DOCKET NO. D2016.9 - NorthWestern Energy · D2016.9.68 Application for Authority to Change and Establish Natural Gas Delivery Service and Production Rates Revenue Requirement (Phase

BEFORE THE PUBLIC SERVICE COMMISSION OF THE STATE OF MONTANA

DOCKET NO. D2016.9.68

Application for Authority to Change and Establish Natural Gas Delivery Service and Production Rates

Revenue Requirement (Phase One)

Allocated Cost of Service and Rate Design (Phase Two)

STATEMENTS AND WORKPAPERS (PHASE ONE)

VOLUME II

September 30, 2016

NORTHWESTERN CORPORATION

CONSOLIDATED BALANCE SHEETS

(in thousands, except per share amounts)

Year Ended December 31, 2015 2014 ASSETS Current Assets:

Cash and cash equivalents $ 11,980 $ 20,362 Restricted cash 6,634 29,662 Accounts receivable, net 154,410 163,479 Inventories 53,458 55,094 Regulatory assets 51,348 47,374 Deferred income taxes — 20,843 Other 8,830 14,071

Total current assets 286,660 350,885 Property, plant, and equipment, net 4,059,499 3,758,008 Goodwill 357,586 355,128 Regulatory assets 517,223 455,757 Other noncurrent assets 57,672 54,165

Total Assets $ 5,278,640 $ 4,973,943

LIABILITIES AND SHAREHOLDERS' EQUITY Current Liabilities:

Current maturities of capital leases $ 1,837 $ 1,730 Short-term borrowings 229,874 267,840 Accounts payable 74,511 81,961 Accrued expenses 183,988 206,882 Regulatory liabilities 80,990 56,169

Total current liabilities 571,200 614,582 Long-term capital leases 26,325 28,162 Long-term debt 1,782,128 1,662,099 Deferred income taxes 501,532 446,600 Noncurrent regulatory liabilities 378,711 362,228 Other noncurrent liabilities 418,570 382,489

Total Liabilities 3,678,466 3,496,160 Commitments and Contingencies (Note 19) Shareholders' Equity: Common stock, par value $0.01; authorized 200,000,000 shares; issued and outstanding 51,788,961 and 48,172,158, respectively; Preferred stock, par value $0.01; authorized 50,000,000 shares; none issued 518

505

Treasury stock at cost (93,948 ) (92,558 ) Paid-in capital 1,376,291 1,313,844 Retained earnings 325,909 264,758 Accumulated other comprehensive loss (8,596 ) (8,766 )

Total Shareholders' Equity 1,600,174 1,477,783 Total Liabilities and Shareholders' Equity $ 5,278,640 $ 4,973,943

See Notes to Consolidated Financial Statement

Docket No. D2016.9.68 Statement A Page 1 of 1

NORTHWESTERN CORPORATION

CONSOLIDATED STATEMENTS OF INCOME

(in thousands, except per share amounts)

Year Ended December 31, 2015 2014 2013 Revenues

Electric $ 944,428 $ 877,967 $ 865,239 Gas 269,871 326,896 287,605 Other — — 1,675

Total Revenues 1,214,299 1,204,863 1,154,519 Operating Expenses

Cost of sales 372,864 482,591 479,546 Operating, general and administrative 297,475 305,886 285,569 Property and other taxes 133,442 114,592 105,540 Depreciation and depletion 144,702 123,776 112,831

Total Operating Expenses 948,483 1,026,845 983,486 Operating Income 265,816 178,018 171,033 Interest Expense, net (92,153 ) (77,802 ) (70,486 ) Other Income, net 7,583 10,198 7,737

Income Before Income Taxes 181,246 110,414 108,284 Income Tax (Expense) Benefit (30,037 ) 10,272 (14,301 ) Net Income $ 151,209 $ 120,686 $ 93,983

Average Common Shares Outstanding 47,298 40,156 38,145

Basic Earnings per Average Common Share $ 3.20 $ 3.01 $ 2.46 Diluted Earnings per Average Common Share $ 3.17 $ 2.99 $ 2.46

See Notes to Consolidated Financial Statements

Docket No. D2016.9.68 Statement B Page 1 of 1

NORTHWESTERN ENERGY STATEMENT C - UTILITY PLANT ACCOUNTS - INDEX

Page No.

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 - 22 23-26 27-30 31 32 - 35

Description

Test Period Rate Base - Total MT Gas Utility Test Period Rate Base - MT Transmission & Distribution Test Period Rate Base - Battle Creek Test Period Rate Base - Bear Paw Test Period Rate Base - South Bear Paw Test Period Rate Base - CMPL Plant in Service Summary - MT Transmission & Distribution Plant in Service Summary - Battle Creek Plant in Service Summary - Bear Paw Plant in Service Summary - South Bear Paw Plant in Service Summary - CMPL Plant in Service Summary - Total MT Gas Utility Plant in Service Summary - Common Utility Gas in Storage Cost of Refinancing Debt Gas Storage Sales 2000 & 2001 FAS 109 MPSC/MCC Taxes Personal Injury Reserve Customer Advances $38M Rate Base Reduction Trial Balance Reconciliation Plant-in-Service Details by Account Major Additions Plant Policy Statements

•

NORTHWESTERN ENERGY· MONTANA GAS UTILITY RATE BASE· 13 MONTH AVERAGE NORTHWESTERN ENERGY COMf>ANY EXHIBIT NO. COL·1 ?AGE OF

(AJ (BJ (CJ (D) (E) (F) (G) (H) (I) (JJ (K) (L)

ACTUAL TO&S TD&S TEST f>ERIOO 13 MONTH AVERAGE NORMAUZING BATTLE BEAR SOUTH REGULATORY DEFERRED WORKING 12131/15

Lil« DESCRIPJION RATE BASE 12131/15 ADJUSTMENTS CREEK eAW BEAR?AW ~ ?LANT ADJ SUS.TOTAL TAXES OTHER CAPITAL ADJUSTED ......h!!:!§.

1 UTILITY ?LANT JN SERVICE 1 2 c .. 617,024,475 12,395,450 16,080,164 61,756,259 370,973 ·10,245,761 697,381,560 697,381,560 2 3 Common 29 127 408 640212 830524 3169646 ·210536 33577257 33577 257 3 4 TOTAL UTILITY PLANT IN SERVICE 646,151,663 13,035,662 16,910,686 64,945,907 370,973 -10,456,297 730,958,617 730,958,817 4 5 5

' ACCUMULATED DEPRECIATION 6 7 c .. 261,610,409 121,916 3,189,723 4,165,519 7,469,547 267,258 0 277,064,372 277,084,372 7 ' Common 11471 503 252141 327 093 1256 207 13306944 13306944 ' 9 TOTAL ACCUMULATED DEPRECIATION 273,261,912 121,916 3.441,864 4,512,612 8,745,754 267,258 0 290,391,316 290,391,316 9 10 10 11 TOTAL NET PLANT 372,669,970 ·121,916 9,593.799 12.396,077 56,200,153 ~ ·10,456,297 440,567,501 440.567 .501 11 12 12 13 13 14 GAS STORED UNDERGROUND 32.096,313 32,096,313 32,096,313 14 15 COST OF REFINANCING DEBT 4.044,903 4,044.903 4,044,903 15 16 GAS STORAGE SALES 2000 & 2001 ( g.2039) ·10.199.816 ·10, 199,816 ·10.199,616 16 17 REGULATORY ASSET FAS 109 61.269,439 61.269,439 61,269,439 17 18 MPSCJMCC TAXES 130,100 -562 129,516 163,570 293,068 18 18 19 20 20 21 LESS: CUSTOMER CONTRIBUTED CAPITAL 21 22 Accumulated Deferred Income Taxes 22 23 See Page 2 for Details 72,626,130 738,103 -41,916 2,846.250 76,170,567 -1,401,488 0 74,769,081 23 24 Personal Injury & Property Damage 3.065.276 3,065,276 3,065,276 24 25 Customer AdvanC

NORTHWESTERN ENERGY - MONTANA TRANSMISSION & DISTRIBUTION RATE BASE -13 MONTH AVERAGE NORTHWESTERN ENERGY COMPANY EXHIBIT NO. CDL-1 PAGE OF

(A) (B} (C) (D) (I) (J) (K) (L)

ACTUAL TD&S TEST PERIOD 13 MONTH AVERAGE REGULATORY NORMALIZING DEFERRED WORKING 12/31/15

LINE DESCRIPTION RATE BASE 12/31/15 PLANT ADJ SUB-TOTAL ADJUSTMENTS TAXES OTHER CAPITAL ADJUSTED --....!:!!::!§_

1 UTILITY PLANT IN SERVICE 2 Gas 617,024,475 -10,245,761 606,778,714 606,778,714 2 3 Common 29,127,408 -210.536 28,916,872 28,916,872 3 4 TOTAL UTILITY PLANT IN SERVICE 646,151,883 -10,456,297 635,695,586 635,695,586 4 5 5 6 ACCUMULATED DEPRECIATION 6 7 Gas 261,810,409 0 261,810,409 121,916 261,932,325 7 8 Common 11.471,503 11,471,503 11,471,503 8 9 TOTAL ACCUMULATED DEPRECIATION 273,281,912 0 273,281,912 121,916 273,403,828 9 10 10 11 TOTAL NET PLANT 372,869,970 -10,456,297 362,413,674 -121,916 362,291,758 11 12 12 13 13 14 GAS STORED UNDERGROUND 32,096,313 32,096,313 32,096.313 14 15 COST OF REFINANCING DEBT 4,044,903 4,044,903 4,044,903 15 16 GAS STORAGE SALES 2000 & 2001 ( 9-2039) -10,199,816 -10,199,816 -10,199,816 16 17 REGULATORY ASSET FAS 109 61,269,439 61,269,439 61,269,439 17 18 MPSC/MCC TAXES 130,100 130,100 163,570 293,670 18 19 19 20 20 21 LESS: CUSTOMER CONTRIBUTED CAPITAL 21 22 Accumulated Deferred Income Taxes 22 23 See Page 2 for Details 72,628,130 72,628, 130 -1,401,486 0 71,226,644 23 24 Personal Injury & Property Damage 3,065,278 3,065,278 3,065,278 24 25 Customer Advances for Construction 6,813,187 6,813,187 6,813, 187 25 26 TOTAL CUSTOMER CONTRIBUTED CAPITAL 82,506,595 0 82,506,595 0 -1,401,486 0 81, 105, 109 26 27 27 28 PLUS: WORKING CAPITAL 28 29 Gross Cash Requirements -13,582,217 -13,582,217 -2,241,586 -15,823,803 29 30 Materials and Supplies 7,085,112 7,085,112 7,085.112 30 31 TOTAL WORKING CAPITAL -6,497, 105 -6,497,105 -2,241,586 -8,738.691 31 32 32 33 TOTAL GAS UTILITY RATE BASE 371,207,209 -10,456,297 360,750,913 -121,916 1,401,486 163,570 -2,241,586 359,952,466 33

1 Accumulated Deferred Income Taxes 1 2 Regulatory Liability - MPSC Taxes 101,752 101,752 101,752 2 3 Accelerated Depreciation 35,511,306 35,511,306 1,501,507 37,012,813 3 4 Customer Advances for Construction -2,657,343 -2,657,343 -2,657,343 4 5 Net Operating Loss -4,725,381 -4,725,381 -2,902,993 -7,628,374 5 6 Deferred Revenue -5,436,426 -5.436,426 -5,436,426 6 7 Accrued Incentive Compensation -691,258 -691,258 -691,258 7 8 Injuries & Damages -972,246 -972,246 -972,246 8 -ucno 9 Cost of Refinancing Debt -197,470 -197,470 -197,470 9 Q) - 0 10 Property Taxes 5,216 5,216 5,216 10 co ~ 0 11 FAS 106 & FAS 112 Post Retirements Benefits -9,088, 186 -9,088, 186 -9,088,186 11 ([) CD ~

12 Environmental Reserve -491,273 -491,273 -491,273 12 N3 -13 Regulatory Asset FAS 109 61,269,439 61,269,439 61,269,439 13 a 3. s: 14 0 14 VJ ().

