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Otter Tail Corporation Announces Second Quarter Earnings

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Reaffirms 2019 Earnings Per Share Guidance Range of $2.10-$2.25
Board of Directors Declares Quarterly Dividend of $0.35 Per Share

FERGUS FALLS, Minn., Aug. 05, 2019 (GLOBE NEWSWIRE) -- Otter Tail Corporation (OTTR) today announced financial results for the quarter ended June 30, 2019.

Summary:

  • Consolidated operating revenues increased 1.3% to $229.2 million compared with $226.3 million for the second quarter of 2018.

  • Consolidated net income and diluted earnings per share were $15.4 million and $0.39 per share, respectively, compared with $18.7 million and $0.47 per share for the second quarter of 2018.

  • The corporation reaffirms its 2019 earnings guidance range of $2.10-$2.25 per diluted share.

CEO Overview
“We are reaffirming our 2019 diluted earnings per share guidance range of $2.10-$2.25. Our second quarter earnings per share is in line with our expectations. Our Electric segment quarter-over-quarter earnings decreased $3.1 million mainly due to the planned outage at Coyote Station, unexpected turbine repairs at our Hoot Lake Plant and milder weather during the quarter compared with the same period last year. The last half of 2018 included a planned outage at our Big Stone Plant, costs associated with the establishment of foundations at Otter Tail Corporation and Otter Tail Power Company and increased tax expense at corporate related to certain tax matters. We don’t expect these costs to occur in the second half of 2019,” said President and CEO Chuck MacFarlane.

“Our Manufacturing segment earnings increased $0.4 million primarily due to improved performance at BTD Manufacturing, with continued operational improvement at its Georgia plant. Earnings from T.O. Plastics were essentially unchanged between the quarters.

“Our Plastics segment second quarter results were $0.4 million lower than 2018 second quarter results driven by lower sales prices on slightly higher volumes. Our business outlook for this segment calls for lower earnings in 2019.

“We closed on the purchase of certain development assets from EDF Renewables Development, Inc. (EDF) in July and have issued a notice to proceed on construction of our $270 million, 150-megawatt Merricourt Wind Energy Center in southeastern North Dakota. An affiliate of EDF and its contractors will begin construction in August with completion anticipated in October 2020. We project our customers will receive approximately 30 percent of their energy from renewable resources we own or secure through power-purchase agreements by 2021.

“In our South Dakota general rate case, the South Dakota Public Utilities Commission approved a partial settlement in March 2019 along with an 8.75 percent return on equity and a transmission rate base adjustment during the second quarter, resulting in an annual revenue increase that is 69 percent of our requested increase. The settlement includes approval of a phase-in plan to provide for a return on amounts invested in the Merricourt Wind Energy Center and Astoria Station generation projects while under construction, along with a moratorium on filing another general rate case in South Dakota until the projects have been in service for one year.

“We began construction of our Astoria Station natural gas-fired combustion turbine generation project in May with site grading and foundation preparation for the switching station. The project continues to be on schedule and on budget.

“Otter Tail Power Company continues to benefit from strong rate base growth investments and expects to invest $1 billion in capital projects from 2019 through 2023, including regulated investments in renewable generation and Astoria Station. This results in a projected compounded annual growth rate of approximately 9 percent in utility rate base from year-end 2018 through 2023 and is expected to deliver value to customers and shareholders. We continue to make system investments to meet our customers’ expectations and enable us to work smarter, reduce emissions and improve reliability and safety.

“Our strategic initiatives to grow our businesses, achieve operational and commercial excellence, and develop our talent are strengthening our position in the markets we serve.”

Cash Flows and Liquidity
Our consolidated cash provided by operations for the six months ended June 30, 2019 was $69.3 million compared with $53.4 million for the six months ended June 30, 2018. The primary reasons for the $15.9 million increase in cash provided by operations between the periods was a $10.0 million decrease in discretionary contributions to the corporation’s funded pension plan and a $12.7 million net increase in cash provided by changes in noncurrent liabilities and deferred credits, partially offset by a $6.4 million decrease in cash from changes in deferred debits and other assets between the periods.

