Search Results

NorthWestern’s current 3 electric service charges are below cost-based levels. 4 5 Table 1 6 Comparison of Current and Cost-Based Service Charges - Electric Current Rate 07/01/2024 Cost- Based Rate Current / Cost- Based (%) ∆ Current to Cost- Based ($) ∆ Current to Cost- Based (%) Residential (Monthly) Service Charge $4.20 $13.77 30.5% $9.57 227.8% GS-1 Secondary (Monthly) Non-Demand $6.00 $22.11 27.1% $16.11 268.5% Demand $8.70 $32.06 27.1% $23.36 268.5% GS-1 Primary (Monthly) Non-Demand $8.80 $235.29 3.7% $226.49 2573.7% Demand $27.70 $740.62 3.7% $712.92 2573.7% GS-2 Substation (Monthly) Service Charge $286.45 $1,780.28 16.1% $1,493.83 521.5% GS-2 Transmission (Monthly) Service Charge $1,380.00 $1,831.14 75.4% $451.14 32.7% Irrigation (Annual) Non-Demand $45.20 $236.59 19.1% $191.39 423.4% Demand $106.50 $557.45 19.1% $450.95 423.4% 7 NorthWestern’s proposed changes to electric monthly service charges are 8 presented below in Table 2., Please describe NorthWestern’s proposal to increase demand charges 2 for electric service customers. 3 A., Fang, NorthWestern proposes to increase the existing 4 demand charges for non-residential customers to be more cost-based. 5 6 Currently, NorthWestern’s electric monthly demand charges are below cost- 7 based levels., Please describe NorthWestern’s proposal to increase monthly demand 3 charges for natural gas service customers. 4 A., NorthWestern proposes to adjust its Natural Gas monthly demand charges to 5 be more cost-based.

CUSTOMER LOAD GROWTH AND DEMAND-SIDE MANAGEMENT _____ a., DEMAND-SIDE MANAGEMENT 43 7., As natural gas demand continues to grow, additional supply and transmission infrastructure will need to be developed to address future increases in demand., NorthWestern’s Energy Supply function is then charged with ensuring it has enough natural gas supply lined up to meet Design Day needs., Storage is filled in the summer during months of low demand.

In column (k), provide revenues from demand charges related to the billing demand reported in column (h)., In column (k), provide revenues from demand charges related to the billing demand reported in column (h)., In column (k), provide revenues from demand charges related to the billing demand reported in column (h)., In column (k), provide revenues from demand charges related to the billing demand reported in column (h)., In column (k), provide revenues from demand charges related to the billing demand reported in column (h).

Max Kilowatts Delivered 04 = Max Kilowatts Delivered The current max demand is displayed in kilowatts., Demand charges are for customers with a demand rate type., This screen is displayed whether they are a demand customer or not.

In column (k), provide revenues from demand charges related to the billing demand reported in column (h)., In column (k), provide revenues from demand charges related to the billing demand reported in column (h)., In column (k), provide revenues from demand charges related to the billing demand reported in column (h)., In column (k), provide revenues from demand charges related to the billing demand reported in column (h)., In column (k), provide revenues from demand charges related to the billing demand reported in column (h).

Our control area average demand for 2024 was approximately 1,372 MWs per hour, with total energy delivered of approximately 11.53 million MWHs, for year ended December 31, 2024., RAT E S N AT U R A L GAS RAT E S Customers are billed for supply, transmission, distribution, storage, Universal Systems Benefits, competitive transmission charges, a distribution charge, and delivery/supply taxes., RAT E S RESIDENTIAL CUSTOMER JANUARY 2025 MONTHLY NATURAL GAS BILL COMPONENTS USING 100 THERMS PER MONTH COMMERCIAL CUSTOMER JANUARY 2025 MONTHLY NATURAL GAS BILL COMPONENTS USING 200 THERMS PER MONTH Supply & Deferred Supply 28% Delivery & Storage Charges 53% Service Charge 15% Taxes 4% Supply & Deferred Supply 28% Delivery & Storage Charges 49% Service Charge 8% Taxes 15% NORTHWESTERN ENERGY’S JANUARY 1, 2025 ELECTRIC COSTS BY SIZE & CUSTOMER TYPE 1 Residential Commercial Industrial GS1 Secondary Non Demand GS1 Secondary Demand GS1 Primary Demand GS2 Substation Demand Monthly kWh 750 1,500 14,000 180,000 650,000 Peak Monthly kW Demand N/A N/A 40 500 1,000 TOTAL ELECTRIC COSTS (supply, distribution, transmission & other charges) Monthly Cost $98.33 $207 $1,623 $17,651 $51,841 Average Cost per kWh for Supply and Delivery $0.1311 $0.1380 $0.1159 $0.0981 $0.0798 NORTHWESTERN SUPPLY R E L ATED COSTS 2 Supply Portion of Monthly Bill $94 $202, ELECTRIC SERVICE CONSTRUCTION CHARGES Upon application for electric service, the Utility shall make an extension of the primary and/or secondary line free of charge to the applicant up to the level of the costs shown below, but no greater than the entire actual cost of such line extension as defined in Montana Public Service Commission Electric Ta r i ff, Rule 6-1., • Demand General Service Commercial and Irrigation Metered Services equal to or greater than 1 MW Allowance; calculated based on a Revenue/Cost Ratio.

