,745 $38,952 $13,024 $109,370 $762 $0 $0 $0 $0 $0 $0 $0

Total System Recovery ---- $11,865,300 $8,872,429 $4,729,710 $1,017,400 $358,541 $2,746,329 $20,449 $2,763,181 $417,035 $265,991 $671,359 $1,396,744 $12,052 $229,690

Month Balance

Fuel & Purch. Power Costs ---- $9,180,150 $5,206,982 $2,575,227 $573,679 $240,235 $1,803,428 $14,413 $3,743,478 $564,058 $359,782 $914,078 $1,889,250 $16,310 $229,690

Fuel & Purch. Pwr Recovery ---- $11,865,300 $8,872,429 $4,729,710 $1,017,400 $358,541 $2,746,329 $20,449 $2,763,181 $417,035 $265,991 $671,359 $1,396,744 $12,052 $229,690

Under / (Over) Recovery ---- ($2,685,150) ($3,665,447) ($2,154,483) ($443,721) ($118,306) ($942,901) ($6,036) $980,296 $147,023 $93,791 $242,719 $492,506 $4,257 ($0)

Exhibit 8 thru 10

Exhibit 8

Page 5 of 5

I

EXHIBIT 09




February-20




EE_2_01 Energy - All 100.0000% 97.4133% 50.3920% 23.8301% 5.7056% 2.2911% 18.4352% 0.1300% 47.0213% 7.2558% 4.7028% 10.4513% 24.4537% 0.1577% 2.5867%

kWh - Generation 199,709,366 194,543,550 100,637,520 47,591,001 11,394,589 4,575,455 36,816,845 259,630 93,906,029 14,490,591 9,391,867 20,872,132 48,836,401 315,039 5,165,816

Losses - G&T 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580

kWh - G&T 194,538,532 189,506,468 98,031,834 46,358,785 11,099,563 4,456,988 35,863,591 252,908 91,474,633 14,115,403 9,148,695 20,331,715 47,571,938 306,882 5,032,064

Losses - Distribution 6,828,338 6,828,338 3,532,304 1,670,410 399,942 160,595 1,292,245 9,113 3,296,034 508,609 329,648 732,597 1,714,122 11,058 ----

kWh - Primary 1

182,678,129 182,678,129 94,499,530 44,688,375 10,699,621 4,296,393 34,571,346 243,795 88,178,599 13,606,794 8,819,047 19,599,118 45,857,816 295,824 ----

Losses - Pri to Sec 1,182,630 1,182,630 671,843 332,844 79,692 ---- 257,491 1,816 510,787 101,345 65,685 ---- 341,554 2,203 ----

kWh - Secondary 157,599,988 157,599,988 89,531,294 44,355,531 10,619,929 ---- 34,313,855 241,979 68,068,694 13,505,449 8,753,362 ---- 45,516,262 293,621 ----

EE_2_02 Energy - Retail 100.0000% 100.0000% 51.7301% 24.4629% 5.8571% 2.3519% 18.9247% 0.1335% 48.2699% 7.4485% 4.8276% 10.7288% 25.1031% 0.1619% ----

194,543,550 194,543,550 100,637,520 47,591,001 11,394,589 4,575,455 36,816,845 259,630 93,906,029 14,490,591 9,391,867 20,872,132 48,836,401 315,039 ----


SES 199,709,366 194,543,550 100,637,520 47,591,001 11,394,589 4,575,455 36,816,845 259,630 93,906,029 14,490,591 9,391,867 20,872,132 48,836,401 315,039 5,165,816

EE_2_04 Bradley Lake 100.0000% 97.4133% 50.3920% 23.8301% 5.7056% 2.2911% 18.4352% 0.1300% 47.0213% 7.2558% 4.7028% 10.4513% 24.4537% 0.1577% 2.5867%

Generation 30,772,040 29,976,070 15,506,643 7,333,017 1,755,725 705,005 5,672,891 40,005 14,469,427 2,232,770 1,447,138 3,216,064 7,524,913 48,542 795,970


Bradley Lake 168,937,326 164,567,480 85,130,878 40,257,984 9,638,864 3,870,450 31,143,954 219,625 79,436,602 12,257,821 7,944,730 17,656,068 41,311,487 266,496 4,369,846


Generation 5,161,280 5,161,280 2,669,934 1,262,599 302,301 121,388 976,758 6,888 2,491,346 384,438 249,168 553,742 1,295,640 8,358 ----

EE_2_07 Energy, Excl. B/L 100.0000% 97.3318% 50.3498% 23.8102% 5.7008% 2.2891% 18.4198% 0.1299% 46.9820% 7.2498% 4.6988% 10.4425% 24.4333% 0.1576% 2.6682%


Total Percent

Fuel Expense (Net of Economy) $7,098,890 81.1431% Losses: Total Percent

Generation - Purch Pwr Expense$1,649,718 18.8569% Retail 13,048,051 6.7%

Fuel & PP Expense $8,748,607 100.0000% System 13,181,803 6.6%

Exhibit 8 thru 10

Exhibit 9

Page 1 of 5




February-20

Allocation System South District North District

Description Factor Total Total South Residential SGS LGS-P LGS-S Lighting Total North Residential SGS LGS-P LGS-S Lighting Seward

Fuel Expense

BRU (Chugach)


Beluga Power Plant EE_2_07 $4,416 $2,224 $1,052 $252 $101 $813 $6 $2,075 $320 $208 $461 $1,079 $7 $118


Plant 1 EE_2_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2 EE_2_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2A EE_2_07 $629,693 $317,049 $149,931 $35,898 $14,415 $115,988 $818 $295,842 $45,651 $29,588 $65,756 $153,855 $993 $16,801


Subtotal $759,687 $382,501 $180,883 $43,308 $17,390 $139,933 $987 $356,916 $55,076 $35,696 $79,330 $185,616 $1,197 $20,270





Plant 1 EE_2_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2 EE_2_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2A EE_2_07 $569,833 $286,910 $135,678 $32,485 $13,044 $104,962 $740 $267,719 $41,312 $26,775 $59,505 $139,229 $898 $15,204