15 Total Deferred Income Taxes 72,628,130 0 72,628,130 -1,401,486 0 0 71,226,644 15 01 0 "' 0 ~ CJ)

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NORTHWESTERN ENERGY - BATTLE CREEK RATE BASE -13 MONTH AVERAGE NORTHWESTERN ENERGY COMPANY EXHIBIT NO. CDL-1 PAGE OF

(B) (G) (I) (J) (K) (L)

TEST PERIOD BATTLE REGULATORY NORMALIZING DEFERRED WORKING 12131115

LINE DESCRIPTION CREEK PLANT ADJ ADJUSTMENT TAXES OTHER CAPITAL ADJUSTED ~

1 UTILITY PLANT IN SERVICE 1 2 Gas 12,395,450 12,395,450 2 3 Common 640,212 640,212 3 4 TOTAL UTILITY PLANT IN SERVICE 13,035,662 0 13,035,662 4 5 5 6 ACCUMULATED DEPRECIATION 6 7 Gas 3,250,948 0 -61,225 3,189,723 7 8 Common 252,141 252,141 8 9 TOTAL ACCUMULATED DEPRECIATION 3,503,089 0 -61,225 3,441,864 9 10 10 11 TOTAL NET PLANT 9,532,574 0 61,225 9,593,799 11 12 12 13 13 14 GAS STORED UNDERGROUND 0 14 15 COST OF REFINANCING DEBT 0 15 16 GAS STORAGE SALES 2000 & 2001 ( 9-2039) 0 16 17 REGULATORY ASSET FAS 109 0 17 18 MPSC/MCC TAXES -582 -582 18 19 19 20 20 21 LESS: CUSTOMER CONTRIBUTED CAPITAL 21 22 Accumulated Deferred Income Taxes 22 23 See Page 2 for Details 953,444 -215,341 0 738,103 23 24 Personal Injury & Property Damage 0 24 25 Customer Advances for Construction 0 25 26 TOTAL CUSTOMER CONTRIBUTED CAPITAL 953,444 0 -215,341 0 738,103 26 27 27 28 PLUS: WORKING CAPITAL 28 29 Gross Cash Requirements -241,893 -241,893 29 30 Materials and Supplies 0 30 31 TOTAL WORKING CAPITAL -241,893 -241,893 31 32 32 33 TOTAL GAS UTILITY RATE BASE 8,579,130 0 61,225 215,341 -582 -241,893 8,613,221 33

1 Accumulated Deferred Income Taxes 1 2 Regulatory liability - MPSC Taxes -245 -245 2 3 Accelerated Depreciation 360,878 304,390 665,268 3 4 Customer Advances for Construction -1,733 -1,733 4 5 Net Operating Loss 592,566 -493,404 99,162 5 6 Deferred Revenue -19,345 -19,345 6 7 Accrued Incentive Compensation -1,070 -1,070 7 -u ()) 0

"" - 0 8 Injuries & Damages 1,758 1,758 8 cc~ 0 9 Cost of Refinancing Debt -521 -521 9

CD CD ,.-w 3 m.

10 Property Taxes 0 10 0 CD Z 11 FAS 106 & FAS 112 Post Retirements Benefits -4,742 -4,742 11 -ao 12 Environmental Reserve -430 -430 12 ~oo 13 Regulatory Asset FAS 109 0 13 "' 14 0 14 0 ~ 15 Total Deferred Income Taxes 953,444 0 -215,341 0 0 738,103 15 °' Co

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NORTHWESTERN ENERGY - BEAR PAW RATE BASE -13 MONTH AVERAGE NORTHWESTERN ENERGY COMPANY EXHIBIT NO. CDL-1 PAGE OF

(B) (G) (I) (J) (K) (L)

TEST PERIOD REGULATORY NORMALIZING DEFERRED WORKING 12131/15

LINE DESCRIPTION BEAR PAW PLANT ADJ ADJUSTMENT TAXES OTHER CAPITAL ADJUSTED ~

1 UTILITY PLANT IN SERVICE 1 2 Gas 16,080,164 16,080,164 2 3 Common 830,524 830,524 3 4 TOTAL UTILITY PLANT IN SERVICE 16,910,688 0 16,910,688 4 5 5 6 ACCUMULATED DEPRECIATION 6 7 Gas 4,287,814 0 -102,295 4,185,519 7 8 Common 327,093 327,093 8 9 TOTAL ACCUMULATED DEPRECIATION 4,614,907 0 -102,295 4,512,612 9 10 10 11 TOTAL NET PLANT 12,295,782 0 102,295 12,398,077 11 12 12 13 13 14 GAS STORED UNDERGROUND 0 14 15 COST OF REFINANCING DEBT 0 15 16 GAS STORAGE SALES 2000 & 2001 ( 9-2039) 0 16 17 REGULATORY ASSET FAS 109 0 17 18 MPSC/MCC TAXES 0 18 19 19 20 20 21 LESS: CUSTOMER CONTRIBUTED CAPITAL 21 22 Accumulated Deferred Income Taxes 22 23 See Page 2 for Details 838,957 -880,873 0 -41,916 23 24 Personal Injury & Property Damage 0 24 25 Customer Advances for Construction 0 25 26 TOTAL CUSTOMER CONTRIBUTED CAPITAL 838,957 0 -880,873 0 -41,916 26 27 27 28 PLUS: WORKING CAPITAL 28 29 Gross Cash Requirements -634,495 -634,495 29 30 Materials and Supplies 0 30 31 TOTAL WORKING CAPITAL -634,495 -634,495 31 32 32 33 TOTAL GAS UTILITY RATE BASE 11,456,825 0 102,295 880,873 0 -634,495 11,805,498 33

1 Accumulated Deferred Income Taxes 1 2 Regulatory Liability - MPSC Taxes -379 -379 2 3 Accelerated Depreciation 233,987 420,850 654,837 3 4 Customer Advances for Construction -2,685 -2,685 4 5 Net Operating Loss 604,970 -1,260,927 -655,957 5 6 Deferred Revenue -29,977 -29,977 6 "U CJ) 0 7 Accrued Incentive Compensation -1,658 -1,658 7 "'-o 8 Injuries & Damages 2,724 2,724 8

NORTHWESTERN ENERGY - SOUTH BEAR PAW RATE BASE-13 MONTH AVERAGE NORTHWESTERN ENERGY COMPANY EXHIBIT NO. CDL-1 PAGE OF

(B) (G) (I) (J) (K) (L)

TEST PERIOD SOUTH REGULATORY NORMALIZING DEFERRED WORKING 12/31/15

LINE DESCRIPTION BEAR PAW PLANT ADJ ADJUSTMENT TAXES OTHER CAPITAL ADJUSTED ~

1 UTILITY PLANT IN SERVICE 1 2 G" 61,756,259 61,756,259 2 3 Common 3,189,648 3 189,648 3 4 TOTAL UTILITY PLANT IN SERVICE 64,945,907 0 64,945,907 4 5 5 6 ACCUMULATED DEPRECIATION 6 7 G" 7,498,904 0 -9,357 7,489,547 7 8 Common 1,256,207 1,256,207 8 9 TOTAL ACCUMULATED DEPRECIATION 8,755,111 0 -9,357 8,745,754 9 10 10 11 TOTAL NET PLANT 56,190,796 0 9,357 56,200,153 11 12 12 13 13 14 GAS STORED UNDERGROUND 0 14 15 COST OF REFINANCING DEBT 0 15 16 GAS STORAGE SALES 2000 & 2001 ( 9-2039) 0 16 17 REGULATORY ASSET FAS 109 0 17 18 MPSC/MCC TAXES 0 18 19 19 20 20 21 LESS: CUSTOMER CONTRIBUTED CAPITAL 21 22 Accumulated Deferred Income Taxes 22 23 See Page 2 for Details 2,649,536 196,714 0 2,846,250 23 24 Personal Injury & Property Damage 0 24 25 Customer Advances for Construction 0 25 26 TOTAL CUSTOMER CONTRIBUTED CAPITAL 2,649,536 0 196,714 0 2,846,250 26 27 27 28 PLUS: WORKING CAPITAL 28 29 Gross Cash Requirements -1,717,534 -1,717,534 29 30 Materials and Supplies 0 30 31 TOTAL WORKING CAPITAL -1,717,534 -1,717,534 31 32 32 33 TOTAL GAS UTILITY RATE BASE 53,541,260 0 9,357 -196,714 0 -1,717,534 51,636,370 33

Accumulated Deferred Income Taxes 1 2 Regulatory liability - MPSC Taxes -708 -708 2 3 Accelerated Depreciation 1,365,380 718,216 2,083,596 3 4 Customer Advances for Construction -5,020 -5,020 4 5 Net Operating Loss 1,284,156 -445,235 838,922 5 6 Deferred Revenue -56,041 -56,041 6 7 Accrued Incentive Compensation -3,099 -3,099 7 "O (I) 0 w Wo 8 Injuries & Damages 5,093 5,093 8 (Q - 0 9 Cost of Refinancing Debt -1,510 -1,510 9 Cl) Cl) "" 01 3 !!?. 10 Property Taxes 0 10 Q, ~ z: 11 FAS 106 & FAS 112 Post Retirements Benefits -13,737 -13,737 11 12 Environmental ReseNe -1,246 -1,246 12

w-P "' () 0 13 Regulatory Asset FAS 109 0 13

"' 14 0 14 2 15 Total Deferred Income Taxes 2,649,536 0 196,714 0 0 2,846,250 15 Q)

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NORTHWESTERN ENERGY - CANADIAN MONTANA PIPELINE RATE BASE-13 MONTH AVE NORTHWESTERN ENERGY COMPANY EXHIBIT NO. CDL-1 PAGE OF

(B) (G) (I) (J) (K) (L)

TEST PERIOD REGULATORY NORMALIZING DEFERRED WORKING 12131/15

LINE DESCRIPTION CMPL PLANT ADJ ADJUSTMENT TAXES OTHER CAPITAL ADJUSTED --....!:!!::!§_

1 UTILITY PLANT IN SERVICE 1 2 Gas 370,973 370,973 2 3 Common 0 3 4 TOTAL UTILITY PLANT IN SERVICE 370,973 0 370,973 4 5 5 6 ACCUMULATED DEPRECIATION 6 7 Gas 279,968 0 7,290 287,258 7 8 Common 0 8 9 TOTAL ACCUMULATED DEPRECIATION 279,968 0 7,290 287,258 9 10 10 11 TOTAL NET PLANT 91,005 0 -7,290 83,715 11 12 12 13 13 14 GAS STORED UNDERGROUND 0 14 15 COST OF REFINANCING DEBT 0 15 16 GAS STORAGE SALES 2000 & 2001 ( 9-2039) 0 16 17 REGULATORY ASSET FAS 109 0 17 18 MPSCIMCC TAXES 0 18 19 19 20 20 21 LESS: CUSTOMER CONTRIBUTED CAPITAL 21 22 Accumulated Deferred Income Taxes 22 23 See Page 2 for Details 0 0 0 23 24 Personal Injury & Property Damage 0 24 25 Customer Advances for Construction 0 25 26 TOTAL CUSTOMER CONTRIBUTED CAPITAL 0 0 0 0 0 26 27 27 28 PLUS: WORKING CAPITAL 28 29 Gross Cash Requirements 0 0 29 30 Materials and Supplies 0 30 31 TOTAL WORKING CAPITAL 0 0 31 32 32 33 TOTAL GAS UTILITY RATE BASE 91,005 0 -7,290 0 0 0 83,715 33

1 Accumulated Deferred Income Taxes 2 Regulatory Liability - MPSC Taxes 0 2 3 Accelerated Depreciation 0 3 4 Customer Advances for Construction 0 4 5 Net Operating Loss 0 5 6 Deferred Revenue 0 6 "U (/) 0 7 Accrued Incentive Compensation 0 7 ., - 0 cc~ 0 8 Injuries & Damages 0 8 (1> (1> "' 9 Cost of Refinancing Debt 0 9 (J) 3 ~ 10 Property Taxes 0 10 0 (1> z 11 FAS 106 & FAS 112 Post Retirements Benefits 0 11 -ao "' . 12 Environmental Reserve 0 12 "'"o 13 Regulatory Asset FAS 109 0 13 "' 0 14 0 14 ~ 15 Total Deferred Income Taxes 0 0 0 0 0 0 15 "' !

