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Pleasedescribetheproposedchangestothemonthly customer charges. 6 A., Overall,theproposedrevenueincreasesforcommercialcustomersareconsistentwith 21 themoderatedrevenuelevelsdeterminedintheadjustedCCOS.Consistentwiththe 22 residentialclass,theportionoftherevenuerequirementnotcollectedviatheproposed 23 JJD-8 customer charge increases is recovered in the proposed distribution delivery and 1 demand charges., The per-kW demand charges will increase as follows: 2 $11.05to$14.13forRate33andthefirst100kWofRate34. 3 $9.79to$12.52forthenext400kWofRate34. 4 $8.53to$10.91foranymonthlykWover500ofRate34. 5 6 Customerimpactsvarygreatlyduetothewiderangeofusageinthecommercialclass. 7 ARate21customerusing1,000kWhwillseeamonthlyincreaseof$25.80.ARate 8 34customerwithapeakdemandof3,000kWandusing1,080,000kWhwillseea 9 monthlyincreaseof$18,438. 10 11 Q., Whatisthebasisofcostsforthestandby charge?, Ifthatprovisionisremoved,how will service charges be applied?

This increase was primarily due to higher Montana transmission loads and rates, favorable weather compared to prior period, higher commercial demand as compared to the prior period due to the COVID-19 pandemic related shutdowns, the prior period disallowance of supply costs, and a favorable electric qualifying facilities (QF) liability adjustment as compared with the prior period., As a result of the project discontinuance, we recorded a $1.6 million pre-tax charge for the write-off of preliminary construction costs., This increase was primarily due to higher Montana transmission loads and rates, favorable weather, higher commercial demand as compared to the prior NorthWestern Reports 2021 Financial Results February 10, 2022 Page 6 period due to the COVID-19 pandemic related shutdowns, the prior period disallowance of supply costs, a favorable electric QF liability adjustment as compared with the prior period, and lower property and other taxes, partly offset by higher operating and maintenance expense, depreciation and depletion, and Montana electric supply costs., Consolidated utility margin for items impacting net income increased $55.9 million, including: • $25.1 million increase due to higher transmission rates and demand due to market conditions and pricing and the recognition of approximately $4.7 million of deferred interim revenues; • $17.1 million increase due to higher electric retail volumes driven by warmer summer weather in both Montana and South Dakota, customer growth, and increased commercial volume as compared to the prior year due to the COVID-19 pandemic related shutdowns, partly offset by warmer overall winter weather in Montana and South Dakota; • $9.4 million increase due to prior period MSPC disallowance of electric supply costs; • $4.4 million increase due to a more favorable electric QF liability adjustment compared to the prior period., This increase was primarily driven by higher Montana transmission loads and rates, favorable weather, higher commercial demand as compared to the prior period due to the COVID-19 pandemic related shutdowns, the prior period disallowance of supply costs, a favorable electric QF liability adjustment as compared with the prior period, and lower property and other taxes, partly offset by higher operation and maintenance expense, higher depreciation expense, and higher administrative and general expense.

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.

Insurance charges include both physical property and liability coverage., Due to the deficiency of supply, NorthWestern relies frequently on imported energy purchases to meet demand., The current portfolio of online resources generate energy more than our load in many hours. 2.3.2.3 Load Management Measures Effects on Projected Capacity and Energy Requirements NorthWestern’s forecast for retail customer load and peak demand including transmission line losses is shown in Table 2-5., NEM and DSM load reductions are shown separately but are also included in load and peak demand forecasts., Annual Charges for U.S.

Very cold winters increase demand for natural gas and to a lesser extent, electricity, while warmer than normal summers increase demand for electricity, especially among our residential and commercial customers., Thus, the rates we are allowed to charge may or may not match our costs at any given time., Demand for electricity and natural gas is often greater in the summer and winter months associated with cooling and heating., Such technologies could also result in further declines in commodity prices or demand for delivered energy., Demand for our Montana transmission capacity fluctuates with regional demand, fuel prices and weather related conditions.

These decreases were partly offset by higher demand to transmit energy across our transmission lines due to market conditions and pricing., Thus, the rates we are allowed to charge may or may not match our costs at any given time., Demand for electricity and natural gas is often greater in the summer and winter months associated with cooling and heating., Such technologies could also result in further declines in commodity prices or demand for delivered energy., Demand for our Montana transmission capacity fluctuates with regional demand, fuel prices and weather related conditions.