Subtotal $3,685,902 $1,855,845 $877,620 $210,126 $84,375 $678,935 $4,788 $1,731,710 $267,219 $173,194 $384,901 $900,586 $5,810 $98,347

Furie Alaska, LLC




Plant 1 EE_2_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2 EE_2_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2A EE_2_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0


Subtotal $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Exhibit 8 thru 10

Exhibit 9

Page 2 of 5

I I







Plant 1 EE_2_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2 EE_2_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2A EE_2_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0


Subtotal $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

AIX




Plant 1 EE_2_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2 EE_2_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2A EE_2_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0


Subtotal $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0



Beluga Power Plant EE_2_07 $31,973 $16,098 $7,613 $1,823 $732 $5,889 $42 $15,022 $2,318 $1,502 $3,339 $7,812 $50 $853

IGT EE_2_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 1 EE_2_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2 EE_2_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2A EE_2_07 $1,012,360 $509,721 $241,045 $57,713 $23,174 $186,475 $1,315 $475,627 $73,394 $47,569 $105,716 $247,353 $1,596 $27,012


Subtotal $1,864,794 $938,920 $444,011 $106,308 $42,688 $343,491 $2,422 $876,118 $135,193 $87,624 $194,731 $455,630 $2,939 $49,756


FSS and ISS EE_2_07 $334,039 $168,188 $79,535 $19,043 $7,647 $61,529 $434 $156,938 $24,217 $15,696 $34,882 $81,617 $527 $8,913

Subtotal $334,039 $168,188 $79,535 $19,043 $7,647 $61,529 $434 $156,938 $24,217 $15,696 $34,882 $81,617 $527 $8,913


Diesel Fuel $681 $343 $162 $39 $16 $125 $1 $320 $49 $32 $71 $166 $1 $18

Emergency Generator 0.00 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Subtotal $681 $343 $162 $39 $16 $125 $1 $320 $49 $32 $71 $166 $1 $18

Total Fuel $6,645,103 $3,345,797 $1,582,212 $378,825 $152,116 $1,224,014 $8,632 $3,122,002 $481,755 $312,242 $693,915 $1,623,616 $10,474 $177,304

Exhibit 8 thru 10

Exhibit 9

Page 3 of 5

I I




Fuel Transportation EE_2_07 $482,204 $242,789 $114,814 $27,490 $11,038 $88,821 $626 $226,549 $34,959 $22,658 $50,354 $117,818 $760 $12,866

Subtotal $482,204 $242,789 $114,814 $27,490 $11,038 $88,821 $626 $226,549 $34,959 $22,658 $50,354 $117,818 $760 $12,866


Less Fuel Credits

Economy Fuel Costs EE_2_07 ($28,418) ($14,308) ($6,766) ($1,620) ($651) ($5,234) ($37) ($13,351) ($2,060) ($1,335) ($2,968) ($6,943) ($45) ($758)

Economy Margins EE_2_07 ($47,332) ($23,831) ($11,270) ($2,698) ($1,083) ($8,718) ($61) ($22,237) ($3,431) ($2,224) ($4,943) ($11,565) ($75) ($1,263)

EGS (Pool) EE_2_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0


Exchange Credits EE_2_07 ($27,053) ($13,621) ($6,441) ($1,542) ($619) ($4,983) ($35) ($12,710) ($1,961) ($1,271) ($2,825) ($6,610) ($43) ($722)

Subtotal ($275,579) ($138,754) ($65,616) ($15,710) ($6,308) ($50,761) ($358) ($129,473) ($19,979) ($12,949) ($28,777) ($67,333) ($434) ($7,353)

Net Fuel and Transportation $6,851,728 $3,449,833 $1,631,409 $390,604 $156,846 $1,262,074 $8,900 $3,219,079 $496,734 $321,951 $715,492 $1,674,101 $10,799 $182,817

Average at Generation $0.03522 $0.03428 $0.03428 $0.03428 $0.03428 $0.03428 $0.03428 $0.00529 $0.02222 $0.07618 $0.08021 $0.00022 $0.00374

Average at Delivery ---- ---- $0.03677 $0.01822 $0.00881 $0.01466 #VALUE! $0.00026 $13 $2.05280 $0.00473 $0.05258 $0.19125 $0.00024 $0








Subtotal ---- $1,649,718 $839,137 $396,824 $95,010 $38,151 $306,987 $2,165 $783,008 $120,826 $78,311 $174,036 $407,208 $2,627 $27,573


Wheeling Revenue EE_2_07 ($40,152) ($20,216) ($9,560) ($2,289) ($919) ($7,396) ($52) ($18,864) ($2,911) ($1,887) ($4,193) ($9,810) ($63) ($1,071)

AWWU Water Sales EE_2_07 ($40,423) ($20,353) ($9,625) ($2,304) ($925) ($7,446) ($53) ($18,992) ($2,931) ($1,899) ($4,221) ($9,877) ($64) ($1,079)


Subtotal ($80,575) ($40,569) ($19,185) ($4,593) ($1,844) ($14,842) ($105) ($37,856) ($5,841) ($3,786) ($8,414) ($19,687) ($127) ($2,150)

Net Purchased Power Expense $1,569,143 $798,568 $377,639 $90,417 $36,307 $292,145 $2,060 $745,153 $114,984 $74,525 $165,622 $387,521 $2,500 $25,423

Average at Generation ---- $0.00807 $0.00794 $0.00794 $0.00794 $0.00794 $0.00794 $0.00794 $0.00794 $0.00794 $0.00794 $0.00794 $0.00794 $0.00794 $0.00492

Average at Delivery ---- ---- $0 $0.00851 $0.00851 $0.00845 $0.00851 $0.00851 $0.01095 $0.00851 $0.00851 $0.00845 $0.00851 $0.00851 $0.00505

Total Net Fuel & Purch. Pwer Exp. $8,420,871 $4,248,400 $2,009,048 $481,021 $193,152 $1,554,218 $10,960 $3,964,231 $611,718 $396,476 $881,114 $2,061,622 $13,299 $208,239


Average at Delivery $0.04745 $0.04529 $0.04529 $0.04496 $0.04529 $0.04529 $0.05824 $0.04529 $0.04529 $0.04496 $0.04529 $0.04529 $0.04138