The following table presents the status of the corporation’s lines of credit:

(in thousands)

Line Limit

In Use On
June 30, 2019

Restricted due to
Outstanding
Letters of Credit

Available on
June 30, 2019

Available on
December 31,
2018

Otter Tail Corporation Credit Agreement

$

130,000

$

13,801

$

--

$

116,199

$

120,785

Otter Tail Power Company Credit Agreement

170,000

22,801

8,766

138,433

160,316

Total

$

300,000

$

36,602

$

8,766

$

254,632

$

281,101

Both credit agreements are in place until October 31, 2023.

Board of Directors Declared Quarterly Dividend
On August 5, 2019 the corporation’s Board of Directors declared a quarterly common stock dividend of $0.35 per share. This dividend is payable September 10, 2019 to shareholders of record on August 15, 2019.

2019 Segment Performance Summary

Electric

Three Months ended June 30,

($s in thousands)

2019

2018

Change

% Change

Retail Electric Revenues

$

88,345

$

87,835

$

510

0.6

Transmission Services Revenues

11,469

11,313

156

1.4

Wholesale Electric Revenues

941

2,539

(1,598

)

(62.9

)

Other Electric Revenues

1,489

2,038

(549

)

(26.9

)

Total Electric Revenues

$

102,244

$

103,725

$

(1,481

)

(1.4

)

Net Income

$

7,502

$

10,600

$

(3,098

)

(29.2

)

Retail Megawatt-hour Sales

1,088,052

1,136,326

(48,274

)

(4.2

)

Heating Degree Days

580

675

(95

)

(14.1

)

Cooling Degree Days

104

228

(124

)

(54.4

)

The following table shows heating and cooling degree days as a percent of normal.

Three Months ended June 30,

2019

2018

Heating Degree Days

112.6

%

133.7

%

Cooling Degree Days

95.4

%

221.4

%

The following table summarizes the estimated effect on diluted earnings per share of the difference in retail kilowatt-hour (kwh) sales under actual weather conditions and expected retail kwh sales under normal weather conditions in the second quarters of 2019 and 2018 and between quarters.

2019 vs Normal

2018 vs Normal

2019 vs 2018

Effect on Diluted Earnings Per Share

$0.01

$0.04

$(0.03)

The $0.5 million increase in retail electric revenues includes:

  • A $1.1 million increase in Minnesota retail revenue due to lower provisions for Tax Cuts and Jobs Act (TCJA) refunds. The effect of lower tax expense recovery requirements was rolled into Minnesota base rates beginning in June 2019.

  • A $1.0 million increase in transmission cost recovery revenues, in large part due to the recovery of investment and operating costs of the Big Stone South-Ellendale 345-kilovolt transmission line energized on February 6, 2019.

  • A $0.7 million increase in South Dakota revenues related to an interim rate increase that went into effect on October 18, 2018.

  • A $0.7 million increase in Minnesota Renewable Rider revenues due to increased cost recovery requirements resulting from the expiration of federal Production Tax Credits (PTCs) in November 2018 on a company-owned wind farm.

  • A $0.3 million increase in Minnesota Conservation Improvement Program (MNCIP) cost recovery revenues due to an increase in MNCIP recoverable expenditures in the second quarter of 2019.

  • A $0.2 million increase in accrued revenue related to the establishment of a generation cost recovery rider in North Dakota (the NDGCR rider) to provide for a return on funds invested in building Astoria Station during its construction phase. The NDGCR rider will be included in North Dakota customer billings beginning in July 2019.

partially offset by:

  • A $1.9 million decrease in retail revenues related to decreased consumption due to milder weather in the second quarter of 2019 compared to warmer than normal weather in May and June of 2018 reflected in a 54.4% decrease in cooling degree days between quarters, and colder weather in April 2018 reflected in a 14.1% decrease in heating degree days between quarters.

  • A $0.8 million reduction in retail revenue due to decreased kwh sales, primarily to commercial and industrial customers, exclusive of the weather-related decrease in retail kwh sales.

  • A $0.7 million decrease in retail revenue related to the recovery of decreased fuel and purchased power costs mainly related to 4.2% decrease in retail kwh sales.

