Delaware (State or other jurisdiction of incorporation) | 1-10499 (Commission File Number) | 46-0172280 (IRS Employer Identification No.) | ||
3010 W. 69th Street Sioux Falls, South Dakota (Address of principal executive offices) | 57108 (Zip Code) | |||
(605) 978-2900 (Registrant's telephone number, including area code) |
Emerging Growth Company o |
Item 2.02 | Results of Operations and Financial Condition |
Item 9.01 | Financial Statements and Exhibits. |
EXHIBIT NO. | DESCRIPTION OF DOCUMENT |
99.1* | Press Release dated November 1, 2017 |
99.2* | Investor Call Presentation, dated November 2, 2017 |
NORTHWESTERN CORPORATION | |||
By: | /s/ Timothy P. Olson | ||
Timothy P. Olson | |||
Corporate Secretary |
NorthWestern Corporation d/b/a NorthWestern Energy 3010 W. 69th Street Sioux Falls, SD 57108 www.northwesternenergy.com |
Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||
(in thousands, except per share amounts) | 2017 | 2016 | 2017 | 2016 (2) | |||||||||||
Revenues | $ | 309,933 | $ | 300,998 | $ | 961,104 | $ | 926,657 | |||||||
Cost of sales | 97,507 | 96,156 | 301,324 | 293,283 | |||||||||||
Gross Margin (1) | 212,426 | 204,842 | 659,780 | 633,374 | |||||||||||
Operating, general and administrative expense | 70,244 | 68,290 | 226,394 | 220,730 | |||||||||||
Property and other taxes | 39,111 | 40,673 | 118,520 | 111,302 | |||||||||||
Depreciation and depletion | 41,525 | 39,763 | 124,481 | 119,551 | |||||||||||
Total Operating Expenses | 150,880 | 148,726 | 469,395 | 451,583 | |||||||||||
Operating Income | 61,546 | 56,116 | 190,385 | 181,791 | |||||||||||
Interest expense, net | (23,149 | ) | (21,049 | ) | (69,957 | ) | (71,979 | ) | |||||||
Other income (loss) | 790 | (121 | ) | 4,413 | 4,176 | ||||||||||
Income Before Income Taxes | 39,187 | 34,946 | 124,841 | 113,988 | |||||||||||
Income tax (expense) benefit | (2,775 | ) | 9,659 | (10,032 | ) | 6,053 | |||||||||
Net Income | $ | 36,412 | $ | 44,605 | $ | 114,809 | $ | 120,041 | |||||||
Basic: Average Shares Outstanding | 48,487 | 48,315 | 48,441 | 48,289 | |||||||||||
Earnings per Share - Basic | $ | 0.75 | $ | 0.92 | $ | 2.37 | $ | 2.49 | |||||||
Diluted: Average Shares Outstanding | 48,551 | 48,490 | 48,507 | 48,464 | |||||||||||
Earnings per Share - Diluted | $ | 0.75 | $ | 0.92 | $ | 2.37 | $ | 2.48 | |||||||
Dividends Declared per Common Share | $ | 0.525 | $ | 0.500 | $ | 1.575 | $ | 1.500 | |||||||
(1) Gross Margin is a non-GAAP financial measure. See "Non-GAAP Financial Measures" section below for more information. | |||||||||||||||
(2) During the fourth quarter of 2016, we early adopted the provisions of Accounting Standards Update No. 2016-09 (ASU 2016-09), Improvements to Employee Share-Based Payment Accounting, revising certain elements of the accounting for share-based payments. As a result of this adoption, during the fourth quarter of 2016, excess tax benefits of $1.8 million related to vested share-based compensation awards were recorded as a decrease in income tax expense in the Condensed Consolidated Statement of Income. The guidance also requires that in future filings that include the previously issued interim financial information, the interim financial information is presented on a recast basis to reflect the adoption of ASU 2016-09 as of January 1, 2016. The Condensed Consolidated Financial Statements for the Nine Months Ended September 30, 2016 have been recast to reflect this adoption, resulting in an increase in net income and earnings per share. |
• | $5.1 million improved electric retail volumes due primarily to warmer summer weather in our Montana jurisdiction and customer growth; partly offset by cooler summer weather in our South Dakota jurisdiction; |