In column (k), provide revenues from demand charges related to the billing demand reported in column (h)., In column (k), provide revenues from demand charges related to the billing demand reported in column (h)., In column (k), provide revenues from demand charges related to the billing demand reported in column (h)., In column (k), provide revenues from demand charges related to the billing demand reported in column (h)., In column (k), provide revenues from demand charges related to the billing demand reported in column (h).

SOUTH DAKOTA GAS RATE SCHEDULE | Contract Sales Service | Rate No. 86

 NorthWestern Energy Schedule O‐9 Electric Utility ‐ State of South Dakota Page 1 of 5 Pro Forma Year Ending December 31, 2022 Derivation of Increased Rates and Proof of Revenue Billing Billing Line Description Units Rate Revenue Units Rate Revenue $ % 1 Large Commercial and Industrial Rate 34 2 Summer Rate 3 Demand Charge ‐ First 100 kW 203,100 $11.05 $2,244,259 203,100 $14.13 $2,869,808 $625,549 27.87% 4 Demand Charge ‐ Next 400 kW 198,557 $9.79 1,943,877 198,557 $12.52 2,485,938 542,062 27.89% 5 Demand Charge ‐ Next 500 kW 186,424 $8.53 1,590,199 186,424 $10.91 2,033,888 443,690 27.90% 6 Total Demand Charge 588,082 $5,778,334 588,082 $7,389,634 $1,611,300 27.89% 7 Power Factor Charge Revenue 168,515 215,486 46,971 27.87% 8 MIN34 Revenue 42,971 54,940 11,969 27.85% 9 Energy Charge ‐ First 100 X Demand 58,097,495 $0.04911 2,853,168 58,097,495 $0.06279 3,647,942 794,774 27.86% 10 Energy Charge ‐ Next 300 X Demand 141,880,980 $0.02348 3,331,365 141,880,980 $0.03001 4,257,848, 55,572 12,107 27.86% 10 Energy Charge ‐ Next 300 X Demand 2,653,500 $0.02348 62,304 2,653,500 $0.03001 79,632 17,327 27.81% 11 Energy Charge ‐ Next 100 X Demand 686,700 $0.01595 10,953 686,700 $0.02038 13,995 3,042 27.77% 12 Energy Charge ‐ Remaining kWh 72,500 $0.00841 610 72,500 $0.01075 779 170 27.82% 13 Total Energy Charge 4,297,750 $117,332 4,297,750 $149,978 $32,647 27.82% 14 Sub‐total Summer Rate $201,920 $258,157 $56,237 27.85% 15 Booked to Billed Revenue Ratio 100.181% 100.00% 16 Booked Base Rate Revenue $202,285 $258,157 $55,872 27.62% 17 Off‐Peak Rate 18 Demand Charge ‐ First 100 kW 1,600 $11.05 $17,680 1,600 $14.13 $22,608 $4,928 27.87% 19 Demand Charge ‐ Next 400 kW 5,790 $9.79 56,687 5,790 $12.52 72,494 15,807 27.89% 20 Demand Charge ‐ Next 500 kW 3,526 $8.53 30,076 3,526 $10.91 38,468 8,392 27.90% 21 Total Demand Charge 10,916 $104,443 10,916 $133,570 $29,127 27.89% 22 Power Factor Charge Revenue 223 285 62 28.07% 23 Option L Discount ‐2,780 ‐3,554 ‐774 27.84%, 10 Energy Charge ‐ Next 300 X Demand 8,284,458 $0.02348 194,519 8,284,458 $0.03001 248,617 54,098 27.81% 11 Energy Charge ‐ Next 100 X Demand 1,335,191 $0.01595 21,296 1,335,191 $0.02038 