Black Hills Corporation

11/05/2025 | Press release | Distributed by Public on 11/05/2025 15:49

Black Hills Corp. Reports 2025 Third-Quarter Results and Reaffirms 2025 Adjusted Earnings Guidance (Form 8-K)

Black Hills Corp. Reports 2025 Third-Quarter Results and Reaffirms 2025 Adjusted Earnings Guidance

•
Reaffirms 2025 adjusted earnings guidance in the range of $4.00 to $4.20 per share, excluding merger-related costs, same as prior GAAP guidance
•
Completed planned equity and debt financing activities for 2025
•
Filed settlement agreement for new customer rates at Nebraska natural gas utility
•
Completing construction of Ready Wyoming 260-mile transmission expansion project to be in service by year-end
•
Commenced construction of Lange II 99 MW generation facility in South Dakota to be in service during second half of 2026
•
Announced tax-free, all-stock merger with NorthWestern Energy in August and filed joint applications for regulatory approval in Montana, Nebraska and South Dakota in October

RAPID CITY, S.D. - Nov. 5, 2025 - Black Hills Corp. (NYSE: BKH) today announced financial results for the third quarter ended Sept. 30, 2025. Net income available for common stock and earnings per share, diluted (EPS) for the three and nine months ended Sept. 30, 2025, compared to the three and nine months ended Sept. 30, 2024, were:

Three Months Ended Sept. 30,

Nine Months Ended Sept. 30,

2025

2024

2025

2024

(in millions, except per share amounts)

GAAP:

Net income available for common stock

$

24.9

$

24.4

$

186.6

$

175.0

Earnings per share, Diluted

$

0.34

$

0.35

$

2.58

$

2.52

Non-GAAP (a):

Adjusted earnings

$

32.5

$

24.4

$

194.2

$

175.0

Adjusted EPS

$

0.45

$

0.35

$

2.68

$

2.52

(a)
During the three and nine months ended Sept. 30, 2025, Black Hills incurred transaction costs of $0.10 per share and $0.11 per share, respectively, related to the NorthWestern Energy merger. See additional details in the GAAP-to-Non-GAAP reconciliation table in the Use of Non-GAAP Financial Measures section below. Minor differences may result due to rounding.

Third quarter GAAP EPS was $0.34 compared to $0.35 in 2024. Third quarter adjusted EPS of $0.45, excluding $0.10 of merger-related costs, compared to $0.35 in the same period in 2024, benefited from new rates and rider recovery of $0.21 per share, which more than offset higher financing and depreciation costs and unfavorable weather.

Year-to-date GAAP EPS was $2.58 compared to $2.52 in the same period in 2024. Year-to-date adjusted EPS of $2.68, excluding $0.11 of merger-related costs, compared to $2.52 in the same period in 2024 benefited from new rates and rider recovery of $0.68 per share, along with favorable weather, which more than offset higher operating expenses, financing and depreciation costs.

"Our team delivered strong financial and operational results while successfully advancing key regulatory and growth initiatives," said Linn Evans, president and CEO of Black Hills Corp. "We completed our planned debt and equity financings for the year, maintaining strong credit quality and liquidity. In Nebraska, we secured a settlement for our natural gas rate review and are preparing to file a new Arkansas gas rate review by year-end. We also plan to file an electric rate review in South Dakota during the first quarter of 2026 - our first in more than a decade.

"Our $4.7 billion five-year capital plan prioritizes core customer needs for safety, reliability, and growth. By year-end, our 260-mile Ready Wyoming transmission expansion project will be complete, enabling a more reliable, interconnected grid to serve our customers. In 2026, our 99 MW Lange II generation project in South Dakota will replace aging infrastructure with advanced generation technology.