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NORTHWESTERN ENERGY- MONTANA OPERATIONS MONTANA TRANSMISSION & DISTRIBUTION

PLANT ACCOUNT BALANCES - RECAP

Plant Balance Transfers Functional Classification 12/31/14 Additions R~tirements Net

Intangible Plant 452,489.51 170,840.60 0.00 0.00

Production Plant 1,086, 183.81 20,036.76 0.09 61,172.54

Storage Plant 40,322,332.58 485,221.99 27,022.95 -67,477.62

Transmission Plant 264,007,051.33 9,453,068.25 301,605.92 62,221.27

Distribution Plant 278,536,722.75 16,615,908.29 1,618, 718.44 0.00

General Plant 24,954,079.63 2,650,012.93 559,648.21 -55,916.19

Total Montana Gas Plant 609,358,859.61 29,395,088.82 2,506,995.61 0.00

Claimed Adjustments

0.00

0.00

2,270,924.08

-2,270,924.08

0.00

0.00

0.00

STATEMENTC UTILITY PLANT ACCOUNTS

Plant Balance 12/31/15

623,330.11

1,167,393.02

42,983,978.08

270,949,810.85

293,533,912.60

26,988,528.16

636,246,952.82

2015 13 Month Averaae

0.00

0.00

0.00

0.00

0.00

0.00

617,024,475.40

"U (/) 0 Dl - 0 co~ 0 (I) (I)"'"

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NORTHWESTERN ENERGY- MONTANA OPERATIONS BATTLE CREEK


Plant Balance Transfers Functional Classification 12131114 Additions Retirements Net

Intangible Plant 2,136.00 0.00 0.00

Production Plant 12,358,510.12 39,834.48 0.00 -61, 172.54

Storage Plant 0.00 0.00 0.00

Transmission Plant 0.00 0.00 0.00

Distribution Plant 0.00 0.00 0.00

General Plant 31,714.56 0.00 0.00 61,172.54

Total Montana Gas Plant 12,392,360.68 39,834.48 0.00 0.00

Claimed Adjustments

0.00

0.00

0.00

0.00

0.00

0.00

0.00


Plant Balance 12131115

2,136.00

12,337, 172.06

0.00

0.00

0.00

92,887.10

12,432, 195.16

2015 13 Month Average

12,395,449.92

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NORTHWESTERN ENERGY - MONTANA OPERATIONS BEAR PAW


Plant Balance Transfers Functional Classification 12/31/14 Additions Retirements Net

Intangible Plant 0.00 0.00 0.00 0.00

Production Plant 15,928,505.48 1,628,851.68 0.00 -14,823.00

Storage Plant 0.00 0.00 0.00 0.00

Transmission Plant 0.00 0.00 0.00 0.00

Distribution Plant 0.00 0.00 0.00 0.00

General Plant 30,931.39 0.00 0.00 0.00

Total Montana Gas Piiii11 15,959,436.87 1,628,851.68 0.00 -14,823.00

Claimed Adjustments

0.00

0.00

0.00

0.00

0.00

0.00

0.00



0.00

17,542,534.16

0.00

0.00

0.00

30,931.39

17,573,465.55


16,080, 163.54

-a(/) 0 "'-o (Q ~ 0 "' "' ,,. co 3 !.. 0"' z -a. 0 "' () . "' 0

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NORTHWESTERN ENERGY- MONTANA OPERATIONS SOUTH BEAR PAW



Intangible Plant 111,820.13 0.00 0.00 0.00

Production Plant 60,666,376.59 100,456.88 2,736.00 14,823.00

Storage Plant 0.00 0.00 0.00 0.00

Transmission Plant 0.00 0.00 0.00 0.00


General Plant 909,581.24 20,036.76 0.00 0.00

Total Montana Gas Plant 61,687,777.96 120,493.64 2,736.00 14,823.00

Claimed Adjustments

0.00

0.00

0.00

0.00

0.00

0.00

0.00



111,820.13

60,778,920.47

0.00

0.00

0.00

929,618.00

61,820,358.60


61, 756,259.39

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NORTHWESTERN ENERGY - MONTANA OPERATIONS CANADIAN-MONTANA PIPELINE COMPANY*


Plant Balance Transfers Functional Classification 12131/14 Additions Retirements Net

Intangible Plant 86,595.31 0.00 0.00 0.00

Production Plant 0.00 0.00 0.00 0.00

Storage Plant 0.00 0.00 0.00 0.00

Transmission Plant 207,186.93 0.00 0.00 0.00


General Plant 77,190.77 0.00 0.00 0.00

Total CMPL Plant 370,973.01 0.00 0.00 0.00

Claimed Adjustments

0.00

0.00

0.00

0.00

0.00

0.00

0.00


Plant Balance 12/31115

86,595.31

0.00

0.00

207,186.93

0.00

77,190.77

370,973.01


370,973.01

-acno m -o cc a o

NORTHWESTERN ENERGY - MONTANA OPERATIONS TOTAL NATURAL GAS UTILITY



Intangible Plant 653,040.95 170,840.60 0.00 0.00

Production Plant 90,039,576.00 1,789,179.80 2,736.09 0.00

Storage Plant 40 ,322 ,332 .58 485,221.99 27,022.95 -67,477.62

Transmission Plant 264,214,238.26 9,453,068.25 301,605.92 62,221.27

Distribution Plant 278,536, 722. 75 16,615,908.29 1,618, 718.44 0.00

General Plant 26,003,497.59 2,670,049.69 559,648.21 5,256.35

Total Gas Utility Plant 699, 769,408.13 31,184,268.62 2,509,731.61 0.00 in U.S. Funds*

Claimed Adiustments

0.00

0.00

2,270,924.08

-2,270,924.08

0.00

0.00

0.00



823,881.55

91,826,019.71

42,983,978.08

271,156,997.78

293,533,912.60

28, 119, 155.42

728,443,945.14

2011 13 Month Averaae

707,627,321.26

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NORTHWESTERN ENERGY - MONTANA OPERATIONS COMMON UTILITY


Plant Balance Functional Classification 12/31/14 Additions Retirements

303 Intangible Plant 19,406,082.04 2,270,689.75 2,321,008.11

389 Land & Land Rights 3,037,852.44 114,505.91 0.00

390 Structures & Improve 35,838'160 .43 27,147,197.57 465,592.52

391 Office Equipment 8,528,087.05 2,348, 794.86 1,339,079.10

397 Communication Equip 25,736,427.13 114,220.56 63,379.56

398 Misc. Equipment 1,117,602.75 12,855.39 5,399.50

Total Common Utility 93,664,211.84 32,008,264.04 4,194,458.79

Allocated to: Electric Utility

Natural Gas Utility

Transfers Claimed Net Adjustments

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 0.00



19,355,763.68

3, 152,358.35

62,519,765.48

9,537,802.81

25,787,268.13

1, 125,058.64

121,478,017.09

79,130,780.33

42,347,236.76


96,320,301.00

62,743,044.00

33,577,257.00

-,, (/) 0 " - 0 «:I ao

NORTHWESTERN ENERGY - MONTANA OPERATIONS GAS IN STORAGE - CUSHION GAS

LINE NO.

1 .

2.

3.

4.

5.

6

7

8

9

10

11

12

13

DECEMBER 2014

JANUARY 2015

FEBRUARY 2015

MARCH 2015

APRIL 2015

MAY 2015

JUNE 2015

JULY 2015

AUGUST 2015

SEPTEMBER 2015

OCTOBER 2015

NOVEMBER 2015

DECEMBER 2015

13 MONTH AVERAGE

BALANCE ACCOUNT 161171

32,096,312.91

32,096,312.91

32,096,312.91

32,096,312.91

32,096,312.91

32,096,312.91

32,096,312.91

32,096,312.91

32,096,312.91

32,096,312.91

32,096,312.91

32,096,312.91

32,096,312.91

32,096,312.91

Docket No. D2016.9.68 Statement C Page 14 of 35

NORTHWESTERN ENERGY - MONTANA OPERATIONS - COST OF REFINANCING DEBT

{A) (B)

A/C189.115 4.65% 6.04 % FMB

DECEMBER 2014 1,886,319.09 127,835.49 2 JANUARY 2015 1,868,005.31 121,443.69 3 FEBRUARY 2015 1,849,691.53 115,051.89 4 MARCH 2015 1,831,377. 75 108,660.09 5 APRIL 2015 1,813,063.97 102,268.29 6 MAY 2015 1,794,750.19 95,876.49 7 JUNE 2015 1,776,436.41 0.00 8 JULY 2015 1,758,122.63 9 AUGUST 2015 1,739,808.85 10 SEPTEMBER 2015 1, 721,495.07 11 OCTOBER 2015 1,703,181.29 12 NOVEMBER 2015 1,684,867.51 13 DECEMBER 2015 1,666,553. 73

14 13 MONTH AVERAGE

DECEMBER 2015

15 ALLOCATION - ELECTRIC UTILITY 65.14 % 10,561, 728.96 16 ALLOCATION - NATURAL GAS UTILITY 34.86 o/o 5,652, 162.59

BASED ON YE 2014 COMMON PLANT SPLIT 16,213,891.55

COST OF REFINANCING DEBT ADDED TO RATE BA! SAP A/C 158600 IN DOCKET 93.6.24 ORDER 5709d FOF 76 SAP A/C 182998

(C)

5.01 % MB

4, 732,872.92 4,694, 704.59 4,656,536.26 4,618,367.93 4,580, 199.60 4,542,031.27 4,503,862.94 4,465,694.61 4,427,526.28 4,389,357.95 4,351,189.62 4,313,021.29 4,274,852.96

3.11% 10yr

3, 722, 149.24 3,691,306.49 3,660,463. 7 4 3,629,620.99 3,598, 778.24 3,567,935.49 3,537,092.74

(D) TOTAL COST OF

4.11% 30yr REFINANCING DEBT

6,211,442.96 6, 194,308.09 6, 177, 173.22 6, 160,038.35 6, 142,903.48 6, 125, 768.61 6, 108,633. 7 4

6,747,027.50 6,684, 153.59 6,621,279.68 6,558,405.77 6,495,531.86 6,432,657.95

16,213,891.55 16,109,431.82 16,004,972.09 15,900,512.36 15, 796,052.63 15,691,592.90 15,587,133.17

11,603,280.22

13 MONTH AVG.

7,558,376.74 4,044,903.48

11,603,280.22

1,253,516.74 14,333,616.43 15,587,133.17 "(J) 0 ., - 0 cc !a 0 "' "' ,..

....lo. 3 !a. "'"' z 0 ao ~no "' "' ~

CJ)

(o i:n

"'

1

2

3

4

5

6

7

8

9

10

11

12

13

NORTHWESTERN ENERGY Docket No. 02016.9.68 Statement c

GAS STORAGE SALES - 2000 & 2001 Page 16 of 35

NET BALANCE DEFERRED *1 NET A/C 274423 & 254423 TAXES RATE BASE

DECEMBER 2014 10,410,07 4.22 0.00 10,410,074.22

JANUARY 2015 10,375,031.20 0.00 10,375,031.20

FEBRUARY 2015 10,339,988.18 0.00 10,339,988.18

MARCH 2015 10,304,945.16 0.00 10,304,945.16

APRIL 2015 10,269,902.14 0.00 10,269,902.14

MAY 2015 10,234,859.12 0.00 10,234,859.12

JUNE 2015 10,199,816.10 0.00 10, 199,816.10

JULY 2015 10,164,773.08 0.00 10, 164, 773.08

AUGUST 2015 10, 129, 730.06 0.00 10,129,730.06

SEPTEMBER 2015 10,094,687.04 0.00 10,094,687 .04

OCTOBER 2015 10,059,644.02 0.00 10,059,644.02

NOVEMBER 2015 10,024,601.00 0.00 10,024,601.00

DECEMBER 2015 9,989,557.98 0.00 9,989,557.98

13 MONTH AVERAGE 10, 199,816.10

2000 & 2001 STORAGE GAS SALES ADDED TO RATE BASE AND AMORTIZED OVER A 38 YEAR LIFE PER MPSC DOCKET D2001.1.1 ORDER 5898h FOF 6 FROM SEPTEMBER 2001 THRU AUGUST 2039.

*1 This liability has been recognized by Northwestern Corporation as having tax basis, as such there is no timing difference and therefore no deferred tax.

A/C 274423 & 254423

MONTHLY ACCRUAL $ 35,043.02

ANNUAL ACCRUAL $ 420,516.24

NORTHWESTERN ENERGY - MONTANA OPERATIONS - FAS 109

(B)

FAS 109 MTU GAS

1 DECEMBER 2014 55, 796,669.22 2 JANUARY 2015 56,909,091.06 3 FEBRUARY 2015 57,668,780.02 4 MARCH 2015 58,893,488.52 5 APRIL 2015 59,341,425.24 6 MAY 2015 61,041,146.44 7 JUNE 2015 61,187,197.75 8 JULY 2015 61,762,411.16 9 AUGUST 2015 61,986, 163.20 10 SEPTEMBER 2015 64,460,201.63 11 OCTOBER 2015 64,635,248.90 12 NOVEMBER 2015 65,751,418.59 13 DECEMBER 2015 67,069,471.01

13 MONTH AVERAGE 61,269,439.44

GAS INCLUDES SAP A/C 153991, 153992, 182993 & 182994

INCLUDED IN RATE BASE IN DOCKET 93.6.24 ORDER 5709d FOF 76

Docket No. 02016.9.68 ·Statement C Page 17 0135

1 2 3

4

5

NORTHWESTERN ENERGY - MONTANA OPERATIONS - MPSC & MCC TAXES

TOTAL MT GAS GASTD&S BATTLE CREEK

MPSC TAXES - UNDER COLLECTION 213,076 212,067 1,009 MCC TAXES - UNDER COLLECTION 111,115 112,821 -1,706

TOTAL 324,191 324,888 -697

RATE BASE INCREASE EQUAL TO HALF 162,444 -349

ANNUAL AMORTIZATION OVER 3 YEARS 108,296 -232

Since Docket D2012.9.94, the annual tax rates associated with funding the MPSC & MCC have varied from 2012 thru 2015. The net impact results in an under-collection of MPSC taxes in the amount of$ 213,076 and an under-collection of MCC taxes in the amount of$ 111, 115

NorthWestern is recommending that the net MPSC & MCC Taxes be added to rate base. To equalize the rate impact, rate base should be adjusted by the same amount each year, which is one half of the initial unamortized amount. NorthWestern is requesting rebate/recovery of these costs over a three year amortization period for this transaction.

