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Once an energy storage resource is depleted, 11 it is unavailable to discharge to help meet system needs until it is able to 12 re-charge., Thus, the solar PV resource helps to satisfy daytime 16 AO-12 energy demand while the energy storage resource can help to meet 1 evening energy demand., E3 modeled some configurations of hybrid 2 resources that could charge from the grid, enabling the storage to charge 3 sufficiently using grid electricity to provide their full reliability benefit., E3 4 also modeled some configurations of hybrid resources that could only 5 charge from their co-located solar or wind resource, which limits their 6 ability to sufficiently charge the storage during loss-of-load events 7 modeled in RECAP., This is because the 13 storage may not be able to fully charge with only VER energy before a 14 loss-of-load event.

CHARGE SIZE PER THERM CLAUSE RATE Surcharge PGC customer chg 81 $10.00 FIRST 30 $0.39410 0.00580 $0.39990 0.54376 $0.94366 OVER 30 $0.17700 0.00580 $0.18280 0.54376 $0.72656 82 $12.00 FIRST 400 $0.19560 0.00370 $0.19930 0.54376 $0.7431 NEXT 1,600 $0.12390 0.00370 $0.12760 0.54376 $0.6714 OVER 2,000 $0.09780 0.00370 $0.10150 0.54376 $0.6453 84A $120.00 ALL Therms $0.08320 0.00240 $0.08560 0.33132 $0.4169 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 0.33132 $0.3766 84BE8 $320.00 $0.04380 0.00150 $0.04530 0.33132 $0.3766 Supplmnt Gas 2 Tab for rates 84B and 84BE8 - "Daily Demand Rate 1" $1.48000 85A $120.00 ALL Therms $0.08320 0.00240 $0.08560 0.38155 $0.4672 85B $320.00 ALL Therms $0.04380 0.00150 $0.04530 0.38155 $0.4269 85BLG $320.00 ALL Therms $0.04380 0.00150 $0.04530 $0.07226 0.38155 $0.4991 86AI $150.00 ALL Therms $0.08320 0.00240 $0.08560 0.33142 $0.4170 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 $0.543760 PGA02 Purch Gas Commodity SD 82 $0.543760 PGA03 Purch Gas Commodity SD 84 $0.331320 PGA04 Purch Gas Commodity SD 85 $0.381550 PGA05 Purch Gas Commodity SD 87 $0.331320 PGA20 Purch Gas Commodity SD 86 Index $0.331420 PGA21 Purch Gas Commodity SD 86 Offer 1 $0.418600 PGA22 Purch Gas Commodity SD 86 Offer 2 $0.405800 PGA23 Purch Gas Commodity SD 86 Offer 3 $0.378100 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 = $0.84 Contract Demand

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

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

Yes No If Yes, address: City: Legal Description Township: Range: Section: ¼ Section: Subdivision: Block: Lot: Site Information Service Needed: Overhead Electric Underground Electric Gas City Limits Yes No Additional Options: Temporary Electric During Construction (Customer Charge) Load Information Electric: Phase: 1 Phase 3 Phase Panel Size: amps Demand: kW Panel Size: Amps Demand: kW Voltage: 120/240 120/208 277/480 Electrical Contractor Phone Wiring Permit Number Primary Electric Heat: 1 Meter 2 Meter Gas: Load Btu/hr (total input of all appliances) Heating/Plumbing Contractor Phone Delivery Pressure Required: 7”wc 14”wc 2psig 5psig Requested installation Date: (You must contact Nort hWestern Energy for actual installation date.)

It shows that except for the small monthly customer 10 charge, the rest of the monthly bill is assessed through kWh-based energy 11 charges and not peak kW demand charges. 12 Table 1: Current GS-1 Primary Non-Demand Rates GSED-1 Primary Non- Demand Customer Charge $235.30 / month Energy Charge $0.008854/kWh ESS-1 Generation Supply $0.073948/kWh Transmission Energy $0.014943/kWh CTC & USB CTC & USB Energy Charge $0.004319/kWh When a customer installs on-site generation, their bills will be dramatically 13 reduced even if they use the Company’s distribution, transmission, and 14 SWW-7 generation resources during periods when their generator is offline., The Schedule SESS-1 replaces the 15 energy charges in ESS-1 with a demand charge and introduces discounted 16 charges for standby services., The Supplemental Contract Capacity charge, which is applied to the 6 customer’s demand not regularly served by on-site generation, is equivalent 7 to the generation and transmission charges found in ESS-1., The demand 8 charge of $29.41/kW month and the energy charge of $0.018424/kWh in 9 Schedule SESS-1 for a customer with an average load factor of 57.2% is 10 equal to the generation and transmission charges under either of the ESS-1 11 Primary Voltage rate options., The model then charged the energy storage system during the 4 lowest four hour demand period and then discharged during the highest four 5 hour demand period.

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.

They may claim there is a cost for this service and demand payment immediately., We never demand prepaid cards, • Scammers demand a separate payment to replace or install a utility-related device or meter., If there is a charge related to work on equipment, it will typically be included in your monthly bill or paid prior to installation, Any over payments will be applied to your NorthWestern Energy account and used to cover future charges.

Applicability Thisrateisavailableforfirm gas volumes, on a contract basis, to commercial and industrial customers who may also require volumes of interruptible gas in excess of firm demand volumes for which they have contracted. 2., Rates Monthly C h a r g e s : C u s t o m e r C h a r g e per Meter: $ 80.00 D e m a n d C h a r g e – S t a n d a r d S e r v i ce: Per therm daily contract demand (never less than 50 therms) $ 0.21910 DemandCharge–ExtendedService: Per therm daily contract demand 1 st 500 therms/day (never less than 50 therms) $ 0.24590 Over 5 0 0 t h e rms/day $ 0 .00000 Non-Gas Commodity Charge: All u s e , p e r t h e r m $ 0 .05911 City Approved Economic Development Surcharge $ 0 .00254 Minimum Monthly Bill -Amount for therms of demand billed and the customer charge Adjustment C l a u s e s : a ., In addition, the new daily use may then become the daily firm contract demand in place of the previous demand determined by the customer and cannot be reduced by the customer for a period of twelve months. 5.