"Our five-year plan includes 500 MW of data center demand by 2029, driven by continued Microsoft expansion and Meta's new AI data center, which will transition from construction power to permanent service later this year. We are also actively negotiating with high-quality partners, expanding our data center load pipeline to more than 3 GW from our previously disclosed pipeline of more than 1 GW. This would drive significant earnings growth incremental to our current plan through our innovative data center tariff and strategic investments in new transmission and generation."

Merger with NorthWestern Energy Group, Inc.

Black Hills Corp. and NorthWestern Energy announced a tax-free, all-stock merger on Aug. 19, 2025. In October 2025, the companies filed joint applications for approval of the transaction with regulatory commissions in Montana, Nebraska and South Dakota. The companies anticipate filing an application with the Federal Energy Regulatory Commission (FERC) in the fourth quarter of 2025. The transaction is expected to close in the second half of 2026, subject to the satisfaction or waiver of certain closing conditions.

"We are advancing our proposed merger with NorthWestern Energy to create a premier Midwest utility presence with enhanced scale, resilience, and opportunities for growth as a combined company," said Linn Evans, president and CEO of Black Hills Corp. "Our joint regulatory filings underscore the transaction's substantial benefits for our customers and stakeholders."

THIRD-QUARTER 2025 HIGHLIGHTS AND RECENT UPDATES

Electric Utilities

•
During the third quarter, Wyoming Electric continued construction of its 260-mile, $350-million Ready Wyoming electric transmission expansion project. The project is on track and expected to be completed and in service by year-end 2025. The project is expected to maintain long-term cost stability for customers, enhance system resiliency and access to power markets, support local economic growth and facilitate development of Wyoming's strong wind and solar natural resources.
•
During the third quarter, South Dakota Electric commenced construction of its 99-megawatt, $280 million Lange II gas-fired generation project. The new facility is expected to be completed and in service during the second half of 2026. The addition of these resources will replace generation resources planned for retirement and support updated planning reserve margin requirements.
•
In 2024, Colorado Electric received approval from the Colorado Public Utilities Commission (CPUC) of a portfolio of projects resulting from a competitive bidding process to pursue its Colorado Clean Energy Plan to reduce emissions 80% by 2030 off a 2005 baseline. The projects included a 50-megawatt utility-owned battery storage project, a 200-megawatt solar power purchase agreement, and a 100-megawatt utility-owned solar project. On Oct. 8, 2025, the company filed a settlement for its request for a certificate of public convenience and necessity for the battery storage project and anticipates approval by year-end. On Oct. 29, 2025, the CPUC recommended continuing negotiations on the 200-megawatt solar power purchase agreement and recommended no further action on the 100-megawatt utility-owned solar project.

Gas Utilities

•
On Oct. 7, Nebraska Gas filed for approval from the Nebraska Public Service Commission of a unanimous settlement agreement for its rate review filed May 1, 2025. The settlement, pending commission approval, includes $23.9 million of new annual revenue based on a capital structure of 51% equity and 49% debt, and a return on equity of 9.85%. The settlement also provides renewal of a five-year system safety and integrity rider, an insurance cost recovery tracker, and a two-year weather normalization pilot program. The settlement allows for final rates on Jan. 1, 2026, replacing interim rates that were effective on Aug. 1, 2025.
•
On July 24, Kansas Gas received approval from the Kansas Corporation Commission of a settlement agreement for its rate review request seeking approval to recover approximately $118 million of system investments and increased operations and maintenance costs driven by inflation and operational needs to serve customers. The black box settlement provides approximately $10.8 million of new annual revenue, with new rates effective Aug. 1, 2025. The settlement provides the renewal of the company's safety and integrity rider and allows for a new insurance cost tracker with deferred accounting treatment. It also includes approval for the company to file an abbreviated case during the first quarter of 2026 that includes the addition of capital placed in service through Dec. 31, 2025.