27,211 5,915 27.77% 12 Energy Charge ‐ Remaining kWh 1,026,144 $0.00841 8,630 1,026,144 $0.01075 11,031 2,401 27.82% 13 Total Energy Charge 13,527,522 $365,967 13,527,522 $467,803 $101,836 27.83% 14 Sub‐total Summer Rate $621,770 794,973 173,203 27.86% 15 Booked to Billed Revenue Ratio 100.191% 100.00% 16 Booked Base Rate Revenue $622,957 $794,973 $172,015 27.61% 17 Off‐Peak Rate 18 Demand Charge ‐ First 100 kW 1,900 $11.05 $20,995 1,900 $14.13 $26,847 $5,852 27.87% 19 Demand Charge ‐ Next 400 kW 7,144 $9.79 69,940 7,144 $12.52 89,443 19,503 27.89% 20 Demand Charge ‐ Next 500 kW 51,120 $8.53 436,055 51,120 $10.91 557,721 121,666 27.90% 21 Total Demand Charge 60,164 $526,990 60,164 $674,011 $147,021 27.90% 22 Power Factor Charge Revenue 45,842 58,620 12,778 27.87% 23 Option L Discount $0.00000, 27.86% 10 Energy Charge ‐ Next 300 X Demand 10,656,818 $0.02348 250,222 10,656,818 $0.03001 319,811 69,589 27.81% 11 Energy Charge ‐ Next 100 X Demand 3,262,531 $0.01595 52,037 3,262,531 $0.02038 66,490 14,453 27.77% 12 Energy Charge ‐ Remaining kWh 2,342,660 $0.00841 19,702 2,342,660 $0.01075 25,184 5,482 27.82% 13 Total Energy Charge 19,894,065 $500,331 19,894,065 $639,542 $139,210 27.82% 14 Sub‐total Summer Rate $838,795 1,072,431 233,636 27.85% 15 Booked to Billed Revenue Ratio 100.178% 100.00% 16 Booked Base Rate Revenue $840,292 $1,072,431 $232,139 27.63% 17 Off‐Peak Rate 18 Demand Charge ‐ First 100 kW 2,000 $11.05 $22,100 2,000 $14.13 $28,260 $6,160 27.87% 19 Demand Charge ‐ Next 400 kW 7,191 $9.79 70,402 7,191 $12.52 90,034 19,632 27.89% 20 Demand Charge ‐ Next 500 kW 43,206 $8.53 368,550 43,206 $10.91 471,381 102,831 27.90% 21 Total Demand Charge 52,398 $461,052 52,398 $589,675 $128,623 27.90% 22 Power Factor Charge Revenue 56,262 71,944 15,682 27.87% 23 Option, 8,237 1,792 27.81% 11 Energy Charge ‐ Next 100 X Demand 7,157 $0.01595 114 7,157 $0.02038 146 32 27.77% 12 Energy Charge ‐ Remaining kWh 0 $0.00841 0 0 $0.01075 0 0 0.00% 13 Total Energy Charge 381,755 $11,476 381,755 $14,669 $3,194 27.83% 14 Sub‐total Summer Revenue Before YS Discount 22,286 28,493 6,207 27.85% 15 Booked to Billed Revenue Ratio 100.174% 100.00% 16 Booked Base Rate Revenue $22,324 $28,493 $6,168 27.63% 17 Off‐Peak Rate 18 Demand Charge ‐ First 100 kW 1,600 $11.05 $17,680 1,600 $14.13 $22,608 $4,928 27.87% 19 Demand Charge ‐ Next 400 kW 263 $9.79 2,579 263 $12.52 3,299 719 27.89% 20 Demand Charge ‐ Next 500 kW 0 $8.53 0 0 $10.91 0 0 0.00% 21 Total Demand Charge 1,863 $20,259 1,863 $25,907 $5,647 27.87% 22 Power Factor Charge Revenue 1 1 $0 81.82% 23 YS Discount $0.00000 ‐11,389 0 $0.00000 ‐11,389 24 Energy Charge ‐ First 100 X Demand 186,348 $0.04911 $9,152 186,348 $0.06279 11,701 $2,549 27.86% 25 Energy Charge ‐ Next 300 X Demand 473,474 $0.02348 11,117