Our electric supply from owned and long-term contracted resources is not adequate to meet our peak- demand needs., Because of this, the volatility of market prices for energy on peak-demand days, even if only for a few days in duration, exposes us to potentially significant market purchases that could negatively impact our results of operations and cash flows., Our owned and long-term contracted resources are inadequate to supply the necessary capacity we require to meet our peak-demand loads, which exposes us to large quantities of market purchases at typically high and volatile energy prices., We remain concerned regarding an overall lack of capacity in the West and our owned and long-term contracted capacity deficit to meet peak-demand loads., Income tax expense for the three months ended March 31, 2023 includes a one- time $3.2 million charge for the reduction of previously claimed alternative minimum tax credits.

Market purchases and sales fill the gap between resources and customer demand., 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.

Montana Taxes Other Than Income 11 Payments for Services 12 Political Action Committees/Political Contributions not applicable 13 Pension Costs not applicable 14 Other Post Employment Benefits not applicable 15 Top Ten Montana Compensated Employees not applicable 16 Top Five Corporate Compensated Employees not applicable 17 Balance Sheet 18 Havre Pipeline Company, LLC Annual Report Table of Contents Description continued on next page Schedule Montana Plant in Service 19 Montana Depreciation Summary 20 Montana Materials and Supplies 21 Montana Regulatory Capital Structure 22 Statement of Cash Flows 23 Long Term Debt not applicable 24 Preferred Stock not applicable 25 Common Stock not applicable 26 Montana Earned Rate of Return 27 Montana Composite Statistics 28 Montana Customer Information 29 Montana Employee Counts not applicable 30 Montana Construction Budget 31 Transmission, Distribution and Storage Systems 32 Sources of Gas Supply 33 MT Conservation and Demand, Programs not applicable 34 Montana Consumption and Revenues 35 Natural Gas Universal System Benefits Programs not applicable 36a Montana Conservation and Demand Side Mgmt., Schedule 3 Sch. 6 AFFILIATE TRANSACTIONS - PRODUCTS & SERVICES PROVIDED TO UTILITY Charges % of Total Charges Affiliate Name Products & Services Method to Determine Price to Utility Affil., Provision for Uncollectible Accounts - - - 3 2 1 4 5 N o tes Receivable-Associated Companies - - - 3 3 1 4 6 A ccounts Receivable-Associated Companies 206,785 90,926 127.42% 34 151 Fuel Stock - - - 3 5 1 5 4 P lant Materials and Operating Supplies 716,916 733,799 -2.30% 36 164 Gas Stored - Current - - - 3 7 1 6 5 P repayments - - - 3 8 1 7 1 I n terest and Dividends Receivable - - - 4 0 1 7 2 R e n ts Receivable - - - 4 1 1 7 3 A ccrued Utility Revenues - - - 4 2 1 7 4 M iscellaneous Current & Accrued Assets - - - 4 3 1 7 5 D e rivative Instrument Assets (175) - - - 4 4 ( L e ss) Long-Term Portion of Derivative Instrument Assets - - - 4 5 1 7 6 L T Portion of Derivative Assets - Hedges - - - 4 6 ( less) LT Portion of Derivative Assets - Hedges - - - 4 7 T otal Current & Accrued Assets 1,397,424 1,524,079 -8.31% 48 Deferred Debits 49 181 Unamortized Debt Expense - - - 5 0 1 8 2 R e g u latory Assets 369,731 369,731 0.00% 51 183 Preliminary Survey and Investigation Charges

Regulated accounting is appropriate provided that (i) rates are established by or subject to approval by independent, third-party regulators, (ii) rates are designed to recover the specific enterprise's cost of service, and (iii) in view of demand for service, it is reasonable to assume that rates are set at levels that will recover costs and can be charged to and collected from customers., This would result in a charge to earnings and (AOCI), net of applicable income taxes, which could be material., All expenditures for maintenance and repairs of utility plant are charged to the appropriate maintenance expense accounts., If our credit rating were to fall below investment grade, the counterparties could require immediate payment or demand immediate and ongoing full overnight collateralization on contracts in net liability positions., This charge is recorded within operating expense, net on the Statements of Income.