Wholesale electric revenues decreased $1.6 million due to fewer opportunities for wholesale sales as Otter Tail Power Company’s Coyote Station was offline during the entire second quarter of 2019 due to an extended maintenance outage. Also, wholesale demand was down due to a milder spring in 2019, which also resulted in lower wholesale electricity prices.

Production fuel costs decreased $7.6 million mainly as a result of a 47.1% decrease in kwhs generated from our fuel‑burning plants due to the maintenance outage at Coyote Station and a 43.3% reduction in generation at Hoot Lake Plant due to maintenance issues and reduced opportunities for economic dispatch resulting from lower wholesale demand and lower wholesale energy prices due to milder spring weather in 2019.

The cost of purchased power to serve retail customers increased $5.2 million (36.3%) due to a 66.4% increase in kwhs purchased as a result of needing to purchase replacement power during Coyote Station’s maintenance outage and reduced availability of Hoot Lake Plant due to maintenance issues. The increased costs due to the increase in kwhs purchased was partially mitigated by an 18.1% decrease in the cost per kwh purchased resulting from lower wholesale energy prices due to the market factors addressed above.

Electric operating and maintenance expense increased $2.1 million including:

  • A $2.6 million increase in external maintenance costs and material and operating supply expenses in connection with the maintenance outage at Coyote Station over the entire second quarter of 2019.

  • A $0.6 million increase in transmission services expenses mainly related to cost reductions and billing adjustments recorded in 2018.

  • A $0.3 million increase in external maintenance costs and material and operating supply expenses at Hoot Lake Plant in connection with an unplanned outage in the second quarter of 2019 for turbine repairs.

partially offset by:

  • A $0.9 million decrease in storm damage repair expenses, including tree trimming and removal costs, due to a large storm in 2018 that impacted Otter Tail Power Company’s service area.

  • A $0.5 million decrease in expenses related to additional software licensing costs incurred in the second quarter of 2018.

Property tax expense increased $0.6 million due to capital additions, mainly transmission assets, in South Dakota and Minnesota.

Depreciation and amortization expense increased $1.1 million mainly due to 2018 capital additions of transmission plant and the new customer information system put in service in 2019.

Income tax expense in the Electric segment increased $0.4 million despite a $2.7 million decrease in income before income taxes mostly due to a $0.9 million decrease in federal PTCs resulting from the expiration of PTCs on Otter Tail Power Company’s Ashtabula wind farm in November 2018.

Manufacturing

Three Months ended June 30,

(in thousands)

2019

2018

Change

% Change

Operating Revenues

$

73,496

$

68,154

$

5,342

7.8

Net Income

3,990

3,583

407

11.4

BTD’s revenue increase of $3.9 million included growth in parts revenue of $4.5 million driven by increased sales in construction, recreational vehicle and agricultural end markets, partially offset by decreased sales in energy end markets. Included in the parts revenue increase is the pass-through of higher material costs of $4.2 million, with the remaining increase due to higher sales volume. Revenues from scrap metal sales were down $0.6 million (29%) quarter over quarter due to a 28% decrease in scrap metal prices on a less than 1% decrease in scrap volume. An increase in cost of products sold at BTD of $3.2 million resulted from both the $4.2 million in higher material costs passed through to customers and increased sales volume, partially offset by a $1.4 million increase in recovery of tooling costs from customers.

The $0.7 million increase in gross margins on sales was partially offset by a $0.4 million increase in operating expenses resulting mainly from increases in labor-related costs due to additional employees. Depreciation and amortization expense at BTD decreased $0.3 million as a result of certain assets reaching the ends of their depreciable lives. BTD’s income before tax increased $0.5 million resulting in increases in income tax expense and net income of $0.1 million and $0.4 million, respectively.

At T.O. Plastics, revenues increased $1.4 million primarily due to a $1.8 million increase in sales of horticultural containers, partially offset by a $0.4 million decrease in industrial sales. The increase in horticultural sales volume is due to an early order program offered to customers during the second quarter, a catch up on shipments that were delayed due to inclement weather in the first quarter of 2019 and growth of plug tray sales to certain horticultural markets. Industrial sales were down due to a customer bringing more production in house.