Exhibit 8 thru 10

Exhibit 9

Page 4 of 5

I I



Fuel & Purch Pwr Recovery (Billed) $10,407,725 $7,193,166 $3,539,756 $815,274 $288,153 $2,533,333 $16,651 $3,006,319 $464,587 $301,116 $664,802 $1,565,601 $10,213 $208,239

F&PP Billed and Calculated Variance $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00

Unadjusted Billing Data

kWh Billed 248,839,359 107,875,405 54,641,472 12,079,014 4,199,253 36,645,917 309,749 92,127,553 $13,505,449 $6,753,362 19,599,118 45,516,262 ######### 48,836,401


$ / kWh - - $0.05990 $0.05990 $0.05946 $0.05990 $0.05990 - $0.03440 $0.03440 $0.03392 $0.03440 $0.03440 -


$ / kWh - - $0.00677 $0.00677 $0.00672 $0.00677 $0.00677 - $0.00000 $0.00000 $0.00000 $0.00000 $0.00000 -


$ / kWh - - $0.00246 $0.00246 $0.00244 $0.00246 $0.00246 - $0.00000 $0.00000 $0.00000 $0.00000 $0.00000 -


Accrued kWh 53,882,760 53,882,760 30,578,584 6,349,550 249,180 16,705,446 - 0 0 0 0 0 - -

Accrued Fuel Dollars $3,227,468 $3,227,468 $1,831,657 $380,338 $14,816 $1,000,656 - $0 $0 $0 $0 $0 - -

$ / kWh - - $0.05990 $0.05990 $0.05946 $0.05990 - - $0.03440 $0.03440 $0.03392 $0.03440 - -


$ / kWh - - $0.00677 $0.00677 $0.00672 $0.00677 - - $0.00000 $0.00000 $0.00000 $0.00000 - -


$ / kWh - - $0.00246 $0.00246 $0.00244 $0.00246 - - $0.00000 $0.00000 $0.00000 $0.00000 - -


Unbilled kWh 51,647,838 51,647,838 30,578,584 6,349,550 346,320 14,373,384 - 0 0 0 0 0 - -

Unbilled Fuel Dollars $3,093,553 $3,093,553 $1,831,657 $380,338 $20,592 $860,966 - $0 $0 $0 $0 $0 - -

$ / kWh - - $0.05990 $0.05990 $0.05946 $0.05990 - - $0.03440 $0.03440 $0.03392 $0.03440 - -

Unbilled Purchased Power Dollars $349,639 $349,639 $207,017 $42,986 $2,327 $97,308 - $0 $0 $0 $0 $0 - -

$ / kWh - - $0.00677 $0.00677 $0.00672 $0.00677 - - $0.00000 $0.00000 $0.00000 $0.00000 - -

Unbilled Renewable Adj Dollars $127,047 $127,047 $75,223 $15,620 $845 $35,359 - $0 $0 $0 $0 $0 - -

$ / kWh - - $0.00246 $0.00246 $0.00244 $0.00246 - - $0.00000 $0.00000 $0.00000 $0.00000 - -


Current Month kWh Sales at Delivery246,604,437 105,640,483 54,641,472 12,079,014 4,296,393 34,313,855 309,749 92,127,553 13,505,449 6,753,362 19,599,118 45,516,262 6,753,362 48,836,401


Current Month Purch. Power Rec $740,394 $714,971 $369,923 $81,775 $28,872 $232,305 $2,097 $0 $0 $0 $0 $0 $0 $25,423

Current Month Renewable Adj Rec $259,790 $259,790 $134,418 $29,714 $10,483 $84,412 $762 $0 $0 $0 $0 $0 $0 $0

Total System Recovery $10,253,175 $7,038,617 $3,539,756 $815,274 $294,818 $2,372,117 $16,651 $3,006,319 $464,587 $301,116 $664,802 $1,565,601 $10,213 $208,239

Month Balance

Fuel & Purch. Power Costs $8,420,871 $4,248,400 $2,009,048 $481,021 $193,152 $1,554,218 $10,960 $3,964,231 $611,718 $396,476 $881,114 $2,061,622 $13,299 $208,239

Fuel & Purch. Pwr Recovery $10,253,175 $7,038,617 $3,539,756 $815,274 $294,818 $2,372,117 $16,651 $3,006,319 $464,587 $301,116 $664,802 $1,565,601 $10,213 $208,239

Under / (Over) Recovery ($1,832,304) ($2,790,217) ($1,530,707) ($334,253) ($101,666) ($817,899) ($5,691) $957,912 $147,131 $95,361 $216,312 $496,021 $3,087 $0

Exhibit 8 thru 10

Exhibit 9

Page 5 of 5

I

EXHIBIT 10

Chugach Electric Association, Inc.Fuel and Purchased Power Rate Adjustment Filing: Tariff Advice No. 495-8

Fuel & Purchased Power Cost Assignment: 0.9584

March 2020




EE_3_01 Energy - All 100.0000% 97.3120% 53.2548% 25.6040% 5.8462% 2.4493% 19.2427% 0.1126% 44.0572% 6.5327% 4.3938% 9.2434% 23.7541% 0.1332% 2.6880%

kWh - Generation 198,783,393 193,440,162 105,861,722 50,896,408 11,621,334 4,868,766 38,251,352 223,862 87,578,441 12,985,905 8,734,157 18,374,312 47,219,206 264,861 5,343,231

Losses - G&T 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580 1.026580

kWh - G&T 193,636,534 188,431,649 103,120,771 49,578,608 11,320,437 4,742,704 37,260,956 218,065 85,310,878 12,649,676 8,508,014 17,898,568 45,996,616 258,004 5,204,885

Losses - Distrib 14,211,702 14,211,702 7,777,471 3,739,268 853,799 357,699 2,810,258 16,447 6,434,231 954,051 641,683 1,349,928 3,469,110 19,459 ----

kWh - Primary 1

174,219,947 174,219,947 95,343,300 45,839,340 10,466,639 4,385,005 34,450,698 201,619 78,876,647 11,695,625 7,866,331 16,548,640 42,527,506 238,545 ----