Note: MPSC Order 7249e, from docket D2012.9.94 approved the net over collection of MPSC/MCC taxes for the period of 2007 thru 2012 over a 3 year period of 2013 - 2016.

-u en o " - 0 cc~ 0 (1) (1) " _.. 3 ~ 00 (1) z oao t:ioo "' "' 0

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NORTHWESTERN ENERGY - MONTANA OPERATIONS - PERSONAL INJURY & PROPERTY DAMAGE RESERVE

AJC 265201 AJC 265202 AJC 265203 AJC 265205 GENERAL LIABILITY AUTO LOSS WORKER'S COMP EMPLOYER & PRAC TOTAL

ENDING BALANCE ENDING BALANCE ENDING BALANCE ENDING BALANCE AJC265200

1 . DECEMBER 2014 3,592,499.52 49,629.70 4,649,088. 71 58,415.10 8,349,633.03

2. JANUARY 2015 3,670,302.36 57,610.70 4,581,225.57 58,415.10 8,367,553.73

3. FEBRUARY 2015 3,900,314.82 62,239.48 4,618,409.36 58,415.10 8,639,378.76

4. MARCH 2015 3,984, 734.02 70,220.48 4,678,029.38 58,415.10 8, 791,398.98

5. APRIL 2015 4,030,310.46 78,201.48 4,675,273.43 58,415.10 8,842,200.47

6 MAY 2015 4, 114,786.92 86,182.48 4,651,871.67 58,415.10 8,911,256.17

7 JUNE 2015 4,205,408.85 94,600.48 4,677,467.94 58,415.10 9,035,892.37

8 JULY 2015 4,322,331.17 97,658.94 4,659,707.76 58,415.10 9,138,112.97

9 AUGUST 2015 4,445,259.58 106,737.94 4,656,730.58 58,415.10 9,267,143.20

10 SEPTEMBER 2015 4,416,806.94 115,998.94 4,673,433.90 58,415.10 9,264,654.88

11 OCTOBER 2015 4,508,283.29 124,577.90 4,678,151.70 58,415.10 9,369,427.99

12 NOVEMBER 2015 4,040,793.39 43, 115.85 4,093,388.14 58,415.10 8,235,712.48

13 DECEMBER 2015 3,912,006.25 47,881.45 4,079,754.49 58,415.10 8,098,057.29

13 MONTH AVERAGE 8,793,109.41 "U (/) 0 "'-o 13MOAVGALLOC co a o CD CD >

1

2

3

4

5

6

7

8

9

10

11

12

13

NORTHWESTERN ENERGY - MONTANA OPERATIONS A/C 220000 CUSTOMER ADVANCES

220100,220130,220150 NATURAL GAS

DECEMBER 2014 6, 189,584.18

JANUARY 2015 6,171,222.18

FEBRUARY 2015 6, 187,280.18

MARCH 2015 5,999,541.53

APRIL 2015 6, 103,304.53

MAY 2015 6,284,591.53

JUNE 2015 6, 701,996.53

JULY 2015 7, 123,915.53

AUGUST 2015 7,541,992.53

SEPTEMBER 2015 7,522, 736.03

OCTOBER 2015 7,684,916.53

NOVEMBER 2015 7, 756,602.53

DECEMBER 2015 7,303,749.73

13 MONTH AVERAGE 6,813, 187.20

Docket No. 02016.9.68 Statement C Page 20 of35

NorthWestern Energy- Docket D2007 .7 .82 Stipulation Agreement - Rate Base Reduction associated with$ 38,800,000 of 2008 & 2009 Plant Expenditures

2 3 4 5 • 7 • 9 10 11 12 13 14 15 16 Annual Year End Year End Year End Year End Year End Year End YaarEnd Year End Year End Year End Year End Year End Year End Year End Year End Year End

VJnta~aYr e~e:endituro 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2008 s 19,400,000 646,020 646,020 646,020 646,020 646,020 646,020 646,020 646,020 646,020 646,020 646,020 646,020 646,020 646,020 646,020 2009 s 19,400,000 0 646,020 646,020 646,020 646,020 646,020 646,020 646,020 646,020 646,020 646,020 646,020 646,020 646,020 646,020 2010

Tota! s 38,600,000 ' s 646,020 s 1,938,060 s 3,230,100 s 4.522.140 s 5,614,160 s 7,106.220 s 8,396,260 s 9,690,300 s 10,982,340 s 12.274,380 s 13,566.420 $ 14,658,460 $16.150.500 s 17,442.540 s 18.734,560

Accumulated D~reciation Reserve Based on NorthWestem'sMontana DeErec!ation Eractice of accruing a full year of deEreclat!on exEense followiQS theyearElaced 'into service. Electric (2/3'1.1) 432.833 1,296,500 2,164,167 3,029,834 3,895,501 4,761,167 5,628,634

Gas (113) 213,167 639,560 1.065,933 1,492,306 1,918,679 2,345,053 2,n1,426

Net Rate Base Eleclrlc 25,996,000 25.563,167 24,697,500 23,831,633 22,966,166 22,100,499 21,234,633 20.369,166

o .. 12,804,000 12,590,813 12,164,440 11,738,067 11,311,694 10,665,321 ~~iQ.iii,,947"~='[9.Q~~i]

To!al Rate Base 38,600,000 38,153.980 36,861,940 35,569,900 34.2n,660 32,985,820 31,693,780 30.401,740

Depreciation Expense based upon a 30 year straight life= 3.33% annual depreciation accrual rate. ~yg~GE~~iQ~f?--;zfil]

Electric portion assigned 2/3's and Natural Gas portion assigned 1/3 per Stipulation

6,492,501 7,358,166 8,223,635 9,089,501 9,955,168

3,197,799 3,624,172 4,050,545 4.476,919 4,903,292

19,503,499 18,637,832 17,772,165 16,906,499 16,040,832

9,606,201 9,179,626 6,753,455 6,327,081 7,900,706

29,109,700 27,817,660 26,525,620 25,233,560 23,941,540

10,620,635

5,329,665

15,175,165

7,474,335

22,649,500

11,686,502 12,552,169

5,756,038 6,162,411

14,309,496 13,443,631

7,047,962 6,621,569

21.357,460 20,065.420

-ucno "' - 0 tl:l !!o co co "" f\l3 ~ ~co z o ::?.o c::; (") 0 °' N

~ Q)

iD

°' ""

17 18 19 20 21 " 23 24 25 Year End Year End Year End Year End Year End Year End Year End Year End Year End

2024 2025 2026 2027 2028 2029 2030 2031 2032

646,020 646.020 646,020 646.020 646,020 646,020 646,020 646,020 646.020

646.020 646,020 646,020 646,020 646,020 646.020 646,020 646.020 646,020

$ 20,026,_620 S 21,316.660 S 22.610,700 S 23,902,740_$ 25.194.780 S 26,486,820 S 27,nS.860 S 29,070,900 S 30,36.f:,940

13.417,835 14,283,502 15,149,169 16,014,836 18,680,503 17,746,169 16,611,636 19,477,503 20,343.170

6,606,765 7,035,158 7,461,531 7,687,904 8,314,277 6,740,651 9,167,024 9,593,397 10,019,770

12,578,165 11,712,496 10,846,631 9,981,164 9,115.497 6,249,831 7,384,164 6,516,497 5,652,830

6,195,215 5,768,842 5,342,469 4,916,096 4,489,723 4,063,349 3,636,976 3,210,603 2,784,230

18,773,360 17,461,340 16,189,300 14,697.260 13,605,220 12,313,160 11,021,140 9,729,100 8.437,060

26 27 28 29 30 31

Year End Year End Year End Year End Year End Year End 2033 2034 2035 2036 2037 2038 646,020 646,020 646,020 646,020 646,020 646,020 646,020 646,020 646,020 646,020 646,020 646,020

$31,654,980 s 32,947,020 s 34,239,06_Q_____!__35,531.100 $ 36,623.140 $38,115,180

21,208,837 22,074,503 22,940,170 23,605,637 24,671,504 25,537,171

10,446,143 10,872,517 11,296,690 11,725,263 12,151,636 12,576,009

4,787,163 3,921.497 3,055,830 2,190,163 1,324.496 458,629

2,357,657 1,931,463 1,505,110 1,076,737 652,364 225,991

7,145,020 5,852,980 4,560,940 3,268,900 1,976,860 664,620

32 33

Year End Year End 2039 2040

19,400 0

646,020 19,400

$_38.780,600 $ 38,600.000

25,963,002 25,996.000

12,797,596 12,804,000

36,600.000

12,998

6.402

19,400 0

Total Exeense 19,400,000 19,400,000

Tota! Depr Reserve

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NORTHWESTERN ENERGY - MONTANA OPERATIONS NATURAL GAS UTILITY

RECONCILIATION OF PLANT BALANCES AT 12/31/14 AND 12/31/15 TO THE MTU TRIAL BALANCE REPORT

MONTANA GAS S14300 ADD ELECTRIC ADD YELLOWSTONE ADD COMMON ADD PROPANE

TOTAL PLANT

TRIAL BALANCE UTILITY PLANT IN SERVICE A/C 161015

Difference

PLANT BALANCE S14300 BGO

TRIAL BALANCE - BGO UTILITY PLANT IN SERVICE A/C 161010

Difference

PLANT BALANCE S14300 CMPL

TRIAL BALANCE - CMPL UTILITY PLANT IN SERVICE A/C 161010

Difference

ACTUAL @ 12/31/14

699,398,435.12 2,555,684,468.94

16,629,416.48 93,664,211 .84

1,519,564.20

3,366,896,096.58

3,366,896,096.58 0.00

0.00

0.00 0.00

370,973.01

371,047.54 -74.53

ACTUAL @ 12/31/15

728,072,972.13 2, 754,359,830.48

18,971,071.06 94,385,956.61

1,519,564.20

3,597,309,394.48

3,597,309,394.48 0.00

27,092,060.48

27,092,060.48 0.00

370,973.01

371,047.54 -74.53


Report output

NorthWestern Energy Butte

Financial statement (USA)

Companv coda MTU Business area ccompBus. Texts F codelarea

MTU 0153316 MTU 0153320 MTU 0153438 MTU 0153981 MTU 0153982 MTU 0153991 MTU 0153992 MTU 0154108 MTU 0155000 mu 0155400 MTU 0156000 MTU 0156015 MTU 0156080 MTU 0156090 MTU 0157320 ,MTU 0157322 MTU 0157323 MTU 0157327 MTU 0157340 MTU 0157342 MTU 0157349 MTU 0157350 MTU 0157351 !MTU 0157352 MTU 0157355 MTU 0157356 MTU 0157359 MTU 0157370 MTU 0157372 MTU 0157373 MTU 0157380 MTU 0157382 MTU 0157500 MTU 0158484 MTU 0158485 MTU 0158486 MTU 0158487 MTU 0158488 MTU 0158489 MTU 0158490 MTU 0158600 MTU 0158701 MTU 0158710 MTU 0158712 MTU 0158713 MTU 0156720 MTU 0150721 MTU 015a722 MTU 015a725 MTU 0150726 MTU 0158727 MTU 0158728 MTU 0159729 MTU 0150730 MTU 0150731 MTU 0158733 MTU 0150740 MTU 0158742 MTU 0150743 MTU 015a744 MTU MTU MTU MTU MTU MTU MTU MTU MTU MTU MTU /ITU MTU MTU MTU MTU MTU MTU

"'"

0159190 0159191 0161015 0161055 0161140 0161145 0161171 0161172 0161173 0161215 0161999 0163500 0165075 0165105 0171015 0171115 0171145 0171150 0171225