Corporate and Other

•
On Oct. 28, Black Hills' board of directors approved a quarterly dividend of $0.676 per share payable on Dec. 1, 2025, to common shareholders of record at the close of business on Nov. 17, 2025. On an annualized basis, the dividend represents 55 consecutive years of increases, the second-longest track record in the electric and natural gas industry.
•
On Oct. 2, Black Hills completed a public debt offering of $450 million, 4.55% senior unsecured notes due Jan. 31, 2031. Proceeds will be used to repay the $300 million aggregate principal amount of its notes due Jan. 15, 2026, at or before maturity. Any remaining net proceeds may be used for general corporate purposes.
•
During the third quarter, the company issued a total of 2.6 million shares of new common stock for net proceeds of $154 million, including a block equity trade. Year to date, the company has issued a total of 3.7 million shares of new common stock for net proceeds of $220 million.
•
During the third quarter, Black Hills maintained its solid investment-grade credit ratings by rating agencies covering the company.
o
On Aug. 19, Moody's Ratings affirmed Black Hills' long-term issuer credit rating at Baa2 with a stable outlook
o
On Aug. 19, S&P Global Ratings affirmed Black Hills' issuer credit rating at BBB+ with a stable outlook

2

REAFFIRMS 2025 ADJUSTED EARNINGS GUIDANCE SAME AS PRIOR GAAP GUIDANCE

Black Hills reaffirms its guidance for 2025 adjusted earnings per share available for common stock* to be in the range of $4.00 to $4.20, based on the following assumptions issued on Feb. 5, 2025:

•
Normal weather conditions within our utility service territories
•
Constructive and timely outcomes of utility regulatory dockets;
•
Excludes mark-to-market adjustments;
•
No unplanned outages at our generation facilities;
•
Compounded annual growth rate of approximately 3.5% for operations and maintenance expense (excludes depreciation and amortization and taxes other than income taxes) off 2023 of $552 million
•
Equity issuance between $215 million and $235 million; and
•
An effective tax rate of approximately 13% for the full year.

* The 2025 adjusted earnings per share guidance shown above is a forward-looking, non-GAAP financial measure. The company is not able to provide comparable GAAP earnings per share guidance due to items that are not considered representative of the company's underlying operating performance that cannot be reasonably quantified for the full year period. These items include NorthWestern merger-related costs of $0.11 per share for the nine months ended Sept. 30, 2025, as well as additional NorthWestern merger-related costs the company expects to incur in the fourth quarter of 2025, in addition to any other unplanned items that may affect GAAP results during the remainder of 2025.

3

USE OF NON-GAAP FINANCIAL MEASURES

Adjusted Earnings and Adjusted EPS

As noted in this earnings release, in addition to presenting its earnings information in conformity with Generally Accepted Accounting Principles (GAAP), the company has provided non-GAAP Adjusted earnings and Adjusted EPS, which reflect adjustments for expenses, gains and losses that the company believes do not reflect ongoing core operating performance.

The company's management uses these non-GAAP financial measures as indicators for evaluating current periods and planning and forecasting future periods. The company also uses these non-GAAP measures when communicating with analysts and investors regarding our earnings results and outlook, as the company believes that these non-GAAP measures allow the company to more accurately compare its ongoing performance across periods. In providing adjusted earnings guidance, there could be differences between adjusted earnings and earnings prepared in accordance with GAAP as a result of our treatment of certain items, such as those described in the reconciliation below.

Limitations on the Use of Non-GAAP Measures

Non-GAAP measures have limitations as analytical tools and should not be considered in isolation or as a substitute for analysis of our results as reported under GAAP. Our presentation of these non-GAAP financial measures should not be construed as an inference that our future results will not be affected by unusual, non-routine, or non-recurring items. The company is not able to provide a forward-looking quantitative GAAP to Non-GAAP reconciliation for non-GAAP measures due to items that are not considered representative of the company's underlying operating performance that cannot be reasonably quantified, including merger-related costs and any other unplanned items that may affect GAAP results during the remainder of 2025.