• | $0.7 million increase due to a final order from the Montana Public Service Commission (MPSC) in our natural gas rate case. This includes an increase of approximately $0.6 million from the resolution of the deferral of gas production interim rates and a $0.1 million increase in rates effective September 1, 2017; |
• | $0.1 million increase in natural gas retail volumes due primarily to customer growth and higher commercial volumes in our Montana jurisdiction partly offset by warmer summer weather; and |
• | $1.6 million increase in other miscellaneous margin items. |
• | $1.0 million decrease in production tax credits, which is an increase in our customer rates, is offset by increased income tax expense; and |
• | $0.6 million increase in operating expenses included in our supply trackers which is offset by an increase in operating, general and administrative expenses; |
• | $1.0 million decrease in revenues for property taxes included in trackers which is offset by decreased property tax expense; and |
• | $0.2 million decrease in natural gas production gathering fees which is offset by a decrease in operating expenses. |
• | $1.8 million increase in employee benefits due to higher medical and supplemental benefit costs; |
• | $0.6 million higher operating expenses recovered through our supply trackers (as discussed above); |
• | $0.4 million higher bad debt expense due to increase in revenues as a result of warmer summer weather in Montana; and |
• | $0.3 million increase in value of non-employee directors deferred compensation due to changes in our stock price (offset by changes in other income with no impact on net income). |
• | $0.6 million lower maintenance costs at our Dave Gates Generating Station; |
• | $0.2 million decrease in natural gas production gathering expense (offset by lower gathering fee revenue discussed above); and |
• | $0.4 million decrease in other miscellaneous expense. |
(in millions) | Three Months Ended September 30, | Nine Months Ended September 30, | |||||||||||||||||||||||
2017 | 2016 | 2017 | 2016 | ||||||||||||||||||||||
Income Before Income Taxes | $ | 39.2 | $ | 34.9 | $ | 124.8 | $ | 74.3 | |||||||||||||||||
Income tax calculated at 35% federal statutory rate | 13.7 | 35.0 | % | 12.2 | 35.0 | % | 43.7 | 35.0 | % | 39.9 | 35.0 | % | |||||||||||||
Permanent or flow-through adjustments: | |||||||||||||||||||||||||
State income, net of federal provisions | (0.7 | ) | (1.7 | )% | (0.6 | ) | (1.8 | )% | (2.0 | ) | (1.6 | )% | (3.0 | ) | (2.6 | )% | |||||||||
Flow-through repairs deductions | (7.0 | ) | (17.9 | )% | (19.0 | ) | (54.4 | )% | (20.6 | ) | (16.5 | )% | (32.7 | ) | (28.6 | )% | |||||||||
Production tax credits | (2.2 | ) | (5.8 | )% | (2.2 | ) | (6.3 | )% | (7.5 | ) | (6.0 | )% | (7.3 | ) | (6.4 | )% | |||||||||
Plant and depreciation of flow-through items | (0.1 | ) | (0.2 | )% | (0.2 | ) | (0.7 | )% | (2.2 | ) | (1.8 | )% | (1.4 | ) | (1.3 | )% | |||||||||
Prior year perm. return to accrual adj. | (0.8 | ) | (2.2 | )% | — | — | % | (0.8 | ) | (0.3 | )% | (1.6 | ) | (1.4 | )% | ||||||||||
Share-based compensation | — | — | % | — | — | % | (0.4 | ) | (0.7 | )% | (0.1 | ) | (0.1 | )% | |||||||||||
Other, net | (0.1 | ) | (0.1 | )% | 0.1 | 0.6 | % | (0.2 | ) | (0.1 | )% | 0.1 | 0.1 | % | |||||||||||
Subtotal | (10.9 | ) | (27.9 | )% | (21.9 | ) | (62.6 | )% | (33.7 | ) | (27.0 | )% | (46.0 | ) | (40.3 | )% | |||||||||
Income Tax Expense (Benefit) | $ | 2.8 | 7.1 | % | $ | (9.7 | ) | (27.6 | )% | $ | 10.0 | 8.0 | % | $ | (6.1 | ) | (5.3 | )% | |||||||
