Minnesota | 0-53713 | 27-0383995 |
(State or other jurisdiction | (Commission | (I.R.S. Employer |
of incorporation) | File Number) | Identification No.) |
215 South Cascade Street, P.O. Box 496, Fergus Falls, MN | 56538-0496 |
(Address of principal executive offices) | (Zip Code) |
o
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Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)
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o
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Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)
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o
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Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))
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o
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Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))
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Item 1.01. | Entry into a Material Definitive Agreement. |
2 |
Item 2.02 | Results of Operations and Financial Condition |
3 |
Item 9.01 | Financial Statements and Exhibits | |
(d) | Exhibits | |
4.1
|
Second Amendment to Third Amended and Restated Credit Agreement, dated as of November 3, 2014, among Otter Tail Corporation, U.S. Bank National Association, as Administrative Agent and as a Bank, Bank of America, N.A. and JPMorgan Chase Bank, N.A., each as a Co-Syndication Agent and as a Bank, KeyBank National Association, as Documentation Agent and as a Bank, and Bank of the West as a Bank.
|
|
4.2
|
Second Amendment to Second Amended and Restated Credit Agreement, dated as of November 3, 2014, among Otter Tail Power Company, U.S. Bank National Association, as Administrative Agent and as a Bank, Bank of America, N.A. and JPMorgan Chase Bank, N.A., each as a Co-Syndication Agent and as a Bank, KeyBank National Association, as Documentation Agent and as a Bank, CoBank, ACB, as a Co-Documentation Agent and as a Bank, and Wells Fargo Bank, National Association as a Bank.
|
|
99.1
|
Press Release issued November 3, 2014.
|
OTTER TAIL CORPORATION | |||
Date: November 4, 2014 | |||
By | /s/ Kevin G. Moug | ||
Kevin G. Moug
|
|||
Chief Financial Officer |
4 |
Exhibit | Description of Exhibit | ||
4.1
|
Second Amendment to Third Amended and Restated Credit Agreement, dated as of November 3, 2014, among Otter Tail Corporation, U.S. Bank National Association, as Administrative Agent and as a Bank, Bank of America, N.A. and JPMorgan Chase Bank, N.A., each as a Co-Syndication Agent and as a Bank, KeyBank National Association, as Documentation Agent and as a Bank, and Bank of the West as a Bank.
|
||
4.2
|
Second Amendment to Second Amended and Restated Credit Agreement, dated as of November 3, 2014, among Otter Tail Power Company, U.S. Bank National Association, as Administrative Agent and as a Bank, Bank of America, N.A. and JPMorgan Chase Bank, N.A., each as a Co-Syndication Agent and as a Bank, KeyBank National Association, as Documentation Agent and as a Bank, CoBank, ACB, as a Co-Documentation Agent and as a Bank, and Wells Fargo Bank, National Association as a Bank.
|
||
99.1 | Press release, dated November 3, 2014 |
(n) (i) Liens securing Indebtedness incurred to pay annual premiums for property, casualty or liability insurance policies maintained by the Borrower or any Subsidiary; provided that such Liens attach only to insurance policies and proceeds thereof, and (ii) pledges and deposits and other Liens securing liability for reimbursement or indemnification obligations of (including obligations in respect of letters of credit or bank guarantees for the benefit of) insurance carriers providing property, casualty or liability insurance to the Borrower or any Subsidiary; |
2 |
3 |
U.S. BANK NATIONAL ASSOCIATION, | ||||
as Agent and a Bank
|
||||
By: | /s/ Jacquelyn Ness | |||
Title: | Vice President | |||
505 Second Avenue North | ||||
Mail Code EP-ND-0630 | ||||
Fargo, ND 58102 | ||||
Attention: Jacquelyn Ness, Vice President | ||||
Telephone: (701) 280-3655 | ||||
Fax: (701) 280-3580 |
JPMORGAN CHASE BANK, N.A., as Co-
Syndication Agent and as a Bank |
||||
By: | /s/ Justin Martin | |||
Title: | Authorized Officer | |||
10 South Dearborn, 9 th Floor, IL1-0090 | ||||
Chicago, IL 60603 | ||||
Attention: Justin Martin | ||||
Telephone: (312) 732-4441 | ||||
Fax: (312) 732-1762 |
KEYBANK NATIONAL ASSOCIATION, as
Documentation Agent and as a Bank |
||||
By: | /s/ Keven D. Smith | |||
Title: | Senior Vice President | |||
1301 5
th
Avenue
Mail Code: WA-31-13-2514
Seattle, WA 98101
|
||||
Attention: | Keven D. Smith | |||
Telephone: | (206) 343-6966 | |||
Fax: (206) 684-6570 |
BANK OF THE WEST, a California Banking
Corporation, as a Bank |
||||
By: | /s/ David Wang | |||
Title: | Director | |||
250 Marquette Ave., Suite 575
Minneapolis, MN 55401
Attention: David Wang
Telephone: (612) 339-1403
Fax: (612) 339-6362
|
The undersigned Departing Lender hereby acknowledges and agrees that, as of the date of this Second Amendment, it is no longer a party to the Credit Agreement, it is not a party to this Amendment (other than for purposes of acknowledging its status as a Departing Lender), and confirms that, as a Departing Lender, its approval is not required to give effect to this Amendment. | |||
UNION BANK, N.A., as a Departing Lender (and solely with respect to Section 4.6 of this Amendment) | |||
By: | /s/ Harvey Hordwitz | ||
Name: Harvey Hordwitz | |||
Title: Vice President |
Bank
:
|
Initial Commitment:
|
Percentage:
|
||||
U.S. Bank National Association
|
$ 45,000,000
|
30.000000000000%
|
||||
Bank of America, N.A.