Our non-GAAP measures may not be comparable to those of other companies. Non-GAAP measures should be used in addition to and in conjunction with results presented in accordance with GAAP. Non-GAAP measures should not be considered as an alternative to net income, operating income or any other operating performance measure prescribed by GAAP, nor should these measures be relied upon to the exclusion of GAAP financial measures. Our non-GAAP measures reflect an additional way of viewing our operations that we believe, when viewed with our GAAP results and the reconciliation to the corresponding GAAP financial measures, provide a more complete understanding of factors and trends affecting our business than could be obtained absent this disclosure. Management strongly encourages investors to review our financial information in its entirety and not rely on a single financial measure.

Three Months Ended Sept. 30,

Nine Months Ended Sept. 30,

2025

2024

2025

2024

(in millions, except per share amounts)

Net income available for common stock (GAAP)

$

24.9

$

24.4

$

186.6

$

175.0

Adjustment:

Merger-related costs

8.4

-

8.4

-

Less: tax effect of adjustment

(0.8

)

-

(0.8

)

-

Adjustment, net of tax

7.6

-

7.6

-

Adjusted earnings (non-GAAP)

$

32.5

$

24.4

$

194.2

$

175.0

Weighted average shares, diluted

72.9

70.6

72.4

69.3

Earnings per share, diluted (GAAP)

$

0.34

$

0.35

$

2.58

$

2.52

Adjustment:

Merger-related costs

0.11

-

0.12

-

Less: tax effect of adjustment

(0.01

)

-

(0.01

)

-

Adjustment, net of tax

0.10

-

0.11

-

Rounding

0.01

-

(0.01

)

-

Adjusted EPS (non-GAAP)

$

0.45

$

0.35

$

2.68

$

2.52

4

BLACK HILLS CORPORATION

CONSOLIDATED FINANCIAL RESULTS

(Minor differences may result due to rounding)

Three Months Ended Sept. 30,

Nine Months Ended Sept. 30,

2025

2024

2025

2024

(in millions, except per share amount)

Revenue

$

430.2

$

401.6

$

1,674.5

$

1,530.6

Operating expenses:

Fuel, purchased power and cost of natural gas sold

112.0

94.5

595.7

518.2

Operations and maintenance

150.8

145.6

452.2

420.8

Depreciation and amortization

71.5

69.3

210.5

201.8

Taxes other than income taxes

17.2

16.4

50.0

50.0

Total operating expenses

351.5

325.8

1,308.4

1,190.8

Operating income

78.7

75.8

366.1

339.8

Interest expense, net

(49.4

)

(45.2

)

(149.6

)

(131.9

)

Other income (expense), net

0.6

(1.3

)

1.1

(1.7

)

Income tax benefit (expense)

(4.0

)

(2.9

)

(26.5

)

(23.6

)

Net income

25.9

26.4

191.1

182.6

Net income attributable to non-controlling interest

(1.0

)

(2.0

)

(4.5

)

(7.6

)

Net income available for common stock

$

24.9

$

24.4

$

186.6

$

175.0

Weighted average common shares outstanding:

Basic

72.8

70.5

72.3

69.2

Diluted

72.9

70.6

72.4

69.3

Earnings per share:

Earnings per share, Basic

$

0.34

$

0.35

$

2.58

$

2.53

Earnings per share, Diluted

$

0.34

$

0.35

$

2.58

$

2.52

5

CONSOLIDATING INCOME STATEMENTS

(Minor differences may result due to rounding)

Consolidating Income Statement

Three Months Ended Sept. 30, 2025

Electric Utilities

Gas Utilities

Corporate and Other

Total

(in millions)

Revenue

$

249.7

$

184.4

$

(3.9

)

$

430.2

Fuel, purchased power and cost of natural gas sold

69.8

42.3

(0.1

)

112.0

Operations and maintenance

69.8

80.3

0.7

150.8

Depreciation and amortization

38.3

33.2

-

71.5

Taxes other than income taxes

9.4

7.8

-

17.2

Operating income

$

62.4

$

20.8

$

(4.5

)