We adopted the provisions of ASU 2016-09, Improvements to Employee Share-Based Payment Accounting, during the fourth quarter of 2016, which resulted in the recognition of $1.8 million in excess tax benefits. In accordance with the guidance, the impact of this adoption is reflected as of January 1, 2016, and included in the state income, net of federal provisions, and share-based compensation lines, resulting in a reduction in tax expense for the nine months ended September 30, 2016. |
Reconciliation of Primary Changes from 2016 to 2017 | Three Months Ended September 30, | Nine Months Ended September 30, | |||||||||||||
($millions, except EPS) | Pre-tax Income | Net (1) Income | Diluted EPS | Pre-tax Income | Net (1) Income | Diluted EPS | |||||||||
2016 reported | $34.9 | $44.6 | $0.92 | $114.0 | $120.0 | $2.48 | |||||||||
Gross Margin | |||||||||||||||
Electric retail volumes | 5.1 | 3.1 | 0.06 | 12.3 | 7.6 | 0.16 | |||||||||
Montana natural gas and production rates | 0.7 | 0.4 | 0.01 | 0.1 | 0.1 | — | |||||||||
Natural gas retail volumes | 0.1 | 0.1 | — | 7.4 | 4.6 | 0.10 | |||||||||
Electric transmission | (0.3 | ) | (0.2 | ) | — | — | — | — | |||||||
2016 MPSC disallowance | — | — | — | 9.5 | 5.8 | 0.12 | |||||||||
South Dakota electric rate increase | — | — | — | 1.2 | 0.7 | 0.01 | |||||||||
Electric QF adjustment | — | — | — | 0.4 | 0.2 | — | |||||||||
2016 Lost revenue adjustment mechanism | — | — | — | (14.2 | ) | (8.7 | ) | (0.18 | ) | ||||||
Other | 1.6 | 1.0 | 0.02 | 2.8 | 1.7 | 0.04 | |||||||||
Subtotal: Margin Items Impacting Net Income | 7.2 | 4.4 | 0.09 | 19.5 | 12.0 | 0.25 | |||||||||
Production tax credits flowed through trackers | 1.0 | 0.6 | 0.01 | 0.4 | 0.2 | — | |||||||||
Operating expenses recovered in trackers | 0.6 | 0.4 | 0.01 | 1.0 | 0.6 | 0.01 | |||||||||
Property taxes recovered in trackers | (1.0 | ) | (0.6 | ) | (0.01 | ) | 5.3 | 3.3 | 0.07 | ||||||
Gas production gathering fees | (0.2 | ) | (0.1 | ) | — | 0.2 | 0.1 | — | |||||||
Subtotal: Margin Items Not Impacting Net Income (2) | 0.4 | 0.3 | 0.01 | 6.9 | 4.2 | 0.08 | |||||||||
Total Gross Margin | 7.6 | 4.7 | 0.10 | 26.4 | 16.2 | 0.33 | |||||||||
OG&A Expense | |||||||||||||||
Employee benefits | (1.8 | ) | (1.1 | ) | (0.02 | ) | (0.8 | ) | (0.5 | ) | (0.01 | ) | |||
Operating expenses recovered in trackers | (0.6 | ) | (0.4 | ) | (0.01 | ) | (1.0 | ) | (0.6 | ) | (0.01 | ) | |||
Bad debt expense | (0.4 | ) | (0.2 | ) | — | (2.3 | ) | (1.4 | ) | (0.03 | ) | ||||
Non-employee directors deferred compensation | (0.3 | ) | (0.2 | ) | — | 1.0 | 0.6 | 0.01 | |||||||
Maintenance costs | 0.6 | 0.4 | 0.01 | (1.4 | ) | (0.9 | ) | (0.02 | ) | ||||||
Natural gas production gathering expense | 0.2 | 0.1 | — | (0.2 | ) | (0.1 | ) | — | |||||||
Labor | — | — | — | (1.4 | ) | (0.9 | ) | (0.02 | ) | ||||||
Insurance reserves | — | — | 1.0 | 0.6 | 0.01 | ||||||||||
Other | 0.4 | 0.2 | — | (0.6 | ) | (0.4 | ) | — | |||||||
Total OG&A Expense | (1.9 | ) | (1.2 | ) | (0.02 | ) | (5.7 | ) | (3.6 | ) | (0.07 | ) | |||
Other items | |||||||||||||||
Depreciation and depletion expense | (1.7 | ) | (1.0 | ) | (0.02 | ) | (7.2 | ) | (4.4 | ) | (0.09 | ) | |||
Property and other taxes | 1.6 | 1.0 | 0.02 | (4.9 | ) | (3.0 | ) | (0.06 | ) | ||||||
Interest expense | (2.1 | ) | (1.3 | ) | (0.03 | ) | 2.0 | 1.2 | 0.02 | ||||||
Other income (incl. offset to Non-employee comp. above) | 0.9 | 0.6 | 0.01 | 0.2 | 0.1 | — | |||||||||
Permanent and flow-through adjustments to income tax | — | (11.0 | ) | (0.23 | ) | (11.7 | ) | (0.24 | ) | ||||||
Impact of higher share count | — | — | — | — | — | — | |||||||||
Total Other items | (1.3 | ) | (11.7 | ) | (0.25 | ) | (9.9 | ) | (17.8 | ) | (0.37 | ) | |||
Total impact of above items | 4.3 | (8.2 | ) | (0.17 | ) | 10.8 | (5.2 | ) | (0.11 | ) | |||||
2017 reported | $39.2 | $36.4 | $0.75 | $124.8 | $114.8 | $2.37 | |||||||||