The revenue increase at T.O. Plastics was mostly offset by a $1.3 million increase in cost of products sold related to the increase in sales volume. Operating expenses increased by $0.1 million due to an increase in sales and marketing costs. T.O. Plastics’ net income was essentially unchanged quarter over quarter.

Plastics

Three Months ended June 30,

(in thousands)

2019

2018

Change

% Change

Operating Revenues

$

53,476

$

54,476

$

(1,000

)

(1.8

)

Net Income

5,792

6,229

(437

)

(7.0

)

Plastics segment revenues and net income decreased $1.0 million and $0.4 million, respectively, due to a 3.6% decrease in polyvinyl chloride (PVC) pipe prices partially offset by a 1.9% increase in pounds of pipe sold. The quarter-over-quarter sales volume increase was due to stronger demand for product in southcentral and southwestern regions of the United States, offset by lower volume sales to certain customers in the northern region of our sales territory. Cost of products sold decreased $0.1 million despite the increase in sales volume due to a 2.0% decrease in the cost per pound of pipe sold. The decrease in pipe prices in excess of the decrease in costs per pound of pipe sold resulted in a 9.0% decrease in gross margin per pound of PVC pipe sold. Plastics segment operating and depreciation expenses decreased $0.4 million between the quarters mainly due to lower incentive compensation resulting from a decrease in operating income in the first half of 2019.

Corporate

Three Months ended June 30,

(in thousands)

2019

2018

Change

% Change

Losses before Income Taxes

$

2,745

$

2,498

$

247

9.9

Income Tax Savings

(887

)

(782

)

(105

)

13.4

Net Loss

$

1,858

$

1,716

$

142

8.3

Corporate pre-tax costs and net-of-tax losses increased mainly due to an increase in certain employee benefit costs.

2019 Business Outlook
We anticipate 2019 diluted earnings per share to be in the range of $2.10 to $2.25. We have taken into consideration strategies for improving future operating results, the cyclical nature of some of our businesses and current regulatory factors facing our Electric segment. We expect capital expenditures for 2019 to be $233 million compared with actual cash used for capital expenditures of $105 million in 2018. Our planned expenditures for 2019 include $79 million for the Merricourt Wind Energy Center and $46 million for Astoria Station.

Segment components of our 2019 earnings per share guidance range compared with 2018 actual earnings are as follows.

Diluted Earnings Per Share

2018 EPS
by
Segment

2019 Guidance
February 18, 2019

2019 Guidance
May 6, 2019

2019 Guidance
August 5, 2019

Low

High

Low

High

Low

High

Electric

$1.36

$1.46

$1.49

$1.48

$1.51

$1.48

$1.51

Manufacturing

$0.32

$0.37

$0.41

$0.35

$0.39

$0.33

$0.37

Plastics

$0.60

$0.44

$0.48

$0.44

$0.48

$0.46

$0.50

Corporate

($0.22)

($0.17)

($0.13)

($0.17)

($0.13)

($0.17)

($0.13)

Total

$2.06

$2.10

$2.25

$2.10

$2.25

$2.10

$2.25

Return on Equity

11.5%

11.5%

12.3%

11.5%

12.3%

11.5%

12.3%

The following items contribute to our earnings guidance for 2019.

• We expect 2019 Electric segment net income to be higher than 2018 segment net income based on:

  • The business outlook assumes an annual net revenue increase of approximately $2.6 million from the full approval of our South Dakota rate case settlement on May 14, 2019. The settlement also allowed us to retain the impact of lower tax rates related to the TCJA from January 1, 2018 through October 17, 2018. This outcome favorably impacts 2019 earnings by approximately $0.02 per share.

  • Increases in allowance for funds used during construction (AFUDC) for planned capital projects, including the Merricourt Wind Energy Center, and increases in AFUDC and North Dakota Generation Cost Recovery Rider revenue related to Astoria Station, with both projects beginning construction in 2019.

  • Increased revenues from completion of the Big Stone South–Ellendale project and additional transmission investments related to our South Dakota Transmission Reliability project.

  • Decreased operating and maintenance expenses due to decreasing costs of pension, medical, workers compensation and retiree medical benefits. The decrease in pension costs is a result of an increase in the discount rate from 3.90% to 4.50%.