Post Retirement - FAS 106 Deferred Cost - Compensated Absences MCC/MPSC Tax Reg Asset - Current FAS109-Non-Plant - Electric FAS109-Non-Plant GU - Electric FAS 109 Non Plant - Gas FAS 109 Non Plant GU - Gas Current-Energy Stored in Out-of-State U Other Current Assets Assets Held for Resale Other Prepayments Prepaid Postage Prepaid Transmission Reservation Prepaid Gas Transmission NG Residential NG Commercial NG Industrial NG Transportation Unbilled-EL-Residential - Dist Unbilled-EL-Sm. Comm/Indust-Dist Unbilled-EL- Lg. Industrial -Dist Unbilled-EL- Lg. Industrial-Trans. Electric Other Transmission Rev. El GS Market Supply GEMS-1 Contract Industrial Energy Imbalance Other Industrial Energy Imbalance CTC QF Credits Unbilled-EL-Residential - Trans Unbilled-EL-Sm. Comm/Indust-Trans Unbilled-EL-Lrg Comm/Indust-Supply Unbilled-EL-Residential - Supply Unbilled-EL-Sm. Comm/Indust-Supply Unamortized Debt Expense Owner's Share 500KV - Puget Owner's Share 500KV - Portland General Owner's Share SOOKV - Avista Owner's Share SOOKV - Pacific Corp. Owner's SOOKV-Talen/PPL SOOKV Operations Account Deposits PPLM share of WET Tax: Unamortized Loss on Reacquired Debt Deferred Gas Tracker-Current Deferred Gas Revenues Unbilled/True Up Propane Tracker - Prior Propane Tracker - Current Electric Sup Def - Prior 'fear Deferred Electric Revenues - Unbilled Electric Sup. Def. - Current Year Unbilled Electric Trackers - Contra Property tax: Tracker Mill creek Tracker - Current Mill creek Tracker - Prior Mill Creek Deferred Elec Rev - Unbilled Spion Kop Tracker - Prior Hydro Tracker - Current Hydro Tracker - Unbilled Hydro Variable Tracker - Current Hydro Variable Tracker - Unbilled Spion Kop Tracker - Current Spion Kop Tracker - Unbilled Fed Dfd Curr Tax Receivable St Dfd Curr Tax Receivable Utility Plant in Service - PP Utility Future Use - PP Electric Plant Acquisition & Adjustment Basin Creek Capital Lease NG in Underground Storage-Cushion Gas NG in Underground Storage - Working Gas Propane in Storage Non-Utility Property - PP Utility Plant - Settlement Offset Goodwill Utility CWIP - PP Utility RWIP - PP Ace Dep-Utility Plant in service - PP Accumulated Amortization - PP Basin Creek Lease Depreciation Ace Amortization of Electric Plant Acq Ace Dep-Non-Utility - PP

Reporting period (01. 2015-12. 2015 J

1, 4013, 774. 00 10, 336, 241. 96

43, 364. oa 969,989.87-630, 323. 33-437, 445. 4 l-284, 262. 85-

2, 254. 45 a25 .00-

0.00 1,300, 645.48

166, 610, 76 3,782,400.00

20,000.0b 9,32a,a62.25 4,610,447.97

86, 590, 15 1, a97' 214. 02 5,76a,3a4.74 5,024,744.04 1,077,867.36 1,659,55a.11

242, 269.12 93,163.67

121,057 .15 60,997.a5-

509, 693.15 1,567,410.46 l,7la,627.43

797,526.62 a, 651,271.96

10,327,133.51 10,303,567.46

141,095.64 5a,549.54 43, 912 .24 29,26a.6s

311,47 149, 231. 00-14, 731. 00

1,253,516.74 1, 106, 741. 75

641,311.92 3,272.48

49,a99.99 2,92a,646.05

10,301,040.00-13,333,520.41 5,400,615.00 4,179,941.00

376,093.20-395,141.36 434,552.23-

7,920,50-13, 548,516. 74 2, 701,806.46

11a,295.77 101,622.19-139, 502. 96-196, 656. 69

43, 419, lOa. 47 a,979,823.27

3597,309,394.4a 3, 783, 001. 29

450,652,a46.95 40,209,537.00 32, 096,312. 91 11,117,421.77

21,0a3.713 297,546.89

9,425.07 163,259, 659. 85 56, 133, 596. 44

9,237,205.67 1384' 095, 74 7. 34-

42, 352, 2a3. 59-19,099,502.00-10,18a,255,42-

19,028.09

[Comparison period {01. 2014-12. 2014)

1,561,000.00 10,004,977.02

171,736.00 1, 015, 69a. 73-

660, 026. 07-452, 6al. 69-294, 163. 77-

81a.3a 19,300.00

30,000,000.00 6,491,a98.86

153, 796.55 3,7a2,400.00

20,000.00 10, 416, 698. 28

5, 101, 004. 81 95, 391. la

1,898,251,47 5,621,395.77 4,926,729.29 1,369,a56.30 1, 609,975.89

232, 945, 90 95,494.55

136,320.70 39,959.82-

531,074.21 l,530,2a4 .43 1,685,271.la

360, 7a9. 74 5, 256, 504. 73 5,094,797.30 9,530,361.40

277,391.35 115,714.45 86,779.50 57,aS0.51 1,441.06

149,231.00-24,244.00

754, 4a6. as 1,976,073.73 3, 722, a24. 73-

28, 453.8a 55, 109 .as

19,263,901.91 9,162,600,00-9,48a,768.16 5,400,615.00 1,920,241.00 1,990,364.22

109, 721. 97 737,141.23-

1, 316. a5-839, 9a6. 04 1s, 739. as

0. 00 0.00 o.oo 0.00

18,741,877.45 3,876,144.69

3366, 896, 096. 5a 3,5sa,413.13

450, 001, 174 .19 40,209,537.00 32, 096, 312. 91 13, 701, 762, 77

39,565.64 297,546.a9

1,316.77 160, 802, 632 .56 110,927,894.aa

6,556,494.42 1316, 995, 791. 92-

33, 833, 193. 59-17,089,022.00-

l,106,a73.18-20,020.31

Page I of I Docket No. 02016.9.68 Statement C Page 24 of35

Time 15:01;56 Date 09/22/2016 RFBILA00/00082342 Paqe

Amounts in USO Absolute

difference 152,226.00-331, 264. 94 12a, 371. 92-

45, 1oa. a6 29, 702. 74 15,236.28

9,900.92

Rol dif 9. 8-3.3

74. 7-4. 5 4. 5 3. 4 3.4

1,436.07 175.5 20,205.00- 104.3-

30,000,000.00- 100.0-5,191,253.Ja- ao.0-

12,014.21 8.3 0.00 0. 00

1,0a7,a36.03- 10.4-490,556.a4- 9.6-

8,801.03- 9.2-1,037.45- 0.1-

l46,9aa,97 2.6 90,014. 75 2.0

291, 9a9. 94- 21. 3-49,582 .22 3.1

9,323.22 4.0 2,330.aa- 2.4-

15,263.55- 11.2-21,038.03- 52.6-21, 381. 06- 4. 0-37, 134 .03 2.4 33,356.25 2.0

42a,736.aa 116.3 3,394,767,23 64.6 4,432,336.21 75.2

853,205.9a 9.0 136,295.71- 49.1-

57,164.91- 49.4-42,867.26- 49.4-2a,sal.a3- 49.4-1,130.39- 78.4-

0. 00 9,513.00- 39.2-

499,029.89 66.1 869,331.98- 44.0-

4,364,136.65 117.2 25,181.40- a8.5-5,a89.86- l0.6-

16,335,255.86- 84.13-1,130,440.00- 12.4-3,844,752.25 40.5

o. 00 2,251,700.00 116.a 2, 366, 457 .42- 118. 9-

205, 419. 39 108.3 302,509,00 41.0

6,611.65- 502.1-12, 70a, 529. 90 1512. 9 2,626,146.61 3467.3

lla,295. 77 101, 622, 19-139, 502. 96-196, 656. 69

24,677,231.02 5,103,67a.58

230,413,297.90 224,5a8.16 571, 672. 76

0.00 0.00

2,5a4,341.00-1a, 401. a6-

o. 00 8,100.30

2,457,027.29 54,794,290.44-2,6a0,711.25

67,099,955.42-8,519,090.00-2,010,4ao.oo-9,001,382.24-

992.22-

131. 7 131. 7

6. 8 6. 3 0.1

10. 9-46. 7-

615. a 1. 5

49. 4-40. 9

5 .1-25.2-11.0-

758. 4-5. 0-

file:///R:/Gtaxall/POOL TAXIREARDON/EXCEL/DURKIN/Misc/MTU%20TB.HTM 9/?.?./?01 h

Report output

Butte General Office Butte


Company code BGO Businass area ...... CComp Bus. Texts Reporting period Fcode area 101. 2015-12. 2015)

BGO 0157500 Unamortized Debt Expense 819,965.38 BGO 0159190 Fed Dfd Curr Tax Receivable 70,606.41 BGO 0159191 St Dfd Curr Tax Receivable 14,602.62 BGO 0161015 Utility Plant in Service - pp 27,092,060.48 BGO 0165075 Utility CWIP - PP 0. 00

comparison period (01. 2014-12. 2014)

726,164.75 0.00 0.00 o. 00

9,224,920.17

Page 1. of I , Docket No. 02016.9.68 Statement C Page 25 of 35

Time 15;04;11 Data 09/22/2016 RFBIIA00/00082342 Page 1

Amounts in USD Absolute Rol

difference dif 93,800.63 12 .9 70,606.41 14,602.62

27,092,060.48 9,224,920.17- 100.0-

file:///R:/Gtaxall/POOL TAX/REARDON/EXCEL/DURKIN/Misc/BG0%20TR.HTM 9/?.?./?016

Report output

Canadian-Montana Pipeline Butte


comany code '"' Business area **** C Comp Bus. Texts Reporting period fcode larea (01. 2015-12. 2015)

'"' 0158990 Other Deferred Debits 12,024.29 '"' 0161010 Utility Plant in Service 371,047.54 '"' 0171010 Ace Dep-Utility Plant in Service 255, 535. 62-"" 0171110 Accumulated Amortization-Utility Only 24, 621. 67-

Comparison period (01. 2014-12. 20H)

11,673.59 371,047.54 255,198.92-

24, 618. 57-

Page I of I

Docket No. 02016.9.68 Statement C Page 26 of 35

Time 15 05:55 Date 09/22/2016 RFBILA00/00082342 Page

Amounts in USO Absolute Rol

difference dif 150.70 1. 3

0.00 336. 70- 0.1-

J. JO-

file:///R:/Gtaxall/POOL TAX/REARDON/EXCEL/DURKIN/Misc/CMP%20TB.HTM 9/22/?_011;

FERC Report - Form 1 - Gas Account Summary by Functional Class-101/106 Only

NorthWestern Energy- Set of books: FERC Basis

Functional Class Beginning FERC Plant Account Balance Additions Retirements

Intangible Plant

302G - Franchises and consents $40,468.97 $0.00 $0.00 303G - Misc intangible plant $525,976.67 $170,840.60 $0.00

Intangible Plant Subtotal: $566,445.64 $170,840.60 $0.00

Nat. Gas Production Plant

325.1 - Producing Lands $1, 104,470.10 $188,215.07 $0.00 325.2 - Producing leaseholds $73,113,897.73 $441,495.14 ($2,520.83) 327 - Field compress station struct $12,325.75 $7,541.91 $0.00 328 - Field meas/reg stat structure $262,707.18 $74,111.17 $0.00 330 - Producing wells, construction $4,579,285.03 $147,375.06 ($107.63) 331 - Producing wells, equipment $4,616,494.86 $98,962.95 ($107.63) 332 - Field lines $2,015,341.47 $675,240.49 $0.00 333 - Field compesser stat equip $1,469,122.27 $65,381.07 $0.00 334 - Field measure/reg stat equip $2, 134,090.32 $80,074.56 $0.00

Nat. Gas Production Plant Subtotal: $89,307,734.71 $1,778,397.42 ($2,736.09)

Nat. Gas Storage

350.1 - Land $4,081,824.74 $32,187.39 ($25,920.26) 350.2- Rights-of-Way $748,917.84 $0.00 $0.00 351 - Structures and improvements $3,155,738.38 $27,501.51 ($100.00) 352-Wells $7,881,277.22 $40,893.71 ($1 ,002.69) 353 - Lines $12,628,890.31 $20,536.88 $0.00 354 - Compressor station equipment $7,479,793.46 $198,269.62 $0.00 355 - Measure/Regulating equip $3,009,909.15 $16,478.13 $0.00 356 - Purification equipment $446,690.66 $121,072.28 $0.00 357 - Other equipment $889,290.82 $28,282.47 $0.00

Nat. Gas Storage Subtotal: $40,322,332.58 $485,221.99 ($27,022.95)

Transmission Gas Plant

365.1 - Land and land rights $740,108.65 $155,889.02 ($372.80) 365.2 - Rights-of-way $7,777,672.28 $318,263.04 $19.05 366 - Structures and improvements $13,179,084.62 $288,838.06 ($32,768.16) 367- Mains $199, 718,766.85 $4,480,771.78 ($171,010.94) 368 - Compressor station equipment $23,821,860.33 $3,045,069.42 ($39,359.64) 369 - Measure/reg station equip $18,603,586.28 $1, 164,236.93 ($58,113.43) 370 - Communication equipment $0.00 $0.00 $0.00

Page 1 of 2 Asset-1000 Note: This reoort is filtered.