|
$ 30,000,000
|
20.000000000000%
|
||||
JPMorgan Chase Bank, N.A.
|
$ 30,000,000
|
20.000000000000%
|
||||
Keybank National Association
|
$27,500,000
|
18.333333333333%
|
||||
Bank of the West, a California Banking Corporation
|
$17,500,000
|
11.666666666667%
|
||||
Total:
|
$150,000,000
|
100.000000000%
|
2 |
3 |
U.S. BANK NATIONAL ASSOCIATION, | ||||
as Agent and a Bank
|
||||
By: | /s/ Jacquelyn Ness | |||
Title: | Vice President | |||
505 Second Avenue North | ||||
Mail Code EP-ND-0630 | ||||
Fargo, ND 58102 | ||||
Attention: Jacquelyn Ness, Vice President | ||||
Telephone: (701) 280-3655 | ||||
Fax: (701) 280-3580 |
JPMORGAN CHASE BANK, N.A., as a Co-
Syndication Agent and as a Bank |
||||
By: | /s/ Justin Martin | |||
Title: | Authorized Officer | |||
10 South Dearborn, 9th Floor, IL1-0090
Chicago, IL 60603
Attention: Justin Martin
Telephone: (312) 732-4441
Fax: (312) 732-1762
|
KEYBANK NATIONAL ASSOCIATION, as
Documentation Agent and as a Bank |
||||
By: | /s/ Keven D. Smith | |||
Title: | Senior Vice President | |||
1301 5
th
Avenue
Mail Code: WA-31-13-2514
Seattle, WA 98101
|
||||
Attention: | Keven D. Smith | |||
Telephone: | (206) 343-6966 | |||
Fax: (206) 684-6570 |
WELLS FARGO BANK, NATIONAL
ASSOCIATION, as a Bank
|
||||
By: | /s/ Nick Brokke | |||
Title: | Vice President | |||
90 S 7
th
Street, 7
th
Floor
MAC: N9305-070
Minneapolis, MN 55408
|
||||
Attention: | Nick Brokke | |||
Vice President | ||||
Tel: 612-667-6637 | ||||
Fax: 612-316-0506 |
COBANK, ACB, as a Co-Documentation Agent
and as a Bank |
||||
By: | /s/ John Kemper | |||
Title: | Vice President | |||
5500 South Quebec St.
Greenwood Village, CO 80111
Attention: John Kemper
Telephone: 303-740-6576
Fax: 303-224-2615
|
The undersigned Departing Lender hereby acknowledges and agrees that, as of the date of this Second Amendment, it is no longer a party to the Credit Agreement, it is not a party to this Amendment (other than for purposes of acknowledging its status as a Departing Lender), and confirms that, as a Departing Lender, its approval is not required to give effect to this Amendment. | |||
UNION BANK, N.A., as a Departing Lender (and solely with respect to Section 4.6 of this Amendment) | |||
By | /s/ Harvey Hordwitz | ||
Name: Harvey Hordwitz | |||
Title: Vice President |
Bank
:
|
Initial Commitment
:
|
Percentage
:
|
||||
U.S. Bank National Association
|
$52,500,000
|
30.882352941176%
|
||||
JPMorgan Chase Bank, N.A.
|
$32,500,000
|
19.117647058824%
|
||||
Bank of America, N.A.