$

78.7

Interest expense, net

(49.4

)

Other income (expense), net

0.6

Income tax benefit (expense)

(4.0

)

Net income

25.9

Net income attributable to non-controlling interest

(1.0

)

Net income available for common stock

$

24.9

Consolidating Income Statement

Three Months Ended Sept. 30, 2024

Electric Utilities

Gas Utilities

Corporate and Other

Total

(in millions)

Revenue

$

232.5

$

173.6

$

(4.5

)

$

401.6

Fuel, purchased power and cost of natural gas sold

54.9

39.7

(0.1

)

94.5

Operations and maintenance

65.1

84.8

(4.3

)

145.6

Depreciation and amortization

38.0

31.3

-

69.3

Taxes other than income taxes

9.4

6.9

0.1

16.4

Operating income

$

65.1

$

10.9

$

(0.2

)

$

75.8

Interest expense, net

(45.2

)

Other income (expense), net

(1.3

)

Income tax benefit (expense)

(2.9

)

Net income

26.4

Net income attributable to non-controlling interest

(2.0

)

Net income available for common stock

$

24.4

Three Months Ended Sept. 30, 2025, Compared to the Three Months Ended Sept. 30, 2024

•
Electric Utilities' operating income decreased $2.7 million primarily due to milder weather and higher operating
expenses partially offset by new rates and rider recovery;
•
Gas Utilities' operating income increased $9.9 million primarily due to new rates and rider recovery driven by the Arkansas Gas, Kansas Gas, and Nebraska Gas rate reviews and lower operating expenses partially offset by the unfavorable margin impacts of wet summer weather on Nebraska irrigation loads;
•
Corporate and Other operating loss increased $4.3 million primarily due to $8.4 million of NorthWestern merger-related costs partially offset by an unallocated favorable true-up of operating expenses; and
•
Interest expense, net increased $4.2 million primarily due to higher CP Program borrowings and lower interest income on lower cash and cash equivalents balances partially offset by higher AFUDC debt driven by construction work-in-progress balances related to the Lange II and Ready Wyoming projects.

6

Consolidating Income Statement

Nine Months Ended Sept. 30, 2025

Electric Utilities

Gas Utilities

Corporate and Other

Total

(in millions)

Revenue

$

706.3

$

979.9

$

(11.7

)

$

1,674.5

Fuel, purchased power and cost of natural gas sold

192.2

403.7

(0.2

)

595.7

Operations and maintenance

207.8

248.5

(4.1

)

452.2

Depreciation and amortization

113.0

97.6

(0.1

)

210.5

Taxes other than income taxes

27.6

22.4

-

50.0

Operating income

$

165.7

$

207.7

$

(7.3

)

$

366.1

Interest expense, net

(149.6

)

Other income (expense), net

1.1

Income tax benefit (expense)

(26.5

)

Net income

191.1

Net income attributable to non-controlling interest

(4.5

)

Net income available for common stock

$

186.6

Consolidating Income Statement

Nine Months Ended Sept. 30, 2024

Electric Utilities

Gas Utilities

Corporate and Other

Total

(in millions)

Revenue

$

659.8

$

884.2

$

(13.4

)

$

1,530.6

Fuel, purchased power and cost of natural gas sold

155.7

362.9

(0.4

)

518.2

Operations and maintenance

190.5

242.6

(12.3

)

420.8

Depreciation and amortization

108.9

92.8

0.1

201.8

Taxes other than income taxes

28.7

21.3

-

50.0

Operating income

$

176.0

$

164.6

$

(0.8

)

$

339.8

Interest expense, net

(131.9

)

Other income (expense), net

(1.7

)

Income tax benefit (expense)

(23.6

)

Net income

182.6

Net income attributable to non-controlling interest

(7.6

)

Net income available for common stock

$

175.0

Nine Months Ended Sept. 30, 2025, Compared to the Nine Months Ended Sept. 30, 2024