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).

These costs are stated in terms of 13 customer, energy, and demand charges. 14 15 Q., Regression analyses using various measures of coincident peak demand did not 13 reveal a significant correlation between costs and the demand measures., Page 2 shows the input assumptions used to develop all levelized 3 fixed charge rates., Pleasedescribethesource of the coincident peak demand and non-coincident peak 12 demand data by class that you employed in both electric studies. 13 A., Rate classes whose tariffs include three-part rates are shown 10 with customer, demand, and energy charges expressed as dollars per customer per month, 11 dollars per kWh or dollars per kW of billing demand, respectively.

NORTHWESTERN ENERGY’S SOUTH DAKOTA 2024 INTEGRATED RESOURCE PLAN

The filing will reflect the inclusion in PCCAM Base Costs of those costs that are normally eligible for PCCAM recovery including gas transmission reservation charges included in FERC Account 547 (fuel) that are estimated to be $8.4 million annually., NorthWestern 13 cannot count on continued energy imports to serve our customers reliably 14 during peak demand given the risk of declining capacity generation in the 15 region., Longer 8 duration capacity deficiency periods present higher risk in terms of 9 meeting reliability standards and requirements in the capacity- 10 constrained Pacific Northwest regional market, where NorthWestern 11 purchases significant quantities of market power to meet retail 12 customer demand., For nearly 12 three solid days, NorthWestern had to serve customer demand in excess of 13 the 837 MW identified in the 2020 Supplement., NorthWestern was 15 able to meet customer demand by purchasing energy from other utilities.

The base revenue 13 CSF-8 requirements addressed in this filing reflect the fixed costs of 1 providing utility services to our customers and therefore are not 2 dependent upon a customer’s kWh usage. 3 4  Demand Charges ($/kW): A demand charge is for costs of the 5 energy infrastructure used – distribution, transmission, and 6 capacity-related power generation – to deliver energy service and 7 to meet a customer’s peak energy demand., A cost-based rate design would 17 include the charges described above – energy/volumetric rates, demand 18 charges, and monthly service/customer charges., Any increase to monthly service charges would 1 result in a compensating decrease to energy and demand charges to 2 ensure the rate design remains revenue neutral, that is, the rates 3 developed will continue to recover the same allocated costs of service for 4 the customer class., A rate structure that has a higher monthly service, or 5 fixed, charge can reduce month-to-month bill volatility that may result from 6 changes in usage and/or demand from month to month. 7 Table 5: Current and Cost-Based Monthly Service Charges – Electric Current Cost- Based Change ($) Change (%) RESIDENTIAL $4.20 $9.94 $5.74 136.7% GS‐1: SECONDARY Non‐Demand $6.00 $10.43‐10.51 5 $4.43‐4.51 73.8‐75.1% Demand $8.70 $49.28‐$57.18 6 $40.58‐48.48 466.4‐557.2% GS‐1: PRIMARY Non‐Demand $8.80 $14.57 $5.77 65.6% Demand $27.70 $269.85‐ $508.76 7 $242.15‐ 481.06 874.2‐ 1,736.7% GS‐2 SUBSTATION $225.00 $1,613.74 $1,388.74 617.2% GS‐2 TRANSMISSION $1,380.00 $2,083.87 $703.87 51.0% IRRIGATION Non‐Demand $45.20 $58.72 $13.52 29.9% Demand $106.50 $228.35 $121.85 114.4% 5 This reflects the difference between choice and non-choice customers with $10.43 for GS1 Sec Non Dmd Choice and $10.51 for GS1 Sec Non Dmd Non Choice. 6 This reflects the difference between, It can impact the bills customers will pay 8 due to changes in the manner (i.e., energy charge, demand 9 charge, and/or monthly service fee) by which NorthWestern seeks 10 to recover cost of service from customers. 11 Further details regarding customer bill impacts are discussed by Mr. 12 Durkin. 13 14 Q.

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).

For some customer classes, 1 such as the residential customer class, energy rates are used to 2 recover almost all of the costs to serve residential customers, not just 3 supply costs. 4 5 • Demand Charges ($/kW): A demand charge is for costs of the energy 6 infrastructure used – distribution, transmission, and capacity-related 7 power generation – to deliver energy service and to meet a customer’s 8 peak energy demand., In addition, a fixed 19 charge can play a significant role in supporting cost-based rate design 20 overall by recovering the remainder of the utility’s cost of service that 21 was not assigned to cost-based energy and/or demand charges. 22 23 CSF-15 The same general structure applies to rate design for natural gas with 1 volumetric rates on a $/therm basis and demand charges on a $/Maximum 2 Daily Delivery Quantity (“MDDQ”) basis, that is, fixed charge ($/month), 3 volumetric rate ($/therms), and demand charge ($/MDDQ). 4 5 Q., A cost-based rate design would 15 include the charges described above – energy/volumetric rates, demand 16 charges, and monthly service/customer charges., The majority of our non-residential electric 19 customers are on a rate schedule with a monthly service fee, a monthly 20 demand charge, and a flat energy rate., The design of NorthWestern’s current rates involve 1 limited use of rate design tools – a monthly service charge, monthly demand, 2 and flat energy rates.

Environmental Protection Agency (EPA) - A Federal 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.

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).