  • Expenses incurred in the last half of 2018 that are not expected during the last half of 2019 consisting of $3.2 million related to the Big Stone Plant outage and the contribution to the Otter Tail Power Company Foundation of $500,000.

partially offset by:

  • Higher depreciation and property tax expense due to large capital projects being put into service.

  • The extension of the planned outage at Coyote Station due to turbine rotor blade damage that was discovered in the early stages of the outage, and the unplanned maintenance outage at Hoot Lake Plant, which both occurred in the second quarter of 2019.

• We expect 2019 net income from our Manufacturing segment to increase over 2018. The overall increase in segment earnings in 2019 is based on:

  • Increased sales at BTD driven by growth in the recreational vehicle, lawn and garden and agricultural end markets. Most of this growth is organic with our existing customer base. However, we are lowering both ends of the guidance range due to expected softness in scrap metal revenues based on lower scrap metal prices in the second quarter which we expect will remain low for the rest of the year, partially offset by higher scrap volumes.

  • A decrease in earnings from T.O. Plastics mainly due to first quarter volume softness and the expected impact on business operations of the partial collapse and replacement of a warehouse roof, which was damaged in March of 2019 during a winter storm.

  • Backlog for the manufacturing companies of approximately $115 million for 2019 compared with $107 million one year ago.

• We expect 2019 net income from the Plastics segment to be lower than 2018 based on lower expected operating margins in 2019. This is due to lower sales volumes in 2019 compared to 2018, slightly lower sales prices and higher resin prices, which have recently moderated. The increase in the guidance is driven by the expectation that resin prices will not increase as much as originally thought based on current market dynamics.

• Corporate costs, net of tax, are expected to be lower in 2019 than in 2018. In 2018, we incurred expenses of $2 million for a contribution to the Otter Tail Corporation Foundation and $1.2 million for accruals related to certain tax matters. These expenses are not expected to occur during the remainder of 2019.

Our consolidated capital expenditure plan for the 2019-2023 time period has been revised from $1.07 billion to $1.11 billion. The increase is primarily driven by the need for additional wind and technology-related investments and transmission investments. Given the increased capital expenditure plan, our compounded annual growth rate in rate base is projected to be 8.6% over the 2018 to 2023 timeframe.

(in millions)

2018

2019

2020

2021

2022

2023

Total

Capital Expenditures:

Electric Segment:

Renewables and Natural Gas Generation

$

125

$

264

$

15

$

82

$

0

$

486

Transformative Technology and Infrastructure

2

7

18

47

54

128

Transmission (includes replacements)

43

42

21

19

17

142

Other

43

45

58

49

55

250

Total Electric Segment

$

87

$

213

$

358

$

112

$

197

$

126

$

1,006

Manufacturing and Plastics Segments

18

20

18

19

23

19

99

Total Capital Expenditures

$

105

$

233

$

376

$

131

$

220

$

145

$

1,105

Total Electric Utility Rate Base

$

1,100

$

1,176

$

1,394

$

1,531

$

1,581

$

1,665

Execution on the currently anticipated electric utility capital expenditure plan is expected to grow rate base and be a key driver in increasing utility earnings over the 2019 through 2023 timeframe.

CONFERENCE CALL AND WEBCAST
The corporation will host a live webcast on Tuesday, August 6, 2019, at 10:00 a.m. CDT to discuss its financial and operating performance.

The presentation will be posted on our website before the webcast. To access the live webcast, go to www.ottertail.com/presentations.cfm and select “Webcast.” Please allow time prior to the call to visit the site and download any software needed to listen in. An archived copy of the webcast will be available on our website shortly after the call.

If you are interested in asking a question during the live webcast, call 877-312-8789. For listen-only mode, call 866-634-1342.

Risk Factors and Forward-Looking Statements that Could Affect Future Results
The information in this release includes certain forward-looking information, including 2019 expectations, made under the Safe Harbor provisions of the Private Securities Litigation Reform Act of 1995. Although we believe our expectations are based on reasonable assumptions, actual results may differ materially from those expectations. The following factors, among others, could cause our actual results to differ materially from those discussed in the forward-looking statements:

  • Federal and state environmental regulation could require us to incur substantial capital expenditures and increased operating costs.