Losses - Pri to Sec 1,605,919 1,605,919 677,467 341,416 77,957 ---- 256,593 1,502 464,226 87,110 58,589 ---- 316,750 1,777 ----

kWh - Secondary 214,008,390 214,008,390 90,280,828 45,497,924 10,388,682 ---- 34,194,105 200,117 61,863,781 11,608,515 7,807,742 ---- 42,210,756 236,768 ----

EE_3_02 Energy - Retail 100.0000% 100.0000% 54.7258% 26.3112% 6.0077% 2.5169% 19.7743% 0.1157% 45.2742% 6.7131% 4.5152% 9.4987% 24.4102% 0.1369% ----

193,440,164 193,440,164 105,861,722 50,896,408 11,621,334 4,868,766 38,251,352 223,862 87,578,441 12,985,905 8,734,157 18,374,312 47,219,206 264,861 ----


SES 198,783,395 193,440,164 105,861,722 50,896,408 11,621,334 4,868,766 38,251,352 223,862 87,578,441 12,985,905 8,734,157 18,374,312 47,219,206 264,861 5,343,231

EE_3_04 Bradley Lake 100.0000% 97.3120% 53.2548% 25.6040% 5.8462% 2.4493% 19.2427% 0.1126% 44.0572% 6.5327% 4.3938% 9.2434% 23.7541% 0.1332% 2.6880%

Generation 30,281,320 29,467,369 16,126,261 7,753,215 1,770,316 741,675 5,826,953 34,102 13,341,108 1,978,185 1,330,502 2,799,019 7,193,055 40,347 813,952


Bradley Lake 168,502,073 163,972,795 89,735,461 43,143,193 9,851,018 4,127,091 32,424,399 189,760 74,237,333 11,007,720 7,403,655 15,575,293 40,026,151 224,514 4,529,279


Generation 3,257,090 3,257,090 1,782,469 856,979 195,677 81,979 644,065 3,769 1,474,621 218,653 147,063 309,381 795,063 4,460 ----

EE_3_07 Energy, Excl. B/L 100.0000% 97.2591% 53.2258% 25.5900% 5.8430% 2.4479% 19.2323% 0.1126% 44.0332% 6.5291% 4.3914% 9.2384% 23.7412% 0.1332% 2.7409%


Total Percent

$6,760,207 82.0785% Losses: Total Percent

$1,476,059 17.9215% Retail 20,826,134 10.8%

$8,236,265 100.0000% System 20,964,479 10.5%

Exhibit 8 thru 10

Exhibit 10

Page 1 of 5




March-20



Fuel Expense

BRU (Chugach)


Beluga Power Plant EE_3_07 $5,923 $3,153 $1,516 $346 $145 $1,139 $7 $2,608 $387 $260 $547 $1,406 $8 $162

IGT Power Plant EE_3_07 $1,565 $833 $400 $91 $38 $301 $2 $689 $102 $69 $145 $371 $2 $43

Plant 1 EE_3_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2 EE_3_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2A EE_3_07 $664,641 $353,761 $170,082 $38,835 $16,270 $127,826 $748 $292,663 $43,395 $29,187 $61,402 $157,794 $885 $18,217


Subtotal $814,317 $433,427 $208,384 $47,581 $19,934 $156,612 $917 $358,570 $53,168 $35,760 $75,229 $193,328 $1,084 $22,320




IGT Power Plant EE_3_07 $37,965 $20,207 $9,715 $2,218 $929 $7,302 $43 $16,717 $2,479 $1,667 $3,507 $9,013 $51 $1,041

Plant 1 EE_3_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2 EE_3_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2A EE_3_07 $273,615 $145,634 $70,018 $15,987 $6,698 $52,622 $308 $120,482 $17,865 $12,016 $25,278 $64,959 $364 $7,500

Gas Adjustment(s) EE_3_07 $2,175 $1,158 $557 $127 $53 $418 $2 $958 $142 $96 $201 $516 $3 $60

Subtotal $3,835,230 $2,041,332 $981,436 $224,094 $93,884 $737,601 $4,317 $1,688,776 $250,407 $168,421 $354,312 $910,528 $5,107 $105,122

Furie Alaska, LLC




Plant 1 EE_3_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2 EE_3_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2A EE_3_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0


Subtotal $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Exhibit 8 thru 10

Exhibit 10

Page 2 of 5

I I







Plant 1 EE_3_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2 EE_3_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2A EE_3_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0


Subtotal $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

AIX




Plant 1 EE_3_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2 EE_3_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2A EE_3_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0


Subtotal $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0



Beluga Power Plant EE_3_07 $40,444 $21,527 $10,350 $2,363 $990 $7,778 $46 $17,809 $2,641 $1,776 $3,736 $9,602 $54 $1,109

IGT EE_3_07 $5,831 $3,104 $1,492 $341 $143 $1,121 $7 $2,568 $381 $256 $539 $1,384 $8 $160

Plant 1 EE_3_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2 EE_3_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Plant 2A EE_3_07 $760,836 $404,961 $194,698 $44,456 $18,625 $146,326 $856 $335,021 $49,676 $33,411 $70,289 $180,631 $1,013 $20,854


Subtotal $1,310,560 $697,556 $335,373 $76,577 $32,082 $252,050 $1,475 $577,082 $85,568 $57,552 $121,074 $311,142 $1,745 $35,922


FSS and ISS EE_3_07 $312,187 $166,164 $79,889 $18,241 $7,642 $60,041 $351 $137,466 $20,383 $13,709 $28,841 $74,117 $416 $8,557

Subtotal $312,187 $166,164 $79,889 $18,241 $7,642 $60,041 $351 $137,466 $20,383 $13,709 $28,841 $74,117 $416 $8,557


Diesel Fuel $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Emergency Generator 0.00 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Subtotal $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Total Fuel $6,272,294 $3,338,480 $1,605,081 $366,493 $153,543 $1,206,304 $7,060 $2,761,894 $409,527 $275,442 $579,457 $1,489,116 $8,353 $171,920