Transfers

$0.00 $0.00

$0.00

$0.00 ($228,075.00)

$45,267.00 $182,808.00

$0.00 $0.00 $0.00 $0.00

($61,172.54)

($61, 172.54)

$0.00 $0.00 $0.00 $0.00 $0.00 $0.00

($67,477.62) $0.00 $0.00

($67,477.62)

$0.00 $0.00

$74,225.38 ($661,534.25)

$0.00 $657,216.61

$0.00

Period Beginning: Jan-2015

Period Ending: Dec-2015

Ending Adjustments Balance

$0.00 $40,468.97 $0.00 $696,817.27

$0.00 $737,286.24

$0.00 $1,292,685.17 $0.00 $73,324,797.04 $0.00 $65,134.66 $0.00 $519,626.35 $0.00 $4,726,552.46 $0.00 $4,715,350.18 $0.00 $2,690,581.96 $0.00 $1,534,503.34 $0.00 $2, 152,992.34

$0.00 $91,022,223.50

$0.00 $4,088,091.87 $0.00 $748,917.84 $0.00 $3, 183, 139.89 $0.00 $7,921,168.24 $0.00 $12,649,427.19 $0.00 $7,678,063.08 $0.00 $2,958,909.66 $0.00 $567,762.94 $0.00 $917,573.29

$0.00 $40, 713,054.00

$0.00 $895,624.87 $0.00 $8,095,954.37 $0.00 $13,509,379.90 $0.00 $203,366,993.44 $0.00 $26,827,570.11 $0.00 $20,366,926.39 $0.00 $0.00

09/21/201615:18:05

'1l en o "'-o

FERC Report· Form 1 ·Gas Account Summary by Functional Class· 101/106 Only


Functional Class Beginning FERC Plant Account Balance Additions Retirements

Transmission Gas Plant

371 • Other equipment $165,972.32 $0.00 $0.00

Transmission Gas Plant Subtotal:' $264,007,051.33 $9,453,068.25 ($301,605.92)

Distribution Gas Plant

374 - Land and land rights $1, 108,885.20 $0.00 $0.00 375. Structures and Improvements $90,523.80 $0.00 $0.00 376. Mains $141,8671095.45 $10,917,733.21 ($297,879.17) 378 • Meas. and reg. stat. eq.-Gen $3,484,201.67 $179,968.75 ($3,311.86) 380. Services $68,589,923.49 $3,336,836.36 ($369,436.53) 381 - Meters $63,274,034.09 $2, 166, 101.88 ($948,090.88) 382 - Meter installations $0.00 $0.00 $0.00 385 - Ind. measuring and regulating $95,842.66 $0.00 $0.00 387 - Other equipment $26,216.39 $15,268.09 $0.00

Distribution Gas Plant Subtotal: $2781536,722.75 $16,615,908.29 ($1,618,718.44)

General Plant

388G-Asset Retirement Costs-Distr $0.00 $0.00 $0.00 389G - Land and land rights $101,675.11 $0.00 $0.00

390G - Structures and improvements $2,290,004.42 $178,428.61 $0.00

391G - Office furniture and equip $224,387.04 $12,425.44 ($9,495.08)

392G -Transportation equipment $10,486,810.10 $1,250,232.14 ($68,366.39) 393G ·Stores equipment $28,926.99 $0.00 $0.00 394G - Tools, shop and garage equip $5,594,298.95 $572,181.79 ($175,313.89)

395G - Laboratory equipment $706,457.28 $103,655.01 ($135,826.05)

396G · Power operated equipment $3,449,066.42 $563,909.08 $0.00 397G ·Communication equipment $31666,975.07 $0.00 ($165,335.30) 398G • Miscellaneous equipment $109,546.73 $0.00 ($5,311.50)

General Plant Subtotal: $26,658,148.11 $2,680,832.07 ($559,648.21)

Grand Total: $699,398,435.12 $31, 184,268.62 ($2,509,731.61)

Page 2 of 2 Asset· 1000 Note: This reoort is filtered.

Transfers

($7,686.47)

$62,221.27

$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 $0.00

$61,172.54 $0.00 $0.00 $0.00 $0.00

$5,256.35 $0.00

$66,428.89

$0.00

Period Beginning: Jan-2015

Period Ending: Dec-2015

Adjustments

$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 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00

$0.00

$0.00

Ending Balance

$158,285.85

$273,220, 734.93

$1, 108,885.20 $90,523.80

$152,486,949.49 $3,660,858.56

$71,557,323.32 $64,492,045.09

$0.00 $95,842.66 $41,484.48

$293,533,912.60

$0.00 $101,675.11

$2,468,433.03 $227,317.40

$11, 729,848.39 $28,926.99

$5,991,166.85 $674,286.24

$4,012,975.50 $3,506,896.12

$104,235.23

$28,845,760.86

$728,072,972.13 " en 0

Ol - 0 ca !.. o (I) (I)"'"

l\) 3 m.. CX> (I) z 0 a. 0 c;oo "' "' ~

m (o

09/21/201615:18:05 "' CX>

Functional Class FERC Plant Account

General Plant

389 - Land and land rights 390 - Structures and improvements 391 - Office furniture, equipment

General Plant Subtotal:

Grand Total:

Page 1 of 1 Note: This reoort is filtered.

FERC Report - Form 1 - Common Account Summary by Functional Class-101/106 Only


Beginning Balance Additions Retirements

$0.00 $114,505.91 $0.00 $0.00 $25,313,123.70 $0.00 $0.00 $1 ,664,430.87 $0.00

$0.00 $27,092,060.48 $0.00

$0.00 $27,092,060.48 $0.00

Asset· 1000

Transfers

$0.00 $0.00 $0.00

$0.00

$0.00

Period Beginning: Jan-2015 Period Ending: Dec-2015

Adjustments

$0.00 $0.00 $0.00

$0.00

$0.00

Ending Balance

$114,505.91 $25,313,123.70 $1,664,430.87

$27,092,060.48

$27,092,060.48

"U (/) 0 " - 0 co 2a. ("') "' "' "" N 3 !!t CO

NORTHWESTERN ENERGY- CANADIAN MONTANA PIPELINE CO - 2015 PLANT DATA IN US FUNDS

Plant Balance 2015 2015 12-31-15 Additions Retirements

CARWAY SECTION 17-12-70 2365.2 Rights-of-Way 3,247.76 2367.1 Mains 203,939.17

Total Transmission Plant 207,186.93 0.00 0.00

GENERAL PLANT 2397.1 72,862.17 2397.2 4,328.60 2397.2 - 2001 Aden SCADA 0.00

Total 77,190.77 0.00 0.00

INTANGIBLE 2301 12,873.39 2302 73,700.19 2303 21.73

Total 86,595.31 0.00 0.00

TOTALCMPL 370,973.01 0.00 0.00

2015 Plant Balance Transfers 12-31-15

3,247.76 203,939.17

0.00 207,186.93

72,862.17 4,328.60

0.00 0.00 77,190.77

12,873.39 73,700.19

21.73 0.00 86,595.31

0.00 370,973.01

13 Month Averaoe

207,186.93

77,190.77

86,595.31

370,973.01

"U (/) 0 Dl - 0 cc a o

NORTHWESTERN ENERGY COMPANY - MONTANA GAS UTILITY 2015 PLANT ACTIVITY OVER$ 1,000,000

DESCRIPTION

TRANSMISSION PLANT

1. RATTLE SNAKE LINE - MISSOULA - 8" LINE

2. TOTAL TRANSMISSION

DISTRIBUTION PLANT

3. DISTRIBUTION MAINS - HELENA DIVISION - PLASTIC

4. DISTRIBUTION SERVICES - BUTTE DIVISION - PLASTIC

5. DISTRIBUTION MAINS - KALISPELL DIVISION - PLASTIC

6. DISTRIBUTION METERS - BOZEMAN DIVISION

7. DISTRIBUTION MAINS - BOZEMAN DIVISION - PLASTIC

8. DISTRIBUTION MAINS - BUTTE DIVISION - PLASTIC

9. TOTAL DISTRIBUTION

10. TOTAL GAS

COMMON PLANT

11. BUTTE GENERAL OFFICE BUILDING (GAS ALLOCATION)

10. TOTAL COMMON

OPERATION DATE

VARIOUS MONTHS

VARIOUS MONTHS

VARIOUS MONTHS

VARIOUS MONTHS

VARIOUS MONTHS

VARIOUS MONTHS

VARIOUS MONTHS

DECEMBER 15, 2015

ADDITIONS

2,679,361

2,679,361

1,157,378

1,210,686

1,504, 104

1,713,896

2,584,918

2,622,860

10,793,842

13,473,203

8,127,618

8,127,618 cl122 ~ cc !! (1 ro ro "" w 3 !2. ~ ro z 0 3. 0 ~no "' "' ~

O>

"' "' "' . '

NORTHWESTERN ENERGY- MONTANA GAS UTILITY


The methods and procedures used to capitalize the cost of borrowed and other funds used during

construction in 2011 was in compliance with the methods and procedures recommended by the

applicable regulatory agencies and are stated below.

POLICY

AFUDC was charged to each individual utility project in construction work in progress at an average rate

of 7.5% for 2015.


UOCK!'I No. 02016.9.68 . Statement C Page 33 of35

There is no plant carried on the Company's books as utility plant which is not used and useful.


There were no significant changes in intangible· plant for 2015.




Data reciuired by this section has been previously submitted to the Commission pursuant to these rules

in numerous MPC rate filings. These Methods and Procedures are outlined below:

A. The Continuing Property Records {CPR) are subsidiary or auxiliary to support Plant Account Nos.

G301 through G398, which in turn are summarized in Account No. 161015 - Plant in Service.

B. The CPR records support the ledger accounts by providing necessary details indicating the below listed fundamental data.

1. Name of Item 2. Location of Property

3. Date Acquired

4. Cost of Asset

5. Asset Control Account and Numbers to which Property is changed.

C. Retirements are recorded on an original cost basis and identified by the year that they were

added to plant. The original cost is credited to both the plant account and location at time of

retirement.