  • Volatile financial markets and changes in our debt ratings could restrict our ability to access capital and increase borrowing costs and pension plan and postretirement health care expenses.

  • Any significant impairment of our goodwill would cause a decrease in our asset values and a reduction in our net operating income.

  • The inability of our subsidiaries to provide sufficient earnings and cash flows to allow us to meet our financial obligations and debt covenants and pay dividends to our shareholders could have an adverse effect on us.

  • We rely on our information systems to conduct our business, and failure to protect these systems against security breaches or cyber-attacks could adversely affect our business and results of operations. Additionally, if these systems fail or become unavailable for any significant period, our business could be harmed.

  • Economic conditions could negatively impact our businesses.

  • If we are unable to achieve the organic growth we expect, our financial performance may be adversely affected.

  • Our plans to grow our businesses through capital projects, including infrastructure and new technology additions, or to grow or realign our businesses through acquisitions or dispositions may not be successful, which could result in poor financial performance.

  • We may, from time to time, sell assets to provide capital to fund investments in our electric utility business or for other corporate purposes, which could result in the recognition of a loss on the sale of any assets sold and other potential liabilities. The sale of any of our businesses could expose us to additional risks associated with indemnification obligations under the applicable sales agreements and any related disputes.

  • Significant warranty claims and remediation costs in excess of amounts normally reserved for such items could adversely affect our results of operations and financial condition.

  • We are subject to risks associated with energy markets.

  • Changes in tax laws, as well as judgments and estimates used in the determination of tax-related asset and liability amounts, could materially adversely affect our business, financial condition, results of operations and prospects.

  • Four of our operating companies have single customers that provide a significant portion of the individual operating company’s and the business segment’s revenue. The loss of, or significant reduction in revenue from, any one of these customers would have a significant negative financial impact on the operating company and its business segment and could have a significant negative financial impact on us.

  • We may experience fluctuations in revenues and expenses related to our electric operations, which may cause our financial results to fluctuate and could impair our ability to make distributions to shareholders or scheduled payments on our debt obligations, or to meet covenants under our borrowing agreements.

  • Actions by the regulators of our electric operations could result in rate reductions, lower revenues and earnings or delays in recovering capital expenditures.

  • Our electric operations are subject to an extensive legal and regulatory framework under federal and state laws as well as regulations imposed by other organizations that may have a negative impact on our business and results of operations.

  • Our electric transmission and generation facilities could be vulnerable to cyber and physical attack that could impair our ability to provide electrical service to our customers or disrupt the U.S. bulk power system.

  • Our electric generating facilities are subject to operational risks that could result in unscheduled plant outages, unanticipated operation and maintenance expenses and increased power purchase costs.

  • Changes to regulation of generating plant emissions, including but not limited to carbon dioxide emissions and regional haze regulation under state implementation plans, could affect our operating costs and the costs of supplying electricity to our customers and the economic viability of continued operation of certain of our steam-powered electric plants.

  • Competition from foreign and domestic manufacturers, the price and availability of raw materials, trade policy and tariffs affecting prices and markets for raw material and manufactured products, prices and supply of scrap or recyclable material and general economic conditions could affect the revenues and earnings of our manufacturing businesses.

  • Our plastics operations are highly dependent on a limited number of vendors for PVC resin and a limited supply of PVC resin. The loss of a key vendor, or any interruption or delay in the supply of PVC resin, could result in reduced sales or increased costs for our plastics business.

  • We compete against many other manufacturers of PVC pipe and manufacturers of alternative products. Customers may not distinguish the pipe companies’ products from those of our competitors.

  • Changes in PVC resin prices can negatively affect our plastics business.

For a further discussion of these risk factors and cautionary statements, refer to reports we file with the Securities and Exchange Commission.

About the Corporation: Otter Tail Corporation has interests in diversified operations that include an electric utility and manufacturing businesses. Otter Tail Corporation stock trades on the Nasdaq Global Select Market under the symbol OTTR. The latest investor and corporate information are available at www.ottertail.com. Corporate offices are in Fergus Falls, Minnesota, and Fargo, North Dakota.