|
$32,500,000
|
19.117647058824%
|
||||
Keybank, National Association
|
$17,500,000
|
10.294117647059%
|
||||
Wells Fargo Bank, National Association
|
$17,500,000
|
10.294117647059%
|
||||
CoBank, ACB
|
$17,500,000
|
10.294117647059%
|
||||
Total:
|
$170,000,000
|
100.000000000%
|
Exhibit 99.1 |
NEWS RELEASE
|
Media contact: | Cris Oehler, Vice President of Corporate Communications, (218) 531-0099 or (866) 410-8780 |
Investor contact: | Loren Hanson, Manager of Investor Relations, (218) 739-8481 or (800) 664-1259 |
For release: | November 3, 2014 | Financial Media |
|
●
|
Consolidated revenues were $242.4 million compared with $229.8 million for the third quarter of 2013.
|
|
●
|
Consolidated net income and diluted earnings from continuing operations totaled $15.7 million and $0.43 per share, respectively, compared with $14.8 million and $0.41 per share for the third quarter of 2013.
|
|
●
|
The corporation expects to be in the upper end of its 2014 consolidated earnings guidance of $1.65 to $1.80 per diluted share, based on its continued strong performance in 2014.
|
|
●
|
The corporation continues its portfolio review strategy and is considering strategic alternatives for its Construction segment.
|
1 |
(in thousands)
|
Line Limit |
In Use On
September 30, 2014 |
Restricted due to
Outstanding Letters of Credit |
Available on
September 30, 2014 |
||||||||||||||||||||
Otter Tail Corporation Credit Agreement
|
$ | 150,000 | $ | 39,000 | $ | 309 | $ | 110,691 | ||||||||||||||||
Otter Tail Power Company Credit Agreement
|
170,000 | -- | 730 | 169,270 | ||||||||||||||||||||
Total
|
$ | 320,000 | $ | 39,000 | $ | 1,039 | $ | 279,961 |
2 |
Three Months ended September 30,
|
|
2014
|
2013
|
76%
|
115%
|
|
●
|
a $3.6 million increase in Environmental Cost Recovery (ECR) rider revenues related to earning a return in Minnesota and North Dakota on increasing amounts invested in the air quality control system (AQCS) under construction at Big Stone Plant,
|
|
●
|
a $1.9 million increase in fuel clause adjustment revenues and fuel and purchased power costs recovered in base rates driven by increased power purchases to meet higher retail kwh sales demand,
|
|
●
|
a $1.6 million increase in revenue due to a 2.1% increase in retail kilowatt-hour (kwh) sales mainly related to increased sales to pipeline customers, and
|
|
●
|
a $1.3 million increase in Transmission Cost Recovery rider revenues related to recovering costs and returns earned on increasing investments in transmission plant,
|
|
●
|
an estimated $1.6 million decrease in revenues related to milder weather and fewer cooling degree days in the third quarter of 2014 compared with the third quarter of 2013,
|
|
●
|
a $0.4 million reduction in Big Stone II cost recovery rider revenues as the North Dakota share of abandoned plant costs were fully recovered by the end of March 2014, and
|
|
●
|
a $0.2 million decrease in renewable resource cost recovery rider revenues.
|
3 |
|
●
|
a $1.9 million increase in contracted maintenance costs at Hoot Lake Plant related to a scheduled spring maintenance shutdown which extended into August of 2014 due to unanticipated maintenance issues encountered during the shutdown,
|
|
●
|
a $0.6 million increase in MISO transmission tariff charges related to increasing investments in regional CapX2020 and MISO-designated MVP transmission projects, and
|
|
●
|
a $0.5 million increase in expenditures for vegetation control and utility pole maintenance,
|
|
●
|
a $0.3 million decrease in amortization of the North Dakota share of Big Stone II abandoned plant costs in conjunction with final recovery of those costs by the end of March 2014.
|
4 |
|
●
|
At BTD, revenues increased $7.6 million mainly as a result of increased sales to customers in recreational, lawn and garden and energy-related end markets. The following factors resulted in a $0.1 million decrease in BTD’s quarter over quarter net income. Cost of products sold increased $6.5 million as a result of increased sales volumes and material handling costs. BTD’s operating expenses increased $1.1 million, mainly as a result of increases in labor, benefits and training costs related to staffing additions, employee development and increased sales. Income tax expense at BTD increased $0.1 million.
|
|
●
|
At T.O. Plastics, revenues and costs of products sold both decreased $1.3 million mainly due to discontinuing a cost-intensive, low-margin product packing process performed for a customer prior to 2014. While the revenues have declined related to this, T.O. Plastics product mix improved, resulting in a higher gross margin percentage and no change in gross profit compared with last year’s third quarter. A $0.2 million increase in administrative and general expenses was offset by decreases in depreciation and income tax expenses, resulting in no change in T.O. Plastics’ net income between the quarters.