(1) Income Tax Benefit (Expense) calculation on reconciling items assumes normal effective tax rate of 38.5%. | |||||||||||||||
(2) These items are offset in in related operating expenses and have no impact to net income. |
(in millions, except EPS) | ||||||
Three Months Ended September 30, 2017 | ||||||
Pre-tax Income | Net(1) Income | Diluted EPS | ||||
2017 Reported GAAP | $39.2 | $36.4 | $0.75 | |||
Non-GAAP Adjustments: | ||||||
Remove favorable weather during quarter | (0.4 | ) | (0.2 | ) | (0.01 | ) |
2017 Adjusted Non-GAAP | $38.8 | $36.2 | $0.74 | |||
Three Months Ended September 30, 2016 | ||||||
Pre-tax Income | Net(1) Income | Diluted EPS | ||||
2016 Reported GAAP | $34.9 | $44.6 | $0.92 | |||
Non-GAAP Adjustments: | ||||||
Add back unfavorable weather during quarter | 1.4 | 0.9 | 0.02 | |||
Remove generation repairs income tax benefit related to years prior to 2016 | - | (12.5 | ) | (0.26 | ) | |
2016 Adjusted Non-GAAP | $36.3 | $33.0 | $0.68 | |||
(1) Income Tax Benefit (Expense) calculation on reconciling items assumes normal effective tax rate of 38.5%. |
(in millions, except EPS) | Estimated to Meet Guidance | |||||||||||||||||||
Nine Months Ended September 30, 2017 | EPS Q4 2017 | EPS Full Year 2017 | ||||||||||||||||||
Pre-tax Income | Net(1) Income | Diluted EPS | Low | - | High | Low | - | High | ||||||||||||
2017 Reported GAAP | $124.8 | $114.8 | $2.37 | |||||||||||||||||
Non-GAAP Adjustments: | ||||||||||||||||||||
Remove favorable weather | (1.6 | ) | (1.0 | ) | (0.02 | ) | ||||||||||||||
2017 Adjusted Non-GAAP | $123.2 | $113.8 | $2.35 | $0.95 | - | $1.10 | $3.30 | - | $3.45 | |||||||||||
Nine Months Ended September 30, 2016 | Q4 2016 | Full Year 2016 | ||||||||||||||||||
Pre-tax Income | Net(1) Income | Diluted EPS | Pre-tax Income | Net(1) Income | Diluted EPS | Pre-tax Income | Net(1) Income | Diluted EPS | ||||||||||||
2016 Reported GAAP | $114.0 | $120.0 | $2.48 | $42.5 | $44.2 | $0.91 | $156.5 | $164.2 | $3.39 | |||||||||||
Non-GAAP Adjustments: | ||||||||||||||||||||
Add back unfavorable weather | 14.2 | 8.7 | 0.18 | 1.0 | 0.6 | 0.01 | 15.2 | 9.3 | 0.19 | |||||||||||
MPSC electric tracker disallowance of costs related to years prior to 2016 | 12.2 | 7.5 | 0.16 | — | — | — | 12.2 | 7.5 | 0.16 | |||||||||||
Remove Lost Revenue Adjustment Mechanism (LRAM) benefit related to years prior to 2016 | (14.2 | ) | (8.7 | ) | (0.18 | ) | — | — | — | (14.2 | ) | (8.7 | ) | (0.18 | ) | |||||
Remove generation repairs income tax benefit related to years prior to 2016 | — | (12.5 | ) | (0.26 | ) | — | — | — | — | (12.5 | ) | (0.26 | ) | |||||||
2016 Adjusted Non-GAAP | $126.2 | $115.0 | $2.38 | $43.5 | $44.8 | $0.92 | $169.7 | $159.8 | $3.30 | |||||||||||
(1) Income Tax Benefit (Expense) calculation on reconciling items assumes normal effective tax rate of 38.5%. |
• | Normal weather in our electric and natural gas service territories; |
• | A consolidated income tax rate of approximately 7%-11% of pre-tax income; and |
• | Diluted average shares outstanding of approximately 48.6 million. |
• | 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; |
• | 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 other developments, may reduce revenues or may increase operating costs, each of which could adversely affect our liquidity and results of operations; |
• | unscheduled generation outages or forced reductions in output, maintenance or repairs, which may reduce revenues and increase cost of sales or may require additional capital expenditures or other increased operating costs; and |
• | adverse changes in general economic and competitive conditions in the U.S. financial markets and in our service territories. |
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