See Otter Tail Corporation’s results of operations for the three- and six-month periods ended June 30, 2019 and 2018 in the following financial statements: Consolidated Statements of Income, Consolidated Balance Sheets – Assets, Consolidated Balance Sheets – Liabilities and Equity, and Consolidated Statements of Cash Flows.


Otter Tail Corporation

Consolidated Statements of Income

In thousands, except share and per share amounts

(not audited)

Quarter Ended June 30,

Year-to-Date June 30,

2019

2018

2019

2018

Operating Revenues by Segment

Electric

Revenues from Contracts with Customers

$

101,875

$

105,290

$

231,033

$

229,130

Changes in Accrued Revenues under Alternative Revenue Programs

369

(1,565

)

(680

)

(2,440

)

Total Electric Revenues

102,244

103,725

230,353

226,690

Manufacturing

73,496

68,154

151,318

136,816

Plastics

53,476

54,476

93,534

104,129

Intersegment Eliminations

(13

)

(7

)

(30

)

(21

)

Total Operating Revenues

229,203

226,348

475,175

467,614

Operating Expenses

Fuel and Purchased Power

27,929

30,290

68,801

70,589

Nonelectric Cost of Products Sold (depreciation included below)

97,996

93,545

188,578

182,330

Electric Operating and Maintenance Expense

39,856

37,741

78,238

77,216

Nonelectric Operating and Maintenance Expense

13,262

12,649

26,739

25,143

Depreciation and Amortization

19,441

18,745

38,572

37,508

Property Taxes — Electric

3,900

3,273

7,859

7,108

Total Operating Expenses

202,384

196,243

408,787

399,894

Operating Income (Loss) by Segment

Electric

15,477

18,442

45,888

43,876

Manufacturing

5,759

5,111

12,580

11,005

Plastics

8,031

8,557

13,173

17,896

Corporate

(2,448

)

(2,005

)

(5,253

)

(5,057

)

Total Operating Income

26,819

30,105

66,388

67,720

Interest Charges

7,825

7,676

15,651

15,048

Nonservice Cost Components of Postretirement Benefits

1,075

1,386

2,110

2,803

Other Income

850

707

2,094

1,890

Income Tax Expense

3,343

3,054

8,971

6,848

Net Income (Loss) by Segment

Electric

7,502

10,600

26,202

27,268

Manufacturing

3,990

3,583

8,832

7,747

Plastics

5,792

6,229

9,521

13,073

Corporate

(1,858

)

(1,716

)

(2,805

)

(3,177

)

Net Income

$

15,426

$

18,696

$

41,750

$

44,911

Average Number of Common Shares Outstanding

Basic

39,712,036

39,605,717

39,684,679

39,578,296

Diluted

39,917,831

39,879,069

39,910,499

39,871,376

Basic Earnings Per Common Share

$

0.39

$

0.47

$

1.05

$

1.13

Diluted Earnings Per Common Share

$

0.39

$

0.47

$

1.05

$

1.13


Otter Tail Corporation

Consolidated Balance Sheets

ASSETS

in thousands

(not audited)

June 30,

December 31,

2019

2018

Current Assets

Cash and Cash Equivalents

$

982

$

861

Accounts Receivable:

Trade—Net

105,407

75,144

Other

9,956

9,741

Inventories

105,860

106,270

Unbilled Receivables

18,349

23,626

Income Taxes Receivable

--

2,439

Regulatory Assets

14,501

17,225

Other

8,511

6,114

Total Current Assets

263,566

241,420

Investments

9,683

8,961

Other Assets

39,002

35,759

Goodwill

37,572

37,572

Other Intangibles—Net

11,858

12,450

Regulatory Assets

131,692

135,257

Right of Use Assets – Operating Leases

19,473

--

Plant

Electric Plant in Service

2,170,259

2,019,721

Nonelectric Operations

234,245

228,120

Construction Work in Progress

73,069

181,626

Total Gross Plant

2,477,573

2,429,467

Less Accumulated Depreciation and Amortization

875,475

848,369

Net Plant

1,602,098

1,581,098

Total

$

2,114,944

$

2,052,517


Otter Tail Corporation

Consolidated Balance Sheets

LIABILITIES AND EQUITY

in thousands

(not audited)

