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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.

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).

NorthWestern Energy 2021 fourth quarter FERC form

SOUTH DAKOTA ELECTRIC RATE SCHEDULE | NORTHWESTERN ENERGY PUBLIC SERVICE CORPORATION d/b/a NORTHWESTERN ENERGY | 326th Revised Sheet No. 33a | ADJUSTMENT CLAUSE RATES Per KWH

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).

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.

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.

I became the Vice President in charge of Customer 11 Care in 2002 and assumed responsibility for Corporate Communications and 12 Human Resources in 2005 and 2009, respectively., While we did not want to be an early adopter of AMI, 20 we believed an AMI deployment was a matter of when, not if, given the 21 advancements in renewable energy, energy efficiency, distributed generation, 22 demand side management, and a move towards increased electrification in 23 BLS-10 general., NorthWestern when making the 15 decision to implement AMI fall into the following categories: 16 • Increased awareness and control by providing customers with detailed 17 usage data in real or near-real time including proactive billing and usage 18 alerts – which allows customers to better understand and manage their 19 consumption, to make more informed decisions about their energy usage, 20 and to identify ways they may be able to lower their bills; 21 BLS-11 • Proactive outage detection which allows the utility to more quickly 1 respond, improve restoration times, and provide alerts to customers 2 containing information about their outage; 3 • Reduction in the need to estimate meter reads which improves billing 4 accuracy and reduces customer confusion and frustration; 5 • Alternative rate and payment options such as time-of-use rates and pre- 6 pay options to give customers more flexibility in how they are billed and 7 how and when they pay; 8 • Energy conservation and demand, response support which allows 9 customers to use energy more wisely and to participate in demand 10 reduction programs to help offset the need to purchase energy on the 11 market during high demand times; 12 • Remote electric connect and disconnect which allows the utility to turn a 13 customer on or off in a matter of minutes on a 24 by 7 basis; and 14 • Automatic demand reset for commercial meters. 15 16 Additionally, NorthWestern has identified the following customer benefits 17 during implementation of AMI: 18 • Events and alarms to aid in detecting potential issues including on the 19 customer side such as faulty wiring or overloading; 20 • Aid in detecting issues with customer equipment such as pumps and 21 private solar installations that are not working properly or at all; 22 BLS-12 • The ability to send a signal to a meter to ensure power is flowing to the 1 meter, which helps customers determine if the issue is on their side of the 2 meter; and 3 • The ability

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.

It specifies the procedure to be utilized to adjust rates for gas sold under NorthWestern Great Falls Gas, LLC (“GFG”) rate schedules in the state of Montana in order to reflect: A.) changes in the GFG expected cost of gas which is defined to mean (1) the first of the month (FOM) AECO index price for Great Falls volumes plus the estimated cost of procurement, storage and transportation to the city gate in Great Falls or (2) the Rocky Mountains, Northwest FOM price for West Yellowstone liquefied natural gas (LNG) volumes published in the Platts Inside FERC’s Gas Market Report (or equivalent publication recognized in the industry as a market clearing price) plus the liquefaction and transportation cost; and B.) amortization of the unrecovered purchased gas cost account, which is defined to mean the gas costs that have been incurred by GFG but not recovered through charges to GFG’s customers., The cost of gas supply shall include all charges incurred by GFG for gas supply, storage, and transportation services., Any extraordinary costs, such as penalty charges and take-or pay charges, shall be clearly identified as such and separately described., Demand costs shall include all annual gathering and transportation demand charges at current rates 2.), Storage cost shall include all annual storage charges at current rates. 3.)

The net of these two activities is charged (or credited) to NorthWestern., In general, the battery is connected to the VER resource that is used to charge the battery., • Demand response resources under automated control., Demand Side Management – The potential for reduction of consumer demand for energy through various methods such as fnancial incentives and behavioral change., Peak Demand – The highest hourly net energy consumption for load.