|
|
●
|
Aevenia’s revenues increased $2.3 million and its net income increased $0.2 million. Aevenia’s revenue increase is due to a significant increase in electric transmission and distribution work in western North Dakota. Aevenia’s costs of revenues earned increased by $1.1 million as a result of the increase in construction activity, and its operating expenses increased by $0.9 million between the quarters, mainly due to an increase in incentive compensation related to Aevenia’s improved operating results.
|
|
●
|
At Foley, a revenue decrease of $4.0 million due to lower work volume was more than offset by higher profit margins on jobs in progress, resulting in a $0.2 million increase in net income between the quarters. Foley’s improved results are reflective of more selective bidding on projects and improved cost control processes in construction management.
|
5 |
|
●
|
a $0.6 million net-of-tax decrease in general and administrative costs related to an increase in Corporate costs allocated to our operating companies,
|
|
●
|
a $0.5 million net-of-tax reduction in accrued stock performance incentive expenses related to a decline in the corporation’s total shareholder return (TSR) ranking relative to the TSR rankings of its peers in the Edison Electric Institute in the third quarter of 2014, and
|
|
●
|
a $0.6 million net-of-tax decrease in interest expense related to the early retirement, in November 2013, of $47.7 million of the corporation’s outstanding 9.0% notes due December 15, 2016,
|
|
●
|
$0.6 million of decreases in miscellaneous other income and in tax savings related to permanent differences.
|
2013 | February 2014 | August 2014 |
Current 2014
|
||||
EPS by
|
EPS Guidance | EPS Guidance | EPS Guidance | ||||
Segment |
Low
|
High
|
Low
|
High
|
Low
|
High
|
|
Electric
|
$1.05
|
$1.19
|
$1.23
|
$1.23
|
$1.26
|
$1.19
|
$1.22
|
Manufacturing
|
$0.32
|
$0.29
|
$0.33
|
$0.30
|
$0.33
|
$0.26
|
$0.29
|
Plastics
|
$0.38
|
$0.25
|
$0.29
|
$0.26
|
$0.29
|
$0.31
|
$0.34
|
Construction
|
$0.04
|
$0.07
|
$0.11
|
$0.10
|
$0.13
|
$0.11
|
$0.14
|
Corporate
|
($0.25)
|
($0.25)
|
($0.21)
|
($0.24)
|
($0.21)
|
($0.22)
|
($0.19)
|
Subtotal – Continuing Operations
|
$1.54
|
$1.55
|
$1.75
|
$1.65
|
$1.80
|
$1.65
|
$1.80
|
Corporate – Loss on Debt Extinguishment
|
($0.17)
|
||||||
Total – Continuing Operations
|
$1.37
|
$1.55
|
$1.75
|
$1.65
|
$1.80
|
$1.65
|
$1.80
|
6 |
|
●
|
The corporation is reducing its 2014 net income expectations for its Electric segment back to within its original guidance range for the year due to the extended outage of Hoot Lake Plant and milder than normal third quarter weather, which have offset higher than expected earnings in the first quarter that were driven, in part, by colder than normal weather. Items affecting the corporation’s 2014 Electric segment earnings guidance compared with 2013 earnings also include:
|
|
o
|
Rider recovery increases, including environmental riders in Minnesota and North Dakota related to the Big Stone Plant AQCS environmental upgrades while under construction, and
|
|
o
|
A decrease in pension costs of approximately $2.0 million as a result of an increase in the discount rate from 4.5% to 5.3%, offset by
|
|
o
|
An increase in interest costs as a result of $150 million of fixed rate long term debt put in place in the first quarter of 2014 to finance the Big Stone Plant AQCS and transmission projects.
|
|
●
|
The corporation is reducing its 2014 earnings expectations for its Manufacturing segment due to the following factors:
|
|
o
|
As part of the recently announced facility expansion, BTD plans on exiting the lease of its Otsego, Minnesota warehouse facilities during the fourth quarter of 2014. The cost associated with exiting the lease is expected to be $0.04 per share.
|
|
o
|
T.O. Plastics earnings are expected to be in line with previous earnings expectations.
|
|
o
|
Backlog for the manufacturing companies of approximately $50 million for 2014 compared with $47 million one year ago.
|
|
●
|
The corporation is raising its previous 2014 net income guidance for its Plastics segment due to stronger actual and anticipated sales volume levels in the last half of 2014 despite an expected continued increase in PVC resin costs which, based on current competitive market conditions, are not expected to be fully recovered through higher sales prices for PVC pipe.