June 30,

December 31,

2019

2018

Current Liabilities

Short-Term Debt

$

36,602

$

18,599

Current Maturities of Long-Term Debt

177

172

Accounts Payable

111,848

96,291

Accrued Salaries and Wages

18,034

24,857

Accrued Federal and State Income Taxes

3,732

--

Other Accrued Taxes

11,753

17,287

Regulatory Liabilities

8,959

738

Current Operating Lease Liabilities

3,784

--

Other Accrued Liabilities

11,260

12,149

Total Current Liabilities

206,149

170,093

Pensions Benefit Liability

88,030

98,358

Other Postretirement Benefits Liability

73,080

71,561

Long-Term Operating Lease Liabilities

16,084

--

Other Noncurrent Liabilities

28,859

24,326

Deferred Credits

Deferred Income Taxes

122,035

120,976

Deferred Tax Credits

19,300

19,974

Regulatory Liabilities

224,655

226,469

Other

2,384

1,895

Total Deferred Credits

368,374

369,314

Capitalization

Long-Term Debt—Net

590,063

590,002

Cumulative Preferred Shares

--

--

Cumulative Preference Shares

--

--

Common Equity

Common Shares, Par Value $5 Per Share

198,775

198,324

Premium on Common Shares

345,030

344,250

Retained Earnings

205,115

190,433

Accumulated Other Comprehensive Loss

(4,615

)

(4,144

)

Total Common Equity

744,305

728,863

Total Capitalization

1,334,368

1,318,865

Total

$

2,114,944

$

2,052,517




Otter Tail Corporation

Consolidated Statements of Cash Flows

In thousands

(not audited)

For the Six Months Ended June 30,

In thousands

2019

2018

Cash Flows from Operating Activities

Net Income

$

41,750

$

44,911

Adjustments to Reconcile Net Income to Net Cash Provided by Operating Activities:

Depreciation and Amortization

38,572

37,508

Deferred Tax Credits

(674

)

(703

)

Deferred Income Taxes

960

2,076

Change in Deferred Debits and Other Assets

3,884

10,309

Discretionary Contribution to Pension Plan

(10,000

)

(20,000

)

Change in Noncurrent Liabilities and Deferred Credits

11,942

(759

)

Allowance for Equity/Other Funds Used During Construction

(688

)

(1,060

)

Stock Compensation Expense – Equity Awards

3,944

2,253

Other—Net

276

(193

)

Cash (Used for) Provided by Current Assets and Current Liabilities:

Change in Receivables

(30,478

)

(25,677

)

Change in Inventories

410

(2,401

)

Change in Other Current Assets

2,870

2,428

Change in Payables and Other Current Liabilities

222

1,233

Change in Interest and Income Taxes Receivable/Payable

6,297

3,470

Net Cash Provided by Operating Activities

69,287

53,395

Cash Flows from Investing Activities

Capital Expenditures

(54,012

)

(49,094

)

Proceeds from Disposal of Noncurrent Assets

3,405

1,477

Cash Used for Investments and Other Assets

(4,776

)

(2,102

)

Net Cash Used in Investing Activities

(55,383

)

(49,719

)

Cash Flows from Financing Activities

Changes in Checks Written in Excess of Cash

(1,120

)

2,236

Net Short-Term Borrowings (Repayments)

18,003

(91,394

)

Common Stock Issuance Expenses

--

(108

)

Payments for Retirement of Capital Stock

(2,730

)

(2,450

)

Proceeds from Issuance of Long-Term Debt

--

100,000

Short-Term and Long-Term Debt Issuance Expenses

--

(441

)

Payments for Retirement of Long-Term Debt

(84

)

(107

)

Dividends Paid

(27,852

)

(26,592

)

Net Cash Used in Financing Activities

(13,783

)

(18,856

)

Net Change in Cash and Cash Equivalents

121

(15,180

)

Cash and Cash Equivalents at Beginning of Period

861

16,216

Cash and Cash Equivalents at End of Period

$

982

$

1,036

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