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., The change in gross margin for items impacting net income includes the following: • An increase in electric retail volumes and demand driven by warmer weather and customer growth, partly offset by lower industrial demand unrelated to the COVID-19 pandemic., Thus, the rates we are allowed to charge may or may not match our costs at any given time., Such technologies could also result in further declines in commodity prices or demand for delivered energy., Reductions in usage, attributable to various factors could materially affect our results of operations, financial position, and cash flows through, among other things, reduced operating revenues, increased operating and maintenance expenses, and increased capital expenditures, as well as potential asset impairment charges or accelerated depreciation and decommissioning expenses over shortened remaining asset useful lives. 61 Demand for our Montana transmission capacity fluctuates with regional demand, fuel prices and weather related conditions.

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.

NATURAL GAS RATE SCHEDULE | Purchased Gas Cost Adjustment | Section No. 3 | Sheet No. 7.1

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.

Optimized Lab Hood $1,500.00 Fume Hood Install Variable Air Volume (VAV) and Electronically Commutated Motor (ECM) Kitchen Ventilation Controls $1,000.00 Kitchen Hood Install Demand Control Ventilation System., Clothes Dryer $200.00 Unit ENERGY STAR® Rated Parking Garage Ventilation - Demand Controlled $150.00 Per 1,000 Square Feet Install Variable Speed Drive (VFD)., Efficiency Opportunities Date Installed Cost Quantity Manufacturer/Model # Rebate To t a l ( O ffice Use) Commercial Air Curtains Optimized Lab Hood Design Kitchen Ventilation - Advanced Controls Dishwasher Clothes Dryer Ventilation - Parking Garages, Demand Controlled Engine Block Heater Controls Pre-Rinse Spray Valve Refrigeration - High Efficiency Compressor Refrigeration - Defrost Controls Grocery - Display Case - Anti-Sweat Heater Controls Water Cooler Page 3 of 4 FOR OFFICE USE ONLY., 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.

When available, copies of the preliminary prospectus supplement, prospectus supplement and accompanying base prospectus relating to the offering may be obtained free of charge on the Securities and Exchange Commission's website at www.sec.gov (http://www.sec.gov) or from BofA Securities by sending a request to: BofA Securities, NC1-004-03-43; 200 North College Street, 3rd Floor, Charlotte, North Carolina 28255-0001, Attention: Prospectus Department or by email at dg.prospectus_requests@bofa.com or from J.P., Our actual future business and financial NorthWestern Corporation Announces Pricing of Public Offering of Common Stock November 17, 2021 Page 3 performance may differ materially and adversely from those expressed in any forward-looking statements as a result of various factors and uncertainties, including, but not limited to:  adverse determinations by regulators, as well as potential adverse federal, state, or local legislation or regulation, including costs of compliance with existing and future environmental requirements, could have a material effect on our liquidity, results of operations and financial condition;  the impact of extraordinary external events, such as the COVID-19 pandemic, on our liquidity, results of operations and financial condition;  changes in availability of trade credit, creditworthiness of counterparties, usage, commodity prices, fuel supply costs or availability due to higher demand, shortages, weather conditions, transportation problems or

Learn what to expect on your monthly statement with net metering.

 NorthWestern Energy Schedule O‐12 Electric Utility ‐ State of South Dakota Page 1 of 1 Pro Forma Year Ending December 31, 2012 Derivation of Increased Rates and Proof of Revenue Billing Billing Line Description Units Rate Revenue Units Rate Revenue $ % 1 Point to Point Distr Only Service Rate 38 2 Summer Rate 3 Demand Charge 26,657 $3.34 $89,035 26,657 $4.18 $111,427 $22,392 25.15% 4 Sub‐total Summer Rate 5 Booked to Billed Revenue Ratio 6 Booked Base Rate Revenue 7 8 Off‐Peak Rate 9 Demand Charge 41,704 $3.34 $139,290 41,704 $4.18 $174,321 $35,030 25.15% 10 Sub‐total Off‐Peak Rate 11 Booked to Billed Revenue Ratio 12 Booked Base Rate Revenue 13 14 Total Point to Point Distr Only Rate 38 68,361 $228,326 68,361 $285,748 $57,422 25.15% ‐‐‐‐‐‐‐‐‐‐ Present Rates ‐‐‐‐‐‐‐‐‐‐‐ ‐‐‐‐‐‐‐‐‐‐ Proposed Rates ‐‐‐‐‐‐‐‐‐‐ Revenue Change