|
|
●
|
The corporation is raising its previous 2014 net income guidance for its Construction segment. Segment net income for 2014 is expected to be higher than previous guidance and 2013 net income as a result of improved cost control processes in construction management, more selective bidding on projects with the potential for higher margins and increased electric transmission and distribution work in western North Dakota. Backlog in place for the construction businesses is $31 million for 2014 compared with $34 million one year ago.
|
|
●
|
The corporation is lowering its previous range for corporate costs for 2014 due to lower employee benefit costs and better-than-expected performance of its captive insurance program.
|
7 |
(in millions)
|
2013
|
2014
|
2015
|
2016
|
2017
|
2018
|
||||||||||||||||||
Capital Expenditures:
|
||||||||||||||||||||||||
Electric Segment:
|
||||||||||||||||||||||||
Transmission
|
$ | 55 | $ | 55 | $ | 98 | $ | 63 | $ | 63 | ||||||||||||||
Environmental
|
73 | 50 | -- | -- | -- | |||||||||||||||||||
Other
|
34 | 43 | 45 | 41 | 80 | |||||||||||||||||||
Total Electric Segment
|
$ | 149 | $ | 162 | $ | 148 | $ | 143 | $ | 104 | $ | 143 | ||||||||||||
Manufacturing and Infrastructure Segments
|
15 | 21 | 35 | 24 | 24 | 28 | ||||||||||||||||||
Total Capital Expenditures
|
$ | 164 | $ | 183 | $ | 183 | $ | 167 | $ | 128 | $ | 171 | ||||||||||||
Total Electric Utility Average Rate Base
|
$ | 885 | $ | 991 | $ | 1,062 | $ | 1,120 | $ | 1,152 |
|
●
|
Federal and state environmental regulation could require the corporation to incur substantial capital expenditures and increased operating costs.
|
|
●
|
Volatile financial markets and changes in the corporation’s debt ratings could restrict its ability to access capital and could increase borrowing costs and pension plan and postretirement health care expenses.
|
|
●
|
The corporation relies on access to both short- and long-term capital markets as a source of liquidity for capital requirements not satisfied by cash flows from operations. If the corporation is not able to access capital at competitive rates, its ability to implement its business plans may be adversely affected.
|
|
●
|
Disruptions, uncertainty or volatility in the financial markets can also adversely impact the corporation’s results of operations, the ability of its customers to finance purchases of goods and services, and its financial condition, as well as exert downward pressure on stock prices and/or limit its ability to sustain its current common stock dividend level.
|
8 |
|
●
|
The corporation made $20.0 million in discretionary contributions to its defined benefit pension plan in January 2014. The corporation could be required to contribute additional capital to the pension plan in the future if the market value of pension plan assets significantly declines, plan assets do not earn in line with the corporation’s long-term rate of return assumptions or relief under the Pension Protection Act is no longer granted.
|
|
●
|
Any significant impairment of the corporation’s goodwill would cause a decrease in its asset values and a reduction in its net operating income.
|
|
●
|
Declines in projected operating cash flows at any of the corporation’s reporting units may result in goodwill impairments that could adversely affect its results of operations and financial position, as well as financing agreement covenants.
|
|
●
|
The corporation currently has $7.3 million of goodwill and a $1.1 million indefinite-lived trade name recorded on its consolidated balance sheet related to the acquisition of Foley in 2003. Foley net earnings improved $10.4 million between 2012 and 2013. If future expected operating profits do not meet the corporation’s projections, the reductions in anticipated cash flows from Foley may indicate its fair value is less than its book value, resulting in an impairment of some or all of the goodwill and indefinite-lived intangible assets associated with Foley along with a corresponding charge against earnings.
|
|
●
|
The inability of the corporation’s subsidiaries to provide sufficient earnings and cash flows to allow the corporation to meet its financial obligations and debt covenants and pay dividends to its shareholders could have an adverse effect on the corporation.
|
|
●
|
Economic conditions could negatively impact the corporation’s businesses.
|
|
●
|
If the corporation is unable to achieve the organic growth it expects, its financial performance may be adversely affected.
|
|
●
|
The corporation’s plans to grow and realign its business mix through capital projects, acquisitions and dispositions may not be successful, which could result in poor financial performance.
|
|
●
|
The corporation may, from time to time, sell assets to provide capital to fund investments in its 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 the corporation’s businesses could expose the corporation to additional risks associated with indemnification obligations under the applicable sales agreements and any related disputes.