SOUTH DAKOTA ELECTRIC RATE SCHEDULE | NORTHWESTERN ENERGY PUBLIC SERVICE CORPORATION d/b/a NORTHWESTERN ENERGY

Monthly Charges: Option A Option B Customer Charge p e r Meter: $ 1 2 0 . 0 0 $ 3 2 0 . 0 0 N o n - G a s C o m m odity Charge, all use, per therm: $0.0832 $0.0438 DemandCharge per therm of daily firm demand as shown on Sheet 9a., Gas Demand Payment Elections A., Seasonally p r ofiled January & February 20% of annual charge per month March & December 15%ofannual charge per month April & November 10%ofannual charge per month May & October 5% of annual charge per month June through September 0%of annual charge per month C., Minimum Monthly Bill: The Customer Charge plus the amount for therms of firm demand (never less than 50 therms)., (Sheet Nos. 12, 12a) 4.Penalty P r ovision If customer fails to comply with Company’s request to curtail or in any way fails to limit the use of gas to the volume of Daily Demand , then all unauthorized gas in excess of Daily Demand so used shall be “Penalty Gas” and be paid by the Customer at a rate which is the greater of $3.00 per therm or the maximum penalty charges permitted to be made by the Company’s upstream service providers for takes of natural gas in excess of authorized limitations, in addition to the regular Commodity Charge for such gas.

SOUTH DAKOTA GAS RATE SCHEDULE | Gas Transportation Tariffs | Rate No. 87

Environmental Protection Agency (EPA) -AFederal agency charged with protecting the environment., The demand for natural gas largely depends upon weather conditions., Thus, the rates we are allowed to charge may or may not match our costs at any given time., Demand for our Montana transmission capacity fluctuates with regional demand, fuel prices and weather related conditions., This charge is recorded within other income, net on the Consolidated Statements of Income.

CHARGE SIZE PER THERM CLAUSE RATE Surcharge PGC customer chg 81 $10.00 FIRST 30 $0.39410 0.00550 $0.39960 0.41025 $0.80985 OVER 30 $0.17700 0.00550 $0.18250 0.41025 $0.59275 82 $12.00 FIRST 400 $0.19560 0.00350 $0.19910 0.41025 $0.6094 NEXT 1,600 $0.12390 0.00350 $0.12740 0.41025 $0.5377 OVER 2,000 $0.09780 0.00350 $0.10130 0.41025 $0.5116 84A $120.00 ALL Therms $0.08320 0.00230 $0.08550 0.26472 $0.3502 Supplmnt Gas 2 Tab for rates 84A and 84ALG - "Daily Demand Rate 1" $1.48000 84B $320.00 ALL Therms $0.04380 0.00150 $0.04530 0.26472 $0.3100 84BE8 $320.00 $0.04380 0.00150 $0.04530 0.26472 $0.3100 Supplmnt Gas 2 Tab for rates 84B and 84BE8 - "Daily Demand Rate 1" $1.48000 85A $120.00 ALL Therms $0.08320 0.00230 $0.08550 0.31495 $0.4005 85B $320.00 ALL Therms $0.04380 0.00150 $0.04530 0.31495 $0.3603 85BLG $320.00 ALL Therms $0.04380 0.00150 $0.04530 $0.07226 0.31495 $0.4325 86AI $150.00 ALL Therms $0.08320 0.00230 $0.08550 0.26532 $0.3508 86A1 $150.00, $0.04380 0.00150 $0.04530 $5,502.00 $0.0453 87BHA $370.00 ALL Therms $0.04380 0.00150 $0.04530 $0.17600 $0.0453 87BNS $370.00 ALL Therms $0.04380 0.00150 $0.04530 $0.13390 $0.0453 87BOR $370.00 ALL Therms $0.04380 0.00150 $0.04530 $0.0453 87BSP $370.00 ALL Therms $0.04380 0.00150 $0.04530 $0.0453 87BVQ $370.00 ALL Therms $0.04380 0.00150 $0.04530 $0.0453 87CHG $370.00 ALL Therms $0.04380 0.00150 $0.04530 $0.0453 87CNL $370.00 ALL Therms $0.04380 0.00150 $0.04530 $0.0453 "Billing Control Files" "Rate Adjustment Type Master" updates PGA01 Purch Gas Commodity SD 81 $0.410250 PGA02 Purch Gas Commodity SD 82 $0.410250 PGA03 Purch Gas Commodity SD 84 $0.264720 PGA04 Purch Gas Commodity SD 85 $0.314950 PGA05 Purch Gas Commodity SD 87 $0.264720 PGA20 Purch Gas Commodity SD 86 Index $0.265320 PGA21 Purch Gas Commodity SD 86 Offer 1 $0.265320 PGA22 Purch Gas Commodity SD 86 Offer 2 $0.265320 PGA23 Purch Gas Commodity SD 86 Offer 3 $0.265320 PGD01 Purchase Gas Demand, SD 84 1.4800000 PGD03 Purchase Gas Demand SD 87BOR 0.6400000 PGD04 Purchase Gas Demand SD 87BVQ 0.7753800 PGD05 Purchase Gas Demand SD 87BSP 0.9034800 PGD06 Purchase Gas Demand SD 87CNL 0.8657200 MGP81 Manufactured Gas Plant Adjustment 0.0000000 MGP82 Manufactured Gas Plant Adjustment 0.0000000 MGP8A Manufactured Gas Plant Adjustment 0.0000000 MGP8B Manufactured Gas Plant Adjustment 0.0000000 Average price of gas per therm based on 150 therms = $0.70 Contract Demand