$30.00 / door N/A $ HVAC Demand Control Ventilation Must have space cooling with VFD on supply and return/relief fans, $50.00 / HP supply fan $ Cooking Hood Demand Control System Automated fan speed control. $0.75 / CFM of make-up air $ Faucet Aerator - Kitchen Must have electric water heating and be ≤ 1.5 GPM aerator., This proof of purchase must show: (1) the date of purchase and itemized price paid, (2) the size, type, make, model or part number for the products, and (3) a description of any installation or other labor charges.

Funding for irrigation projects is provided through NorthWestern’s Universal System Benefits Charge (USBC)., Estimate electric energy and demand savings and/or natural gas savings for each measure., Electric demand reduction will be detailed by month as well. 8., NorthWestern is not responsible for project design, operation, or performance; however, NorthWestern will review the project design to verify estimates of costs, energy savings, and demand savings., The study proposal will include preliminary estimates of annual energy and electric demand savings and/or natural gas savings potential associated with the defined scope of work. 5.

Funding for irrigation projects is provided through NorthWestern’s Universal System Benefits Charge (USBC)., Estimate electric energy and demand savings and/or natural gas savings for each measure., Electric demand reduction will be detailed by month as well. 8., NorthWestern is not responsible for project design, operation, or performance; however, NorthWestern will review the project design to verify estimates of costs, energy savings, and demand savings., The study proposal will include preliminary estimates of annual energy and electric demand savings and/or natural gas savings potential associated with the defined scope of work. 5.

Demand reported in column (h) must be in megawatts., In column (k), provide revenues from demand charges related to the billing demand reported in column (h)., In column (e) report the demand charges and in column (f) energy charges related to the amount of energy transferred., Report in column (h) the total charge shown on bills rendered to the respondent., NameOfCompanyOrPublicAuthorityTransmissionOfElectricityByOthers Name of Company or Public Authority (Footnote Affiliations) (a) StatisticalClassificationCode Statistical Classification (b) TransmissionOfElectricityByOthersEnergyReceived MegaWatt Hours Received (c) TransmissionOfElectricityByOthersEnergyDelivered MegaWatt Hours Delivered (d) DemandChargesTransmissionOfElectricityByOthers Demand Charges ($) (e) EnergyChargesTransmissionOfElectricityByOthers Energy Charges ($) (f) OtherChargesTransmissionOfElectricityByOthers Other Charges ($) (g) ChargesForTransmissionOfElectricityByOthers Total Cost of Transmission ($) (h) 1 MONTANA 2 Vigilante Elec.

All transmission costs are classified as demand-related costs., NorthWestern’s firm power supply contracts have demand charges that are not recoverable 15 in its Fuel Clause., Note that the system peak demand occurred in 10 the month of July., Generation costs and non-recoverable purchased power demand charges are functionalized 4 as production-related and allocated on the basis of the 12CP demand allocation factor., Lines 22 – 35 show the unit $/kW 10 charges that would result by using different units of customer demand (12 CP, NCP, billing 11 demand).

NorthWestern Energy is upgrading its technology with new electric meters and gas modules in Montana, enabling two-way communication between the company and its advanced meters on customers' homes and businesses. But what if I don’t want an upgraded meter?

Emphasize energy efficiency measures to reduce energy demand., The final plan should model an adoption rate for net metered systems that takes into account the modified rate structure and demand charges that are proposed by NorthWestern in the rate case., Does Basin Creek ever contribute toward peak hour demand?, Demand response has once again been ignored., The Demand Response report in the 2015 Plan identified 35 MW of nominated demand response capacity by commercial customers.

Thus, the rates we are allowed to charge may or may not match our costs at any given time., Demand for electricity and natural gas is often greater in the summer and winter months associated with cooling and heating., We are also impacted by market conditions outside of our service territories related to demand for transmission capacity and wholesale electric pricing., Such technologies could also result in further declines in commodity prices or demand for delivered energy., Demand for our Montana transmission capacity fluctuates with regional demand, fuel prices and weather related conditions.

NorthWestern Energy 2022 fourth quarter FERC form

Company reports GAAP diluted earnings per share of $0.68 for the quarter, affirms 2021 earnings guidance range, and announces a $0.62 per share quarterly dividend payable December 31, 2021.