|
|
●
|
The corporation’s plans to grow and operate its manufacturing and infrastructure businesses could be limited by state law.
|
|
●
|
Significant warranty claims and remediation costs in excess of amounts normally reserved for such items could adversely affect the corporation’s results of operations and financial condition.
|
|
●
|
The corporation is subject to risks associated with energy markets.
|
|
●
|
The corporation is subject to risks and uncertainties related to the timing and recovery of deferred tax assets which could have a negative impact on the corporation’s net income in future periods.
|
|
●
|
The corporation relies on its information systems to conduct its business, and failure to protect these systems against security breaches or cyber-attacks could adversely affect its business and results of operations. Additionally, if these systems fail or become unavailable for any significant period of time, the corporation’s business could be harmed.
|
|
●
|
The corporation may experience fluctuations in revenues and expenses related to its electric operations, which may cause its financial results to fluctuate and could impair its ability to make distributions to its shareholders or scheduled payments on its debt obligations, or to meet covenants under its borrowing agreements.
|
|
●
|
Actions by the regulators of the corporation’s electric operations could result in rate reductions, lower revenues and earnings or delays in recovering capital expenditures.
|
|
●
|
Otter Tail Power Company’s 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.
|
9 |
|
●
|
Changes to regulation of generating plant emissions, including but not limited to carbon dioxide emissions, could affect Otter Tail Power Company’s operating costs and the costs of supplying electricity to its customers.
|
|
●
|
Competition from foreign and domestic manufacturers, the price and availability of raw materials and general economic conditions could affect the revenues and earnings of our manufacturing businesses.
|
|
The corporation’s Plastics segment is highly dependent on a limited number of vendors for PVC resin, many of which are located in the Gulf Coast regions, and a limited supply of resin. The loss of a key vendor, or an interruption or delay in the supply of PVC resin, could result in reduced sales or increased costs for this segment.
|
|
●
|
The corporation’s plastic pipe companies compete against a large number of other manufacturers of PVC pipe and manufacturers of alternative products. Customers may not distinguish the pipe companies’ products from those of its competitors.
|
|
●
|
Changes in PVC resin prices can negatively impact PVC pipe prices, profit margins on PVC pipe sales and the value of PVC pipe held in inventory.
|
|
●
|
A significant failure or an inability to properly bid or perform on projects or contracts by the corporation’s construction businesses could lead to adverse financial results and could lead to the possibility of delay or liquidated damages.
|
|
●
|
The corporation’s construction subsidiaries enter into contracts which could expose them to unforeseen costs and costs not within their control, which may not be recoverable and could adversely affect the corporation’s results of operations and financial condition.
|
10 |
Quarter Ended September 30,
|
Year-to-Date September 30,
|
||||||||||||||||
2014
|
2013
|
2014
|
2013
|
||||||||||||||
Operating Revenues by Segment
|
|||||||||||||||||
Electric
|
$ | 89,410 | $ | 86,283 | $ | 301,409 | $ | 270,155 | |||||||||
Manufacturing
|
55,536 | 49,323 | 164,341 | 152,282 | |||||||||||||
Plastics
|
51,613 | 46,659 | 140,186 | 128,820 | |||||||||||||
Construction
|
45,846 | 47,509 | 111,599 | 108,928 | |||||||||||||