NORTHWESTERN ENERGY STATEMENT D- UTILITY ACCUMULATED DEPRECIATION,

DEPLETION AND AMORTIZATION - INDEX

Page No. Description

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19

Test Period Depreciation Reserve - MT Transmission & Distribution Test Period Depreciation Reserve - Battle Creek Test Period Depreciation Reserve - Bear Paw Test Period Depreciation Reserve - South Bear Paw Test Period Depreciation Reserve - CMPL Test Period Depreciation Reserve - Total MT Gas Utility Depreciation Reserve Activity - MT Transmission & Distribution Depreciation Reserve Activity - Battle Creek Depreciation Reserve Activity - Bear Paw Depreciation Reserve Activity - South Bear Paw Depreciation Reserve Activity- CMPL Depreciation Reserve Activity- Total MT Gas Utility Depreciation Reserve Activity - Common Utility Montana Common Utility Montana Gas Utility Depreciation Depreciation Policy Allocation Method Plant Allocation 2015 Montana A&G Allocation Study

Docket No. D2016.9.68 Statement D Page 1 of 19

STATEMENT D, ACCUMULATED DEPRECIATION, DEPLETION AND AMORTIZATION

NORTHWESTERN ENERGY - MONTANA OPERATIONS MONTANA GAS DEPARTMENT - TRANSMISSION, DISTRIBUTION & STORAGE

Depreciation Reserve 13 Month Average

Functional Classification @ 12/31/15

Intangible Plant 133,062.34

Storage Plant 23,271,233.00

Transmission Plant 102, 143, 108.00

Distribution Plant 121,977,930.00

General Plant 14,285,079.20

Total Above 261,810,412.54

Common Allocation 11,471,503.45

Total MT TD&S Gas Depr Reserve 273,281,915.99

Claimed Adjustments:

1. Depreciation Rate Adjustments

2. Total Adjustments

Claimed Adjustments

0.00

-805.00

14,209.00

96,932.00

11,579.50

121,915.50

0.00

121,915.50

121,915.50

121,915.50

Test Period Deoreciation Reserve

133,062.34

23,270,428.00

102, 157,317.00

122,074,862.00

14,296,658.70

261,932,328.04

11,471,503.45

273 ,403 ,831 .49

Docket No. D2016.9.68 Statement D Page 2of19


NORTHWESTERN ENERGY- MONTANA OPERATIONS MONTANA GAS DEPARTMENT- BATTLE CREEK



Production Plant 3,212,868.21

General Plant 38,079.34

Total Above 3,250,947.55

Common Allocation 252, 140.52

Total Battle Creek Gas Depr Reserve 3,503,088.07



2. Depletion Rate Adjustments


Claimed Test Period Adjustments Depreciation Reserve

-61,229.00 3,151,639.21

4.00 38,083.34

-61,225.00 3, 189, 722.55

0.00 252,140.52

-61,225.00 3,441,863.07

61.50

-61,286.50

-61,225.00


NORTHWESTERN ENERGY- MONTANA OPERATIONS MONTANA GAS DEPARTMENT - BEAR PAW



Production Plant 4,280,067.61

General Plant 7,746.28

Total Above 4,287,813.89

Common Allocation 327,092.68

Total Bear Paw Gas Depr Reserve 4,614,906.57






-102,784.00 4, 177,283.61

489.50 8,235.78

-102,294.50 4, 185,519.39

0.00 327,092.68

-102,294.50 4,512,612.07

-214.00

-102,080.50

-102,294.50




NORTHWESTERN ENERGY - MONTANA OPERATIONS MONTANA GAS DEPARTMENT - SOUTH BEAR PAW

Functional Classification

Intangible Plant

Production Plant

General Plant

Total Devon Gas Reserves

Common Allocation

Total Devon Gas Depr Reserve






@ 12/31/15

39,465.66

7,404,307.16

55,131.18

7,498,904.00

1,256,207.35

8,755,111.35


0.00 39,465.66

-9,758.50 7,394,548.66

402.00 55,533.18

-9,356.50 7,489,547.50

0.00 1,256,207.35

-9,356.50 8,745,754.85

604.00

-9,960.50

-9,356.50



NORTHWESTERN ENERGY- MONTANA OPERATIONS CANADIAN MONTANA PIPELINE COMPANY


Intangible Plant

Production Plant

Storage Plant

Transmission Plant

Distribution Plant

General Plant

Total Above

Common Allocation

Total CMP Depr. Reserve in U.S. FUNDS





@ 12/31/15

21,960.23

0.00

0.00

188,795.42

0.00

69,208.71

279,964.36

0.00

279,964.36


0.00 21,960.23

0.00 0.00

0.00 0.00

721.68 189,517.10

0.00 0.00

6,568.33 75,777.04

7,290.00 287,254.36

0.00 0.00

7,290.00 287,254.36

7,290.00

7,290.00



NORTHWESTERN ENERGY - MONTANA OPERATIONS TOTAL NATURAL GAS UTILITY


Intangible Plant

Production Plant

Storage Plant

Transmission Plant

Distribution Plant

General Plant

Total Above

Common Allocation

Total Depr. Reserve






@ 12/31/15

194,488.23

14,897,242.98

23,271,233.00

102,331,903.42

121,977,930.00

14,455,244. 71

277, 128,042.34

13,306,944.00

290,434,986.34


0.00 194,488.23

-173,771.50 14,723,471.48

-805.00 23,270,428.00

14,930.68 102,346,834.10

96,932.00 122,074,862.00

19,043.33 14,474,288.04

-43,670.50 277,084,371.84

0.00 13,306,944.00

-43,670.50 290,391,315.84

129,657.00

-173,327.50

-43,670.50

NORTHWESTERN ENERGY - MONTANA TRANSMISSION, DISTRIBUTION & STORAGE GAS UTILITY 2015 ACCUMULATED DEPRECIATION DATA

Reserve Balance Current Year Adjustment to Current Depr at Other Misc. Highway Transfers E11ooticmal Classmcation 12131114 Accrual Deor for rates Prooosed Rates Credits Credits ___Nfil Retirements

Intangible Plant 99,471.74 82,831.36 0.00 82,831.36 0.00 0.00 0.00 0.00

Production Plant 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Storage Plant 22,959,860. 70 675.778.92 -1,610.00 674,168.92 0.00 0.00 -27,981.24 27,022.95

Transmission Plant 100,013,932.43 4,425,439.68 28.418.00 4.453,857.68 0.00 0.00 26,644.46 301,605.92

Distribution Pl art 119,440,228.70 7,280,622.12 193.864.00 7 .474.486.12 0.00 0.00 0.00 1,618,718.44

General Plant l3 299 556.97 2071 025.15 23 159.00 2 094184.15 0.00 0.00 3 742.42 559 648.21

Total TO&S 255,813,050.54 14,535,697.23 243,831.00 14,779,528.23 0.00 0.00 2.405.64 2,506,995.52

STATEMENTD Working Papers on Recorded Changes to Accumulated Depreciation

Reserve Balance Removals Salvage Other 12131115

0.00 0.00 182,303.10

0.00 0.00 0.00 0.00

18,107.15 2,500.00 0.00 23,563,418.28

91,098.07 35,348.00 -10.44 104,137,068.14

1,368,522.40 1,729.04 0.00 123,929,203.02

853.65 45 345.25 0.00 14 882 326.93

1.478,581.27 84,922.29 -10.44 266,694,319.47


261,932,328.04

~sa~ cc en CD CD ,.-....... 3 !a 0 CD Z -ao ~oo

~ a> (o

°' "'

NORTHWESTERN ENERGY - MONTANA GAS UTILITY - BATILE CREEK 2015 ACCUMULATED DEPRECIATION DATA

Reserve Balance Current Year Adjustment to Current Depr at Other Misc. Highway F1mctjonal Classification 12/31/14 Accrual Depr for rates Prooosed Rates Credits Credits

Production Plant 2,903,462.61 630,562.00 -122,458.00 508,104.00 0.00 0.00

General Plant 7 494.41 3123.00 8.00 3131.00 0.00 0.00

Total Batlle Creek 2,910,957.02 633,685.00 -122,450.00 511,235.00 0.00 0.00


Transfers Reserve Balance - Retirements Removals Salvage Other 12131/15 0.00 0.00 0.00 0.00 0.00 3,411,566.61 0.00 0.00 0.00 0.00 0.00 10625.41

0.00 0.00 0.00 0.00 0.00 3,422,192.02


3,189,722.55

,, en o Ill - 0 cc 2a. 0 "' "' "' CD 3 £a. 0"' z -a. 0 Co

"' °'

NORTHWESTERN ENERGY - MONTANA GAS UTILITY - BEAR PAW 2015 ACCUMULATED DEPRECIATION DATA

Reserve Balance Current Year Adjustment to Current Depr at Other Misc. Highway E11IB:;jiQDal Classification 12131114 Accrual pepr for rates Prooosed Rates Credits Credits

Production Plant 3,540,613.04 1,510,455.00 -205,568.00 1,304,887.00 0.00 0.00

General Plant 5425.08 1 819.00 979.00 2 798.00 0.00 0.00

Total Bear Paw 3,546,038.12 1,512,274.00 -204,589.00 1,307,685.00 0.00 0.00


Transfers Reserve Balance ____Ng! Retirements Removals Salvage Other 12131115

0.00 0.00 0.00 0.00 0.00 4,845,500.04

0.00 0.00 0.00 0.00 0.00 8 223.08

0.00 0.00 0.00 0.00 0.00 4,853,723.12


4,185,519.39

"U (J) 0 Dl - 0 cc~ 0 CD CD >

NORTHWESTERN ENERGY - MONTANA GAS UTILITY - BEAR PAW SOUTH 2015 ACCUMULATED DEPRECIATION DATA

Reserve Balance Current Year Adjustment to Current Depr at Other Misc. Highway fJmctjonal Classification 12131/14 Accrual Dear for rates Prooosed Rates Credits Credits

Intangible Plant 20,458.53 22,364.00 0.00 22,364.00 0.00 0.00

Production Plant 5,209,953.26 4,409,398.36 -19,517.00 4,389,881.36 0.00 0.00

General Plant 29 694.49 24 018.00 804.00 24 822.00 0.00 0.00

Total South Bear Paw 5,260, 106.28 4,455,780.36 -18,713.00 4,437,067.36 0.00 0.00

Transfers ___Nfil Retirements

0.00 0.00

-2,405.64 2,736.09

0.00 0.00

-2,405.64 2,736.09


Reserve Balance Removals Salvage Other 12131/15

0.00 0.00 42,822.53

34.69 6,950.00 0.00 9,601,608.20

Q,QQ 0.00 0.00 54 516.49

34.69 6,950.00 0.00 9,698,947.22

201513 Month Average

7,489,547.50

,, en o "'-o (C !. 0 ct> ct> "" _,,, 3 m. 0 CD z 0 ao - . ~oo CD N

0 ~

"' (o "' co

NORTHWESTERN ENERGY ~ CANADIAN MONTANA PIPELINE 2015 ACCUMULATED DEPRECIATION DATA

Reserve Balance Current Year Adjustment to Current Depr al Other Misc. Highway Ecmctkmal Classification 12/31/14 Accrual Depr for rates Prnoosed Rates Credits Credits

Intangible Plant 21,960.23 0.00 0.00 0.00 0.00 0.00

Production Plant 0.00 0.00 0.00 0.00 0.00 0.00

Storage Plant 0.00 0.00 0.00 0.00 0.00 0.00

Transmission Plant 188,760.09 70.65 1,443.35 1,514.00 0.00 0.00

Distribution Plant 0.00 0.00 0.00 0.00 0.00 0.00

General Plant 69 074.03 269.35 13 136.65 13 406.00 Q,QQ 0.00

Total CMP in U.S. Funds 279,794.35 340.00 14.580.00 14,920.00 0.00 0.00


Transfers Reserve Balance -----1ifil Retirements Removals Salvage Other 12131/15

0.00 0.00 0.00 0.00 21,960.23

0.00 0.00 0.00 0.00 0.00

o.oo 0.00 0.00 0.00 0.00

0.00 0.00 0.00 0.00 190,274.09

0.00 0.00 0.00 0.00 0.00

llQQ 0.00 0.00 0.00 llQQ 82 480.03

0.00 0.00 0.00 0.00 0.00 294,714.35

201513 Month AveraQe

287,254.36

-o en o ., - 0 Ul 2?. 0 (!) (!).,,,.

....... 3 !1 ~(!) z 0 ao ::: 0 0 CD N

0 ~

"' Co "' "'

NORTHWESTERN ENERGY - MONTANA NATURAL GAS UTILITY 2015 ACCUMULATED DEPRECIATION DATA

Reserve Balance Current Year Adjustment to Current Depr at Other Misc. Highway Transfers Functional Classification 12131/14 Accrual Depr for rates Prooosed Rates Credits Credits _____Nfil

Intangible Plant 141,890.50 105, 195.36 0.00 105, 195.36 0.00 0.00 0.00

Production Plant 11,654,028.91 6,550,415.36 -347,543.00 6,202,872.36 0.00 0.00 -2,405.64

Storage Plant 22,959,860. 70 675,778.92 -1,610.00 674,168.92 0.00 0.00 -27,981.24

Transmission Plant 100,202,692.52 4.425,510.33 29,861.35 4,455,371.68 0.00 0.00 26,644.46

Distributbn Plart 119,440,228.70 7,280,622.12 193,864.00 7,474,486.12 0.00 0.00 0.00

General Plant 13411244.98 2100 254.50 38 086.65 2 138 341.15 0.00 0.00 3 742.42

Total MT Gas Utility 267,809,946.31 21,137,776.59 -87,341.00 21,050.435.59 0.00 0.00 0.00


Reserve Balance Retirements Removals Salvage Other 12131/15

0.00 0.00 0.00 0.00 247,085.86

2,736.09 34.69 6,950.00 0.00 17,858,674.85

27,022.95 18,107.15 2,500.00 0.00 23,563.418.28

301,605.92 91,098.07 35,348.00 -10.44 104,327,342.23

1,618,718.44 1,368,522.40 1,729.04 0.00 123,929,203.02

559 648.21 853.65 45 345.25 0.00 15038171.94

2,509,731.61 1.478,615.96 91,872.29 -10.44 284,963,896.18

201513 Month Averaqe

277,084,371.84

-u en o ., - 0 cc a o CD CD >< ...... 3 ~ "' CD z o 3.o - . ~oo "' "' 0

~

"' (o "' CX>

NORTHWESTERN ENERGY - MONTANA COMMON UTILITY 2015 ACCUMULATED DEPRECIATION DATA

Reserve Balance Current Year Other Misc. Highway Transfers Functional Classification 12131/14 Accrual Credits Credits ~

C303 Intangible Plant 5,002,068.03 3, 152,279.40 0.00 0.00 0.00

C389 Land & land Rights -170,644.74 0.00 0.00 0.00 0.00

C390 Structures & Improve 13,472,495.47 635,205.96 0.00 0.00 0.00

C391 Office Equipment 5,030,112.30 803,005.80 0.00 0.00 0.00

C397 Communication Equip 10,778,098.67 1,014,563.64 0.00 0.00 0.00

C398 Misc. Equipment 530895.09 55 880.16 0.00 0.00 0.00

Total Common Utility 34,643,024.82 5,660,934.96 0.00 0.00 0.00

Allocated to:

Electric Utility

Natural Gas Utility


Reserve Balance Retirements Removals Salvage Other 12/31/15

2,321,008.11 0.00 0.00 5,833,339.32

0.00 193.73 3,750.00 -167,088.47

465,592.52 27,798.37 0.00 0.00 13.614,310.54

1,339,079.10 0.00 0.00 0.00 4,494,039.00

63,379.56 2,444.06 51.40 0.00 11,726,890.09

5 399.50 6 011.34 0.00 0.00 575 364.41

4,194,458.79 36,447.50 3,801.40 0.00 36,076,854.89

21,259.481.61

12,219, 160.50


36,963,734.00

23,656,790.00

13,306,944.00

I "'U 00 0 m D)o. "' - 0 CD CD "' _.. 3 s. t.> CD z o 3.o - .