Exhibit 8 thru 10

Exhibit 10

Page 3 of 5

I I




Fuel Transportation EE_3_07 $489,891 $260,749 $125,363 $28,625 $11,992 $94,217 $551 $215,715 $31,986 $21,513 $45,258 $116,306 $652 $13,428

Subtotal $489,891 $260,749 $125,363 $28,625 $11,992 $94,217 $551 $215,715 $31,986 $21,513 $45,258 $116,306 $652 $13,428


Less Fuel Credits

Economy Fuel Costs EE_3_07 ($1,979) ($1,053) ($506) ($116) ($48) ($381) ($2) ($871) ($129) ($87) ($183) ($470) ($3) ($54)

Economy Margins EE_3_07 ($9,052) ($4,818) ($2,316) ($529) ($222) ($1,741) ($10) ($3,986) ($591) ($398) ($836) ($2,149) ($12) ($248)

EGS (Pool) EE_3_07 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0


Exchange Credits EE_3_07 ($27,344) ($14,554) ($6,997) ($1,598) ($669) ($5,259) ($31) ($12,041) ($1,785) ($1,201) ($2,526) ($6,492) ($36) ($749)

Subtotal ($177,929) ($94,704) ($45,532) ($10,396) ($4,356) ($34,220) ($200) ($78,348) ($11,617) ($7,814) ($16,438) ($42,242) ($237) ($4,877)

Net Fuel and Transportation $6,584,257 $3,504,524 $1,684,912 $384,721 $161,179 $1,266,301 $7,411 $2,899,261 $429,895 $289,142 $608,277 $1,563,179 $8,768 $180,471


Average at Delivery ---- ---- $0.03882 $0.03703 $0.03703 $0.03676 $0.03703 $0.03703 $0.03703 $0.03703 $0.03676 $0.03703 $0.03703 $0








Subtotal ---- $1,476,059 $791,967 $380,764 $86,941 $36,424 $286,164 $1,675 $655,187 $97,149 $65,342 $137,461 $353,254 $1,981 $28,904


Wheeling Revenue EE_3_07 ($30,471) ($16,218) ($7,798) ($1,780) ($746) ($5,860) ($34) ($13,417) ($1,989) ($1,338) ($2,815) ($7,234) ($41) ($835)

AWWU Water Sales EE_3_07 ($46,849) ($24,936) ($11,989) ($2,737) ($1,147) ($9,010) ($53) ($20,629) ($3,059) ($2,057) ($4,328) ($11,123) ($62) ($1,284)


Subtotal ($77,320) ($41,154) ($19,786) ($4,518) ($1,893) ($14,870) ($87) ($34,047) ($5,048) ($3,395) ($7,143) ($18,357) ($103) ($2,119)

Net Purchased Power Expense $1,398,738 $750,813 $360,977 $82,423 $34,531 $271,294 $1,588 $621,141 $92,101 $61,946 $130,318 $334,897 $1,878 $26,784


Average at Delivery ---- ---- $0 $0.03475 $0.01880 $0.00787 $0.00439 $0.00793 $0.00793 $0.00793 $0.00787 $0.00793 $0.00793 $0.00515

Total Net Fuel & Purch. Pwer Exp. $7,982,995 $4,255,337 $2,045,890 $467,144 $195,710 $1,537,595 $8,999 $3,520,402 $521,996 $351,088 $738,595 $1,898,077 $10,647 $207,256

Average at Generation $0.04020 $0.04020 $0.04020 $0.04020 $0.04020 $0.04020 $0.04020 $0.04020 $0.04020 $0.04020 $0.04020 $0.03879

Average at Delivery $0.04713 $0.04497 $0.04497 $0.04463 $0.04497 $0.04497 $0.04497 $0.04497 $0.04463 $0.04497 $0.04497 $0.03982

Exhibit 8 thru 10

Exhibit 10

Page 4 of 5

I I



Fuel & Purch Pwr Recovery (Billed) $9,367,615 $6,471,001 $3,046,749 $728,459 $310,278 $2,371,622 $13,892 $2,689,359 $399,386 $268,586 $561,330 $1,451,915 $8,142 $207,255

F&PP Billed and Calculated Variance $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00

Unadjusted Billing Data

kWh Billed 177,111,389 93,638,676 44,072,661 10,537,509 4,521,685 34,306,704 200,117 78,412,421 $11,608,515 $7,807,742 16,548,640 42,210,756 $236,768 5,060,292


$ / kWh - - $0.05990 $0.05990 $0.05946 $0.05990 $0.05990 - $0.03440 $0.03440 $0.03392 $0.03440 $0.03440 -


$ / kWh - - $0.00677 $0.00677 $0.00672 $0.00677 $0.00677 - $0.00000 $0.00000 $0.00000 $0.00000 $0.00000 -


$ / kWh - - $0.00246 $0.00246 $0.00244 $0.00246 $0.00246 - $0.00000 $0.00000 $0.00000 $0.00000 $0.00000 -


Accrued kWh 51,647,838 51,647,838 30,578,584 6,349,550 346,320 14,373,384 - 0 0 0 0 0 - -

Accrued Fuel Dollars $3,093,553 $3,093,553 $1,831,657 $380,338 $20,592 $860,966 - $0 $0 $0 $0 $0 - -

$ / kWh - - $0.05990 $0.05990 $0.05946 $0.05990 - - $0.03440 $0.03440 $0.03392 $0.03440 - -


$ / kWh - - $0.00677 $0.00677 $0.00672 $0.00677 - - $0.00000 $0.00000 $0.00000 $0.00000 - -


$ / kWh - - $0.00246 $0.00246 $0.00244 $0.00246 - - $0.00000 $0.00000 $0.00000 $0.00000 - -


Unbilled kWh 44,652,643 44,652,643 25,154,981 5,027,237 209,640 14,260,785 - 0 0 0 0 0 - -

Unbilled Fuel Dollars $2,674,601 $2,674,601 $1,506,783 $301,131 $12,465 $854,221 - $0 $0 $0 $0 $0 - -

$ / kWh - - $0.05990 $0.05990 $0.05946 $0.05990 - - $0.03440 $0.03440 $0.03392 $0.03440 - -