Corporate Revenue and Intersegment Eliminations
|
(34 | ) | (6 | ) | (81 | ) | (74 | ) | |||||||||
Total Operating Revenues
|
242,371 | 229,768 | 717,454 | 660,111 | |||||||||||||
Operating Expenses
|
|||||||||||||||||
Fuel and Purchased Power
|
25,831 | 27,476 | 98,725 | 88,916 | |||||||||||||
Nonelectric Cost of Goods Sold (depreciation included below)
|
123,151 | 115,475 | 333,511 | 311,474 | |||||||||||||
Electric Operating and Maintenance Expense
|
36,524 | 33,789 | 117,278 | 107,966 | |||||||||||||
Nonelectric Operating and Maintenance Expense
|
13,421 | 12,857 | 42,086 | 38,811 | |||||||||||||
Depreciation and Amortization
|
15,122 | 15,039 | 44,871 | 44,794 | |||||||||||||
Total Operating Expenses
|
214,049 | 204,636 | 636,471 | 591,961 | |||||||||||||
Operating Income (Loss) by Segment
|
|||||||||||||||||
Electric
|
16,022 | 14,231 | 52,684 | 41,183 | |||||||||||||
Manufacturing
|
4,847 | 4,908 | 14,673 | 15,489 | |||||||||||||
Plastics
|
5,238 | 5,906 | 16,810 | 19,431 | |||||||||||||
Construction
|
3,560 | 3,104 | 5,588 | 1,554 | |||||||||||||
Corporate
|
(1,345 | ) | (3,017 | ) | (8,772 | ) | (9,507 | ) | |||||||||
Total Operating Income
|
28,322 | 25,132 | 80,983 | 68,150 | |||||||||||||
Interest Charges
|
7,687 | 6,574 | 21,909 | 20,431 | |||||||||||||
Other Income
|
494 | 1,401 | 3,175 | 2,958 | |||||||||||||
Income Tax Expense – Continuing Operations
|
5,476 | 5,133 | 15,250 | 13,113 | |||||||||||||
Net Income (Loss) by Segment – Continuing Operations
|
|||||||||||||||||
Electric
|
8,612 | 8,787 | 30,507 | 24,301 | |||||||||||||
Manufacturing
|
2,899 | 2,970 | 8,095 | 8,333 | |||||||||||||
Plastics
|
3,092 | 3,403 | 9,985 | 11,215 | |||||||||||||
Construction
|
2,205 | 1,784 | 3,438 | 716 | |||||||||||||
Corporate
|
(1,155 | ) | (2,118 | ) | (5,026 | ) | (7,001 | ) | |||||||||
Net Income from Continuing Operations
|
15,653 | 14,826 | 46,999 | 37,564 | |||||||||||||
Discontinued Operations
|
|||||||||||||||||
Income - net of Income Tax Expense (Benefit) of
$116, $39, $166 and ($35) for the respective periods
|
172 | 312 | 249 | 428 | |||||||||||||
Gain on Disposition - net of Income Tax Expense of
$6 for the nine months ended September 30, 2013
|
-- | -- | -- | 210 | |||||||||||||
Net Income from Discontinued Operations
|
172 | 312 | 249 | 638 | |||||||||||||
Net Income
|
15,825 | 15,138 | 47,248 | 38,202 | |||||||||||||
Preferred Dividend Requirement and Other Adjustments
|
-- | -- | -- | 513 | |||||||||||||
Balance for Common
|
$ | 15,825 | $ | 15,138 | $ | 47,248 | $ | 37,689 | |||||||||
Average Number of Common Shares Outstanding
|
|||||||||||||||||
Basic
|
36,596,396 | 36,179,507 | 36,415,500 | 36,141,664 | |||||||||||||
Diluted
|
36,838,990 | 36,381,900 | 36,658,257 | 36,344,063 | |||||||||||||
Basic Earnings Per Common Share:
|
|||||||||||||||||
Continuing Operations (net of preferred dividend requirement and other adjustments)
|
$ | 0.43 | $ | 0.41 | $ | 1.29 | $ | 1.02 | |||||||||
Discontinued Operations
|
-- | 0.01 | 0.01 | 0.02 | |||||||||||||
$ | 0.43 | $ | 0.42 | $ | 1.30 | $ | 1.04 | ||||||||||
Diluted Earnings Per Common Share:
|
|||||||||||||||||
Continuing Operations (net of preferred dividend requirement and other adjustments)
|
$ | 0.43 | $ | 0.41 | $ | 1.28 | $ | 1.02 | |||||||||
Discontinued Operations
|
-- | 0.01 | 0.01 | 0.02 | |||||||||||||
$ | 0.43 | $ | 0.42 | $ | 1.29 | $ | 1.04 |
11 |
September 30,
|
December 31,
|
|||||||
2014
|
2013
|
|||||||
Current Assets
|
||||||||
Cash and Cash Equivalents
|
$ | -- | $ | 1,150 | ||||
Accounts Receivable:
|
||||||||
Trade—Net
|
105,119 | 83,572 | ||||||
Other
|
13,687 | 9,790 | ||||||
Inventories
|
78,939 | 72,681 | ||||||
Deferred Income Taxes
|
47,228 | 35,452 | ||||||
Unbilled Revenues
|