In column (k), provide revenues from demand charges related to the billing demand reported in column (h)., In column (k), provide revenues from demand charges related to the billing demand reported in column (h)., In column (k), provide revenues from demand charges related to the billing demand reported in column (h)., In column (k), provide revenues from demand charges related to the billing demand reported in column (h)., In column (k), provide revenues from demand charges related to the billing demand reported in column (h).

In column (k), provide revenues from demand charges related to the billing demand reported in column (h)., In column (k), provide revenues from demand charges related to the billing demand reported in column (h)., In column (k), provide revenues from demand charges related to the billing demand reported in column (h)., In column (k), provide revenues from demand charges related to the billing demand reported in column (h)., In column (k), provide revenues from demand charges related to the billing demand reported in column (h).

CLASS OF SERVICE: Commercial and Industrial Rate No. 94 RATE DESIGNATION: Firm Sales NEBRASKA PUBLIC SERVICE COMMISSION NATURAL GAS RATE SCHEDULE for NORTHWESTERN ENERGY PUBLIC SERVICE CORPORATION d/b/a NORTHWESTERN ENERGY

Demand Read and Demand Usage are additional reads and usage included on certain types of meters to measure efciency., Demand represents the highest usage of energy in any 15-minute period during a monthly billing cycle., Demand is measured in kilowatts (kW)., High demand is typically associated with equipment start-up., By spreading equipment start-ups over a more extended period, you may be able to lower demand and reduce your demand charges. 19.

Demand Read and Demand Usage are additional reads and usage included on certain types of meters to measure efciency., Demand is measured in kilowatts (kW)., High demand is typically associated with equipment start- up., By spreading equipment start-ups over a more extended period, you may be able to lower demand and reduce your demand charges. 20., Electric Delivery Total Meter Number: 2000012345 English: 833-970-2262 Spanish: 833-970-2263 4317 22.23 $ Read Dates Meter Readings 1234567-8 Customer Name: DELIVERY SERVICES ELECTRIC DELIVERY JOHN SMITH Account Number: Demand Usage 4.20 $ Delivery Charges 18.03 $ Read Dates Days kWh Meter Readings Demand Read Current Res.

In column (k), provide revenues from demand charges related to the billing demand reported in column (h)., In column (k), provide revenues from demand charges related to the billing demand reported in column (h)., In column (k), provide revenues from demand charges related to the billing demand reported in column (h)., In column (k), provide revenues from demand charges related to the billing demand reported in column (h)., In column (k), provide revenues from demand charges related to the billing demand reported in column (h).