•
Electric Utilities' operating income decreased $10.3 million primarily due to higher operating expenses, unplanned generation outages, lower transmission services revenues and unfavorable weather partially offset by new rates and rider recovery;
•
Gas Utilities' operating income increased $43.1 million primarily due to new rates and rider recovery driven by the Arkansas Gas, Iowa Gas, Kansas Gas, and Nebraska Gas rate reviews and favorable weather partially offset by higher operating expenses;
•
Corporate and Other operating loss increased $6.5 million primarily due to $8.4 million of NorthWestern merger-related costs;
•
Interest expense, net increased $17.7 million due to higher interest rates on long-term debt, higher CP Program borrowings and lower interest income on lower cash and cash equivalents balances partially offset by higher AFUDC debt driven by construction work-in-progress balances related to the Lange II and Ready Wyoming projects;
•
Other income, net, increased $2.8 million primarily due to higher AFUDC equity driven by construction work-in-progress
balances related to the Lange II and Ready Wyoming projects;
•
Income tax expense increased $2.9 million primarily due to higher pre-tax income; and
•
Net income attributable to non-controlling interest decreased $3.1 million due to lower net income from Black Hills Colorado IPP primarily driven by unplanned generation outages.

7

OPERATING STATISTICS

Electric Utilities

Revenue

Quantities Sold

Three Months Ended Sept. 30,

Nine Months Ended Sept. 30,

Three Months Ended Sept. 30,

Nine Months Ended Sept. 30,

By Customer Class

2025

2024

2025

2024

2025

2024

2025

2024

(in millions)

(in GWh)

Retail Revenue -

Residential

$

68.8

$

66.1

$

189.3

$

179.4

393.5

411.1

1,120.9

1,123.4

Commercial

74.6

70.7

210.3

199.9

561.6

571.9

1,578.5

1,590.6

Industrial (a)

49.8

41.6

147.3

126.8

639.1

531.5

1,912.8

1,643.4

Municipal

4.6

4.4

13.4

12.8

41.4

41.4

110.1

111.7

Other Retail

3.5

3.5

10.3

10.5

-

-

-

-

Subtotal Retail Revenue - Electric

201.3

186.3

570.6

529.4

1,635.6

1,555.9

4,722.3

4,469.1

Wholesale

5.5

6.1

16.9

21.1

110.5

124.4

366.7

459.2

Market - off-system sales

16.3

10.7

38.3

22.8

267.0

227.0

660.6

506.8

Transmission

11.1

13.6

33.3

39.1

-

-

-

-

Other (b)

15.5

15.8

47.2

47.4

-

-

-

-

Total Revenue and Quantities Sold

$

249.7

$

232.5

$

706.3

$

659.8

$

2,013.1

$

1,907.3

5,749.6

5,435.1

Other Uses, Losses, or Generation, net (c)

112.9

110.7

332.4

237.5

Total Energy

2,126.0

2,018.0

6,082.0

5,672.6

(a)
The increase in industrial revenues and quantities sold for the three and nine months ended Sept. 30, 2025, compared to the same periods in 2024, was primarily driven by Wyoming Electric LPCS Tariff and BCIS Tariff customers.
(b)
Includes Integrated Generation, inter-segment rent, and non-regulated services to our retail customers under the Service Guard Comfort Plan and Tech Services.
(c)
Includes company uses and line losses.