Unbilled Purchased Power Dollars $10,678,903 $302,288 $170,299 $34,034 $1,409 $96,546 - $0 $0 $0 $0 $0 - -

$ / kWh - - $0.00677 $0.00677 $0.00672 $0.00677 - - $0.00000 $0.00000 $0.00000 $0.00000 - -

Unbilled Renewable Adj Dollars $10,678,903 $109,841 $61,881 $12,367 $512 $35,082 - $0 $0 $0 $0 $0 - -

$ / kWh - - $0.00246 $0.00246 $0.00244 $0.00246 - - $0.00000 $0.00000 $0.00000 $0.00000 - -


Current Month kWh Sales at Delivery170,116,194 86,643,481 38,649,058 9,215,196 4,385,005 34,194,105 200,117 78,412,421 11,608,515 7,807,742 16,548,640 42,210,756 236,768 5,060,292


Current Month Purch. Power Rec $613,142 $586,357 $261,654 $62,387 $29,467 $231,494 $1,355 $0 $0 $0 $0 $0 $0 $26,784

Current Month Renewable Adj Rec $213,055 $213,055 $95,077 $22,669 $10,699 $84,117 $492 $0 $0 $0 $0 $0 $0 $0

Total System Recovery $8,884,107 $5,987,492 $2,671,815 $637,047 $300,899 $2,363,838 $13,892 $2,689,359 $399,386 $268,586 $561,330 $1,451,915 $8,142 $207,255

Month Balance

Fuel & Purch. Power Costs ---- $7,982,995 $4,255,337 $2,045,890 $467,144 $195,710 $1,537,595 $8,999 $3,520,402 $521,996 $351,088 $738,595 $1,898,077 $10,647 $207,256

Fuel & Purch. Pwr Recovery ---- $8,884,107 $5,987,492 $2,671,815 $637,047 $300,899 $2,363,838 $13,892 $2,689,359 $399,386 $268,586 $2,363,838 $0 $8,142 $207,256

Under / (Over) Recovery ---- ($901,112) ($1,732,155) ($625,926) ($169,903) ($105,189) ($826,244) ($4,893) $831,043 $122,610 $82,502 ($1,625,244) $1,898,077 $2,504 $0

Exhibit 8 thru 10

Exhibit 10

Page 5 of 5

I

EXHIBIT 11



Fuel in Storage Account Balance


I. Volume of Gas (Mcf) in Storage (Excludes Gas Exchanges)

Net Injections Net Withdrawals

FSS ISS FSS ISS

Month Purchased Fuel Gas 1

Injection Transfer Inj Injection Transfer Inj Total Withdrawal Transfer W/D Withrawal Transfer W/D Total Adjustments Balance

Oct-18 67,585 743 66,842 - - - 66,842 26,022 - - - 26,022 1,509,542

Nov-18 78,104 859 77,245 - - - 77,245 11,606 - - - 11,606 1,575,181

Dec-18 41,625 458 41,167 - - - 41,167 60,841 - - - 60,841 1,555,507

Jan-19 21,312 234 21,078 - - - 21,078 150,830 - - - 150,830 1,425,755

Feb-19 16,784 185 16,599 - - - 16,599 119,156 - - - 119,156 1,323,198

Mar-19 19,252 212 19,040 - - - 19,040 77,946 - - - 77,946 1,264,292

Apr-19 46,440 511 45,929 7,834 - - 53,763 37,840 - - - 37,840 1,280,215

May-19 58,498 644 57,854 - - - 57,854 8,065 - - - 8,065 1,330,005

Jun-19 48,239 531 47,708 - - - 47,708 70,096 - - - 70,096 1,307,617

Jul-19 35,370 531 34,839 - - - 34,839 140,078 - - - 140,078 1,202,378

Aug-19 38,002 570 37,432 8,183 - - 45,615 97,563 - - - 97,563 1,150,430

Sep-19 103,572 1,554 102,019 - - - 102,019 43,242 - - - 43,242 1,209,207

Oct-19 254,245 3,814 250,431 - - - 250,431 24,419 - - - 24,419 1,435,219

Nov-19 206,267 3,094 203,173 - - 20,000 223,173 19,827 20,000 - - 39,827 1,618,565

Dec-19 91,265 1,369 27,134 31,343 62,762 20,000 141,239 45,614 20,000 71,419 31,343 168,376 1,591,428

Jan-20 2,626 39 2,587 - - - 2,587 313,695 - - - 313,695 1,280,320

Feb-20 13,702 206 13,497 - - - 13,497 113,096 - - - 113,096 1,180,720

Mar-20 20,738 311 20,427 - - - 20,427 72,216 - - - 72,216 1,128,931 1

Gas used for CINGSA injection services.

Exhibit 11

8/26/2020 12:10 PM

Exhibit 11

Page 1 of 4

I I I I

I I I I





II. Value of Gas in Storage (Excludes Gas Exchanges)

Net Injections 1

Net Withdrawals

FSS ISS FSS ISS

Month Injection Transfer Inj Injection Transfer Inj Total Withdrawal Transfer W/D Withdrawal Transfer W/D Total Adjustment 2

Balance Price

Oct-18 $522,736 $0 $0 $0 $522,736 $199,621 $0 $0 $0 $199,621 $0 $11,577,007 $7.67

Nov-18 $604,095 $0 $0 $0 $604,095 $89,009 $0 $0 $0 $89,009 $0 $12,092,093 $7.68

Dec-18 $321,948 $0 $0 $0 $321,948 $462,404 $0 $0 $0 $462,404 $0 $11,951,637 $7.68

Jan-19 $164,838 $0 $0 $0 $164,838 $1,158,892 $0 $0 $0 $1,158,892 $0 $10,957,583 $7.69

Feb-19 $129,816 $0 $0 $0 $129,816 $915,768 $0 $0 $0 $915,768 $0 $10,171,630 $7.69

Mar-19 $148,879 $0 $0 $0 $148,879 $599,183 $0 $0 $0 $599,183 $0 $9,721,326 $7.69

Apr-19 $364,352 $0 $0 $0 $364,352 $290,957 $0 $0 $0 $290,957 $0 $9,794,721 $7.65

May-19 $460,531 $0 $0 $0 $460,531 $71,860 $0 $0 $0 $71,860 $4,840 $10,188,233 $7.66