I -'" O 0

1

2

3 4 5

6 7 8

Docket No. 02016.9.68 Statement D Page 14of19

NORTHWESTERN ENERGY - MONTANA COMMON UTILITY

13 Month Average Plant@ 12/31/15

96,320,301.00

13 Month Average Reserve@ 12/31/15

36,963, 734.46

2015 Book Accrual

Depreciation 2,508,655.56 Amortization 3, 152,279.40

Total 5,660,934.96

Test Period Book Accrual

Depreciation 2,508,655.56 Amortization 3, 152,279.40

Total 5,660,934.96

Electric Natural Gas

62,743,044.00 33,577 ,257 .00


23,656,790.05 13,306,944.41


1, 781, 145.45 727,510.11 2,238, 118.37 914,161.03 4,019,263.82 1,641,671.14


1,781,145.45 727,510.11 2,238, 118.37 914,161.03 4,019,263.82 1,641,671.14



No policy change has been made effective since the period covered by the last annual report on FERC

Form No. 1 as filed with the FERC or the annual report as filed with the Montana Public Service

Commission (MPSC).

During 2D16, NorthWestern Energy engaged Foster Associates, Inc. to conduct a Depreciation Rate

Technical Update for all Utility Property through for all gas utility depreciable property through

December 31, 2015. The results of that Technical Update have been included in a normalizing

adjustment to the 2015 book depreciation expense.

The actual mechanics of computation are as follows:

Strait line method is used. All accounts are depreciated by application of a depreciation rate to the

original cost of the property.

It should be noted that the depreciation rate used above reflects consideration of expected average

service life and net salvage costs.


DEPRECIATION POLICY


The depreciation policy of NorthWestern Energy is as stated in our annual report on 10K, "Notes to

Consolidated Financial Statement, Note No. 2 - Significant Accounting Policies". This note is included in

other published documents of the Company.

The note is reproduced below:

Propertv. Plant and Equipment

Property, plant and equipment are stated at original cost, including contracted services, direct labor and material, AFUDC,

and indirect charges for engineering, supervision and similar overhead items. All expenditures for maintenance and repairs of

utility property, plant and equipment are charged to the appropriate maintenance expense accounts. A betterment or

replacement of a unit of property is accounted for as an addition and retirement of utility plant. At the time of such a

retirement, the accumulated provision for depreciation is charged with the original cost of the property retired and also for the

net cost of removal. Also included in plant and equipment are assets under capital lease, which are stated at the present value

of minimum lease payments.

AFUDC represents the cost of financing construction projects with borrowed funds and equity funds. While cash is not

realized currently from such allowance, it is realized under the rate making process over the service life of the related property

through increased revenues resulting from a higher rate base and higher depreciation expense. The component of AFUDC

attributable to borrowed funds is included as a reduction to interest expense, while the equity component is included in other

income. We determine the rate used to compute AFUDC in accordance with a formula established by the FERC. This rate

averaged 7.5%, 8.0%, and 8.1%, for Montana and South Dakota for 2015, 2014, and 2013, respectively. AFUDC capitalized

totaled $13.6 million for the year ended December 31, 2015, $10.8 million for the year ended December 31, 2014 and $8.2

million for the year ended December 31, 2013 for Montana and South Dakota combined.

We record provisions for depreciation at amounts substantially equivalent to calculations made on a straight-line method

by applying various rates based on useful lives of the various classes of properties (ranging from three to 50 years) determined

from engineering studies. As a percentage of the depreciable utility plant at the beginning of the year, our provision for

depreciation of utility plant was approximately 3.3%, 2.9%, and 3.2% for 2015, 2014, and 2013, respectively.

Depreciation rates include a provision for our share of the estimated costs to decommission our jointly owned plants at

the end of the useful life. The annual provision for such costs is included in depreciation expense, while the accumulated

provisions are included in noncurrent regulatory liabilities.


ALLOCATION METHOD

UocKet No. DZOT6:e;sa · Statement D Page 17of19

The same allocation method has been followed in this application that was included in and was accepted

by the Montana Public Service Commission in the electric rate application, Docket No. 83.9.67, Order

No. 5051c.


Docket No. 02016.9.68 Statement D Page 18of19

The only overall plant allocation made is the apportionment of common utility plant to the Gas Utility.

For the test period, allocations of Common Utility Plant at December 31, 2015 were made to the Gas Utility based on the percentages for 2015.

The methods, procedures and significant data used are included in the following sheets which portray the percentage allocations for the Test Period.

MEMORANDUM

TO:

FROM:

DATE:

File

John Peters

October 27, 2014


RE: 2015 MONTANA ADMINISTRATIVE AND GENERAL ALLOCATION STUDY INCLUDING HYDRO BUDGET PLANT & LABOR

The September 2014 period allocation study was completed October 27, 2014. The same criteria for both the General Office and Divisions was used as in prior studies. The results are:

General Office Electric & Gas Allocation Study (September 2014)

Factors used were: 1. Rate-Based Plant Balances (September 2014) 2. Customers (September 2014) 3. Operations Labor (12ME September 2014)

The results are: Electric • 71 % Gas. 29% Propane· 0%

Division Allocation Study (September 2014)

Factors used were: 1. Customers {by Division September 2014) 2. Distribution O&M (12ME September 2014) 3. Distribution Plant (by Division September 2014)

The results are: Electric Gas

Billings & Lewistown •........ 91% 9o/o Bozeman & Livingston ....... 69% 31% Butte ................................ 65% 35% Great Falls ........................ 88% 12% Havre ............................... 73% 27% Helena .............................. 70% 30% Missoula & Hamilton .......... 65% 35% Kalispell .......................... 0% 100%

Common T&D (Segments) A/location Study (September 2014)

Factors used were: 1. O&M Labor(12ME September2014)

The results are:

Electric Other Generation ..... . Electric Hydro Generation .... . Electric Transmission .......... . Electric Distribution ............. .

Subtotal-Electric ......... .

Natural Gas Production ...... .. Natural Gas Storage ........... . Natural Gas Transmission .... . Natural Gas Distribution ....... .

Subtotal-Natural Gas .. ..

Common Common Common Electric & Electric

6% 0%

23% 71%

100%

Oo/o

Gas

0%

14% 3%

31% 52%

100%

Gas

4% 0%

16% 51%

71%

4% 1% 9%

15%

29%

Allocation Report


13 Month Avg Balance Known Amount Claimed

Line @ 12/31/15 Changes in Rate Base

1 Gross Cash Requirements -13,582,217 -4,835,508 -18,417,725

2 Materials and Supplies 7,085,112 0 7,085,112

3 TOTAL -6,497,105 -4,835,508 -11,332,613

Docket No. 02016.9.68 Statement E Page 1of7

STATEMENT E WORKING CAPITAL

NORTHWESTERN ENERGY - MONTANA GAS UTILITY CALCULATION OF CASH WORKING CAPITAL

MONT ANA TRANSMISSION, DISTRIBUTION & STORAGE TEST PERIOD 2015

2 3 4 5

6

7

8

9

10

11

GAS DELIVERY 0 & M COSTS OTHER TAXES ST ATE INCOME TAXES FEDERAL INCOME TAXES

SUB-TOTAL

RATE BASE wfo ewe

WEIGHTED COST OF DEBT '2

INTEREST EXPENSE IN RETURN

TOTAL CASH WORKING REQUIREMENT

WORKING CASH- 2015 ACTUAL

CASH WORKING CAPITAL ADJUSTMENT

375,769, 169

2.49o/o

1' NET LAG DAYS FROM MAC 2015 LEAD/LAG UPDATE

2* WEIGHTED COST FROM PROPOSED CAPITAL STRUCTURE

12 MONTH ENDED EXPENSES

47,649,005 33,975,479

0 1

81,624,485

9,356,652

Docket No. 02016.9.68 Statement E Page 2 of 7

NET LAG CASH DAYS *1 WORKING CAPITAL

-65.21 -14,582,829

-48.41 -1,240,974

-15,823,803

-13,582.217

-2,241,586


BATTLE CREEK TEST PERIOD 2015

1 2 3 4 5

6

7

8

9

10

11

1·

2·

GAS DELIVERY 0 & M COSTS OTHER TAXES STATE INCOME TAXES FEDERAL INCOME TAXES

SUB-TOTAL

RATE BASEw/oCWC

WEIGHTED COST OF DEBT •2


TOTAL CASH \AJORl


BEAR PAW TEST PERIOD 2015

1 2 3 4 5

6

7

8

9

10

11

1•

2•


SUB-TOTAL

RA TE BASE w/o ewe




WORKING CASH - 2015 ACTUAL (was not split)


11,805,265

2.490/o

NET LAG DAYS FROM MAC 2015 LEAD/LAG UPDATE

WEIGHTED COST FROM PROPOSED CAPITAL STRUCTURE


3,049,652 283,586

-1 0

3,333,238

293,951

Docket No. 02016.9.68 Statement E

•Page 4 of 7

NETLAG CASH DAYS *1 WORKING CAPITAL

-65.21 -595,508

-48.41 -38,987

-634,495

0

-634,495


SOUTH BEAR PAW TEST PERIOD 2015

1 2 3 4 5

6

7

8

9

10

11

1·

2·


SUB-TOTAL

RATE BASE w/o ewe




WORKING CASH - 2015 ACTUAL (was not split)


51,635,351

2.49%

NET LAG DAYS FROM MAC 2015 LEAD/LAG UPDATE

WEIGHTED COST FROM PROPOSED CAPITAL STRUCTURE


8,261,854 397,219

0 0

8,659,073

1,285,720

Docket No. 02016.9.68 Statement E Page 5 of7

NET LAG CASH DAYS *1 WORKING CAPITAL

-65.21 -1,547,009

-48.41 -170,525

-1,717,534

0

-1,717,534

NORTHWESTERN ENERGY MONTANA GAS OPERATIONS

MATERIALS & SUPPLIES BALANCES

MONTANA

GAS M&S

M & S 5,940,638.79

FUEL 391,211.65

DECEMBER 2014 6,331,850.44

M & S 6,574,804.47

FUEL 367,398.14

JANUARY 2015 6,942,202.61

M&S 6,761,129.55

FUEL 276,927.78

FEBRUARY 2015 7,038,057.33

M & S 6,960,658.80

FUEL 309,887.39

MARCH 2015 7,270,546.19

M & S 6,884,275.10

FUEL 304,460.22

APRIL 2015 7,188,735.32

M & S 7,018,014.74

FUEL 299,674.65

MAY 2015 7,317,689.39

M & S 6,927, 182.69

FUEL 294,928.70

JUNE 2015 7,222, 111.39

M & S 6,972,219.52

FUEL 291,499.05

Docket No. 02016.9.68 Statement E Page 6 of 7

JULY 2015

M&S

Documents

DOCKET NO. D2016.9 - NorthWestern Energy · D2016.9.68 Application for Authority to Change and Establish Natural Gas Delivery Service and Production Rates Revenue Requirement (Phase