Revenue

Quantities Sold

Three Months Ended Sept. 30,

Nine Months Ended Sept. 30,

Three Months Ended Sept. 30,

Nine Months Ended Sept. 30,

By Business Unit

2025

2024

2025

2024

2025

2024

2025

2024

(in millions)

(in GWh)

Colorado Electric

$

79.6

$

74.9

$

218.3

$

208.7

621.3

675.4

1,677.7

1,816.8

South Dakota Electric

90.6

86.0

255.5

242.5

711.8

669.8

2,032.7

1,882.3

Wyoming Electric

68.6

60.3

200.0

176.7

659.9

537.1

1,970.9

1,661.8

Integrated Generation

10.9

11.3

32.5

31.9

20.1

25.0

68.3

74.2

Total Revenue and Quantities Sold

$

249.7

$

232.5

$

706.3

$

659.8

2,013.1

1,907.3

5,749.6

5,435.1

Three Months Ended Sept. 30,

Nine Months Ended Sept. 30,

2025

2024

2025

2024

Degree Days

Actual

Variance from Normal

Actual

Variance from Normal

Actual

Variance from Normal

Actual

Variance from Normal

Heating Degree Days:

Colorado Electric

34

(15)%

19

(57)%

3,390

8%

3,050

(8)%

South Dakota Electric

86

(41)%

48

(71)%

4,432

---

4,080

(12)%

Wyoming Electric

157

---

109

(35)%

4,382

2%

4,135

(8)%

Combined (a)

77

(24)%

47

(58)%

3,952

3%

3,624

(10)%

Cooling Degree Days:

Colorado Electric

770

(13)%

904

5%

1,005

(14)%

1,247

10%

South Dakota Electric

598

10%

789

57%

760

15%

903

48%

Wyoming Electric

277

(31)%

368

(6)%

337

(30)%

486

6%

Combined (a)

610

(8)%

756

17%

785

(8)%

975

19%

(a)
Degree days are calculated based on a weighted average of total customers by state.

8

Three Months Ended Sept. 30,

Nine Months Ended Sept. 30,

Contracted generating facilities Availability(a) by fuel type

2025

2024

2025

2024

Coal

77.3%

90.7%

80.6%

87.3%

Natural gas and diesel oil

97.9%

98.0%

94.2%

95.4%

Wind

82.8%

92.3%

82.6%

91.6%

Total Availability (b)

89.9%

95.1%

88.7%

92.5%

Wind Capacity Factor (a)

26.1%

32.0%

32.4%

36.2%

(a)
Availability and Wind Capacity Factor are calculated using a weighted average based on capacity of our generating fleet.
(b)
2025 included unplanned outages at Wygen III, Pueblo Airport Generation #4-5, and Busch Ranch I and II. 2024 includes unplanned outages at Wygen I and Pueblo Airport Generation #4-5.

OPERATING STATISTICS (continued)

Gas Utilities

Revenue

Quantities Sold and Transported

Three Months Ended Sept. 30,

Nine Months Ended Sept. 30,

Three Months Ended Sept. 30,

Nine Months Ended Sept. 30,

By Customer Class

2025

2024

2025

2024

2025

2024

2025

2024

(in millions)

(Dth in millions)

Retail Revenue -

Residential

$

86.0

$

76.2

$

543.4

$

476.5

3.6

3.5

41.5

38.2

Commercial

30.0

27.2

206.3

183.9

2.5

2.4

20.5

19.3

Industrial

8.2

7.6

21.3

18.5

2.0

2.4

4.4

5.1

Other Retail (a)

4.4

6.5

26.0

28.9

-

-

-

-

Subtotal Retail Revenue - Gas

128.6

117.5

797.0

707.8

8.1

8.3

66.4

62.6

Transportation

43.6

43.2

143.4

130.9

36.2

35.8

122.8

117.0

Other (b)

12.2

12.9

39.5

45.5

-

-

-

-

Total Revenue and Quantities Sold

$

184.4

$

173.6

$

979.9

$

884.2

44.3

44.1

189.2

179.6

(a)
Includes Black Hills Energy Services revenue under the Choice Gas Program.
(b)
Includes inter-segment rent and non-regulated services under the Service Guard Comfort Plan, Tech Services, and HomeServe.