Jun-19 $378,551 $0 $0 $0 $378,551 $563,669 $0 $0 $0 $563,669 $75 $10,003,190 $7.65

Jul-19 $275,714 $0 $0 $0 $275,714 $1,116,426 $0 $0 $0 $1,116,426 $63,662 $9,226,140 $7.67

Aug-19 $296,113 $0 $0 $0 $296,113 $753,918 $0 $0 $0 $753,918 $10,267 $8,778,602 $7.63

Sep-19 $772,336 $0 $0 $0 $772,336 $331,625 $0 $0 $0 $331,625 $2,871 $9,222,183 $7.63

Oct-19 $1,966,517 $0 $0 $0 $1,966,517 $201,276 $0 $0 $0 $201,276 ($1,065) $10,986,358 $7.65

Nov-19 $1,624,960 $0 $0 $153,096 $1,778,056 $151,772 $153,096 $0 $0 $304,869 ($3,158) $12,456,387 $7.70

Dec-19 $216,595 $248,785 $636,174 $20,000 $1,121,554 $363,910 $153,929 $560,486 $248,785 $1,327,110 ($481) $12,250,350 $7.70

Jan-20 $21,688 $0 $0 $0 $21,688 $2,455,182 $0 $0 $0 $2,455,182 ($293) $9,816,563 $7.67

Feb-20 $111,995 $0 $0 $0 $111,995 $867,822 $0 $0 $0 $867,822 ($1,187) $9,059,549 $7.67

Mar-20 $167,340 $0 $0 $0 $167,340 $554,106 $0 $0 $0 $554,106 ($736) $8,672,047 $7.68

1 Includes transportation costs into storage and storage injection fees.

2 Includes prior month dollar adjustment to balance CINGSA storage cost.

Exhibit 11

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Exhibit 11

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I I I I

I I I I





III. Gas Exchange Transaction Summary

Exchange Gas Volume (Mcf) Value of Exchange Gas in Storage

Gas Withdrawn to Gas Injected from Cumulative Cumulative Balance Gas Withdrawn to Gas Injected from Cumulative Cumulative Balance

Month Exchange Customer Exchange Customer Exchange Balance (Native and Exchange) Exchange Customer Exchange Customer Adjustment2

Exchange Balance (Native and Exchange) Price

Oct-18 7,558 - 1,132 1,508,410 $58,261 $0 $0 $6,609 $11,570,398 $7.67

Nov-18 - - 1,132 1,574,049 $0 $0 $0 $6,609 $12,085,484 $7.68

Dec-18 7,559 - (6,426) 1,561,933 $53,374 $0 $0 ($46,765) $11,998,402 $7.68

Jan-19 - - (6,426) 1,432,181 $0 $0 $0 ($46,765) $11,004,348 $7.68

Feb-19 - - (6,426) 1,329,624 $0 $0 $0 ($46,765) $10,218,395 $7.69

Mar-19 - 692 (5,734) 1,270,026 $0 $5,388 $0 ($41,377) $9,762,703 $7.69

Apr-19 - 9,643 3,909 1,276,307 $0 $75,071 $0 $33,695 $9,761,027 $7.65

May-19 6,097 3,083 895 1,329,110 $56,801 $23,880 ($4,840) $5,614 $10,182,619 $7.66

Jun-19 16,128 8,275 (6,958) 1,314,575 $150,256 $64,179 ($75) ($80,388) $10,083,578 $7.67

Jul-19 13,315 13,879 (6,394) 1,208,773 $146,697 $107,501 ($63,662) ($55,922) $9,282,061 $7.68

Aug-19 7,235 17,224 3,595 1,146,836 $60,807 $133,825 $10,267 $27,363 $8,751,239 $7.63

Sep-19 3,008 4,813 5,400 1,203,807 $24,614 $37,189 $2,871 $42,808 $9,179,375 $7.63

Oct-19 21,559 985 (15,174) 1,450,393 $179,461 $7,650 ($1,065) ($130,068) $11,116,426 $7.66

Nov-19 - 20,915 5,741 1,612,824 $0 $177,797 ($3,158) $44,570 $12,411,816 $7.70

Dec-19 49,787 16,791 (27,255) 1,618,683 $415,276 $140,240 ($481) ($230,947) $12,481,297 $7.71

Jan-20 62,009 1,970 (87,294) 1,367,614 $517,777 $16,746 ($293) ($732,271) $10,548,833 $7.71

Feb-20 1,003 7,880 (80,417) 1,261,137 $8,373 $66,985 ($1,187) ($674,846) $9,734,395 $7.72

Mar-20 - 7,478 (72,939) 1,201,870 $0 $63,568 ($736) ($612,014) $9,284,061 $7.72

Exhibit 11

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Exhibit 11

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ML&P's Balance in Storage at March 31, 2020

Average

Description Volume (MMcf) Inventory Price

FSS 500 $3.18

ISS 15 $7.66

Exhibit 11

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Exhibit 11

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EXHIBIT 12




Projected Fuel Expense by Power Plant and Source

Power Plant Fuel Source Total Retail Seward

Beluga: AIX Energy, LLC (4/2016-3/2024) $0 $0 $0

BRU $0 $0 $0


Furie (5/2017-33/2033) $0 $0 $0

Hilcorp Alaska, LLC (1/2015-3/2028) $0 $0 $0

IGT: AIX Energy, LLC (4/2016-3/2024) $0 $0 $0

BRU $0 $0 $0


Furie (5/2017-33/2033) $0 $0 $0


SPP: AIX Energy, LLC (4/2016-3/2024) $0 $0 $0

BRU $446,456 $434,338 $12,118


Furie (5/2017-33/2033) $0 $0 $0


Plant 1: AIX Energy, LLC (4/2016-3/2024) $0 $0 $0

BRU $0 $0 $0


Furie (5/2017-33/2033) $0 $0 $0



BRU $0 $0 $0


Furie (5/2017-33/2033) $0 $0 $0


Exhibit 12

Exhibit 12

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Projected Fuel Expense by Power Plant and Source