Revenue

Quantities Sold and Transported

Three Months Ended Sept. 30,

Nine Months Ended Sept. 30,

Three Months Ended Sept. 30,

Nine Months Ended Sept. 30,

By Business Unit

2025

2024

2025

2024

2025

2024

2025

2024

(in millions)

(Dth in millions)

Arkansas Gas

$

31.0

$

25.4

$

196.5

$

167.2

4.9

4.5

23.4

21.5

Colorado Gas

27.9

31.5

182.7

191.5

3.5

3.3

21.9

21.3

Iowa Gas

21.7

21.0

138.6

110.4

6.1

5.8

28.1

26.4

Kansas Gas

23.7

19.6

114.9

90.8

8.6

8.5

27.9

26.1

Nebraska Gas

57.2

54.2

245.4

218.9

15.6

16.5

61.7

58.1

Wyoming Gas

22.9

21.9

101.8

105.4

5.6

5.5

26.2

26.2

Total Revenue and Quantities Sold

$

184.4

$

173.6

$

979.9

$

884.2

44.3

44.1

189.2

179.6

Three Months Ended Sept. 30,

Nine Months Ended Sept. 30,

2025

2024

2025

2024

Heating Degree Days

Actual

Variance from Normal

Actual

Variance from Normal

Actual

Variance from Normal

Actual

Variance from Normal

Arkansas Gas (a)

1

(92)%

9

(40)%

2,151

(3)%

1,925

(18)%

Colorado Gas

99

(7)%

80

(29)%

3,758

---

3,613

(5)%

Iowa Gas

75

2%

45

(47)%

4,003

(1)%

3,450

(19)%

Kansas Gas (a)

18

(20)%

19

(26)%

3,001

7%

2,576

(11)%

Nebraska Gas

41

(23)%

22

(65)%

3,633

---

3,281

(12)%

Wyoming Gas

153

(22)%

132

(37)%

4,586

---

4,384

(6)%

Combined (b)

71

(11)%

50

(43)%

3,811

(1)%

3,502

(11)%

(a)
Arkansas Gas and Kansas Gas have weather normalization mechanisms that mitigate the weather impact on revenue.
(b)
The combined heating degree days are calculated based on a weighted average of total customers by state excluding Kansas Gas due to its weather normalization mechanism. Arkansas Gas is partially excluded based on the weather normalization mechanism in effect from November through April.

9

CONFERENCE CALL AND WEBCAST

Black Hills will host a live conference call and webcast at 11 a.m. EST on Thursday, Nov. 6, 2025, to discuss the company's financial results.

To participate by phone and ask a question during the live broadcast, participants can access the event directly at Black Hills Corp. Conference Q&A. Please allow at least five minutes to register. Upon registration, dial-in information will be provided, including a personal identification number.

To access a listen-only webcast and view presentation slides, please register at Black Hills Corp. Webcast. At the conclusion of the call, a replay of the broadcast will be available at this link and at Black Hills' investor relations website for up to one year.

EEI FINANCIAL CONFERENCE ATTENDANCE

Leadership from Black Hills will be attending the 2025 Edison Electric Institute Financial Conference taking place from Nov. 9, 2025, though Nov. 11, 2025. An investor presentation will be available prior to the conference on Black Hills' website at www.blackhillscorp.com under "Events and Presentations."

ABOUT BLACK HILLS CORP.

Black Hills Corp. (NYSE: BKH) is a customer-focused, growth-oriented utility company with a tradition of improving life with energy and a vision to be the energy partner of choice. Based in Rapid City, South Dakota, the company serves 1.35 million natural gas and electric utility customers in eight states: Arkansas, Colorado, Iowa, Kansas, Montana, Nebraska, South Dakota and Wyoming. More information is available at www.blackhillscorp.com.

Black Hills Corporation published this content on November 05, 2025, and is solely responsible for the information contained herein. Distributed via Edgar on November 05, 2025 at 21:49 UTC. If you believe the information included in the content is inaccurate or outdated and requires editing or removal, please contact us at [email protected]