Plant 2A: AIX Energy, LLC (4/2016-3/2024) $0 $0 $0

BRU $3,040,739 $2,958,207 $82,532


Furie (5/2017-33/2033) $0 $0 $0


EGS (Pool): AIX Energy, LLC (4/2016-3/2024) $0 $0 $0

BRU $0 $0 $0


Furie (5/2017-33/2033) $0 $0 $0


Other Fuel Related Expenses

Emergency Generator and Other Diesel Fuel $0 $0 $0

CINGSA - FSS/ISS Capacity/Withdrawal Fees $1,488,033 $1,447,645 $40,388

CINGSA - Gas Withdrawn $40,590 $39,489 $1,102



Exhibit 12

Exhibit 12

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Actual Fuel Expense by Power Plant and Source


Fuel Balance for Quarter Ending March 31, 2020

Beluga: AIX Energy, LLC (4/2016-3/2024) $0 $0 $0

BRU $21,798 $21,214 $584


Furie (5/2017 - 3/2033) $0 $0 $0

Hilcorp Alaska, LLC (1/2015-3/2028) $527,813 $513,663 $14,150

IGT: AIX Energy, LLC (4/2016-3/2024) $0 $0 $0

BRU $1,702 $1,655 $47


Furie (5/2017 - 3/2033) $0 $0 $0

Hilcorp Alaska, LLC (1/2015-3/2028) $41,168 $40,042 $1,126

SPP: AIX Energy, LLC (4/2016-3/2024) $0 $0 $0

BRU $387,576 $377,147 $10,429


Furie (5/2017 - 3/2033) $0 $0 $0



BRU $0 $0 $0


Furie (5/2017 - 3/2033) $0 $0 $0



BRU $0 $0 $0


Furie (5/2017 - 3/2033) $0 $0 $0


Exhibit 12

Exhibit 12

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Actual Fuel Expense by Power Plant and Source


Plant 2A AIX Energy, LLC (4/2016-3/2024) $0 $0 $0

BRU $1,987,685 $1,934,257 $53,428


Furie (5/2017 - 3/2033) $0 $0 $0


EGS (Pool) AIX Energy, LLC (4/2016-3/2024) $0 $0 $0

BRU $0 $0 $0


Furie (5/2017 - 3/2033) $0 $0 $0



Emergency Generator and Diesel Fuel $23,120 $22,506 $614

CINGSA - FSS/ISS Capacity and Withdrawal Fees $666,434 $648,427 $18,006

CINGSA - Gas Withdrawn $6,103,557 $5,940,133 $163,424


Adjustment $2,175 $2,115 $60


Exhibit 12

Exhibit 12

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Power PlantFuel Source Volume Unit Cost Total Cost Volume Unit Cost Total Cost

Beluga Power Plant

AIX Energy, LLC (4/2016-3/2024) 0 $0.00 $0 0 $0.00 $0

BRU 7,147 $3.05 $21,798 0 $0.00 $0


Furie (5/2017 - 3/2033) 0 $0.00 $0 0 $0.00 $0

Hilcorp Alaska, LLC (1/2015-3/2028) 70,377 $7.50 $527,813 0 $0.00 $0

International Generation

AIX Energy, LLC (4/2016-3/2024) 0 $0.00 $0 0 $0.00 $0

BRU 558 $3.05 $1,702 0 $0.00 $0


Furie (5/2017 - 3/2033) 0 $0.00 $0 0 $0.00 $0

Hilcorp Alaska, LLC (1/2015-3/2028) 5,489 $7.50 $41,168 0 $0.00 $0


AIX Energy, LLC (4/2016-3/2024) 0 $0.00 $0 0 $0.00 $0

BRU 127,074 $3.05 $387,576 169,112 $2.64 $446,456


Furie (5/2017 - 3/2033) 0 $0.00 $0 0 $0.00 $0

Hilcorp Alaska, LLC (1/2015-3/2028) 1,234,513 $7.50 $9,258,846 1,470,172 $7.49 $11,011,588

Plant 1

AIX Energy, LLC (4/2016-3/2024) 0 $0.00 $0 0 $0.00 $0

BRU 0 $0.00 $0 0 $0.00 $0


Furie (5/2017 - 3/2033) 0 $0.00 $0 0 $0.00 $0

Hilcorp Alaska, LLC (1/2015-3/2028) 0 $0.00 $0 0 $0.00 $0

Plant 2

AIX Energy, LLC (4/2016-3/2024) 0 $0.00 $0 0 $0.00 $0

BRU (North and South Districts) 0 $0.00 $0 0 $0.00 $0


Furie (5/2017 - 3/2033) 0 $0.00 $0 0 $0.00 $0


Exhibit 12

Exhibit 12

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Power PlantFuel Source Volume Unit Cost Total Cost Volume Unit Cost Total Cost

Plant 2A

AIX Energy, LLC (4/2016-3/2024) 0 $0.00 $0 0 $0.00 $0

BRU 920,224 $2.16 $1,987,685 1,151,795 $2.64 $3,040,739


Furie (5/2017 - 3/2033) 0 $0.00 $0 0 $0.00 $0

Hilcorp Alaska, LLC (1/2015-3/2028) 244,345 $7.25 $1,771,499 263,534 $7.49 $1,973,870

MEA - EGS

AIX Energy, LLC (4/2016-3/2024) 0 $0.00 $0 0 $0.00 $0

BRU 0 $0.00 $0 0 $0.00 $0


Furie (5/2017 - 3/2033) 0 $0.00 $0 0 $0.00 $0



Emergency Generator Fuel 0 $0.00 $23,120 0 $0.00 $0

CINGSA - FSS, ISS and fees ---- $0.00 $666,434 ---- $0.00 $1,488,033

CINGSA Gas Withdrawn 793,701 $7.69 $6,103,557 5,224 $7.77 $40,590

Gas Transportation and Compression 0 $0.00 $1,551,252 0 $0.00 $1,886,733

Adjustment(s) 0 $0.00 $2,175 0 $0.00 $0

Total Fuel and Transportation Expense 3,403,427 $6.57 $22,344,624 3,059,837 $6.50 $19,888,009

Exhibit 12

Exhibit 12

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