15,804 | 18,157 | ||||||
Costs and Estimated Earnings in Excess of Billings
|
6,271 | 4,063 | ||||||
Regulatory Assets
|
19,947 | 17,940 | ||||||
Other
|
10,779 | 7,747 | ||||||
Assets of Discontinued Operations
|
10 | 38 | ||||||
Total Current Assets
|
297,784 | 250,590 | ||||||
Investments
|
8,706 | 9,362 | ||||||
Other Assets
|
29,856 | 28,834 | ||||||
Goodwill
|
38,808 | 38,971 | ||||||
Other Intangibles—Net
|
12,595 | 13,328 | ||||||
Deferred Debits
|
||||||||
Unamortized Debt Expense
|
4,147 | 4,188 | ||||||
Regulatory Assets
|
73,725 | 83,730 | ||||||
Total Deferred Debits
|
77,872 | 87,918 | ||||||
Plant
|
||||||||
Electric Plant in Service
|
1,521,948 | 1,460,884 | ||||||
Nonelectric Operations
|
197,767 | 194,872 | ||||||
Construction Work in Progress
|
234,342 | 187,461 | ||||||
Total Gross Plant
|
1,954,057 | 1,843,217 | ||||||
Less Accumulated Depreciation and Amortization
|
705,393 | 676,201 | ||||||
Net Plant
|
1,248,664 | 1,167,016 | ||||||
Total
|
$ | 1,714,285 | $ | 1,596,019 |
12 |
September 30,
|
December 31,
|
|||||||
2014
|
2013
|
|||||||
Current Liabilities
|
||||||||
Short-Term Debt
|
$ | 39,000 | $ | 51,195 | ||||
Current Maturities of Long-Term Debt
|
198 | 188 | ||||||
Accounts Payable
|
107,307 | 113,457 | ||||||
Accrued Salaries and Wages
|
21,679 | 19,903 | ||||||
Billings In Excess Of Costs and Estimated Earnings
|
2,508 | 13,707 | ||||||
Accrued Taxes
|
10,998 | 12,491 | ||||||
Derivative Liabilities
|
6,520 | 11,782 | ||||||
Other Accrued Liabilities
|
8,286 | 6,532 | ||||||
Liabilities of Discontinued Operations
|
3,300 | 3,637 | ||||||
Total Current Liabilities
|
199,796 | 232,892 | ||||||
Pensions Benefit Liability
|
50,799 | 69,743 | ||||||
Other Postretirement Benefits Liability
|
46,083 | 45,221 | ||||||
Other Noncurrent Liabilities
|
21,890 | 25,209 | ||||||
Deferred Credits
|
||||||||
Deferred Income Taxes
|
229,148 | 195,603 | ||||||
Deferred Tax Credits
|
26,927 | 28,288 | ||||||
Regulatory Liabilities
|
76,942 | 73,926 | ||||||
Other
|
918 | 718 | ||||||
Total Deferred Credits
|
333,935 | 298,535 | ||||||
Capitalization
|
||||||||
Long-Term Debt, Net of Current Maturities
|
498,540 | 389,589 | ||||||
Common Equity
|
||||||||
Common Shares, Par Value $5 Per Share
|
183,987 | 181,358 | ||||||
Premium on Common Shares
|
267,346 | 255,759 | ||||||
Retained Earnings
|
113,569 | 99,441 | ||||||
Accumulated Other Comprehensive Loss
|
(1,660 | ) | (1,728 | ) | ||||
Total Common Equity
|
563,242 | 534,830 | ||||||
Total Capitalization
|
1,061,782 | 924,419 | ||||||
Total
|
$ | 1,714,285 | $ | 1,596,019 |
13 |
For the Nine Months Ended
September 30,
|
||||||||
In thousands
|
2014
|
2013
|
||||||
Cash Flows from Operating Activities
|
||||||||
Net Income
|
$ | 47,248 | $ | 38,202 | ||||
Adjustments to Reconcile Net Income to Net Cash Provided by Operating Activities:
|
||||||||
Net Gain from Sale of Discontinued Operations
|
-- | (210 | ) | |||||
Net Income from Discontinued Operations
|
(249 | ) | (428 | ) | ||||
Depreciation and Amortization
|
44,871 | 44,794 | ||||||
Deferred Tax Credits
|
(1,361 | ) | (1,422 | ) | ||||
Deferred Income Taxes
|
20,824 | 15,215 | ||||||
Change in Deferred Debits and Other Assets
|
4,299 | 9,817 | ||||||
Discretionary Contribution to Pension Plan
|
(20,000 | ) | (10,000 | ) | ||||
Change in Noncurrent Liabilities and Deferred Credits
|
(1,336 | ) | 7,318 | |||||
Allowance for Equity/Other Funds Used During Construction
|
(1,180 | ) | (1,462 | ) | ||||
Change in Derivatives Net of Regulatory Deferral
|
214 | 120 | ||||||
Stock Compensation Expense – Equity Awards
|
1,126 | 1,116 | ||||||
Other—Net
|
(1,303 | ) | 813 | |||||
Cash (Used for) Provided by Current Assets and Current Liabilities:
|
||||||||
Change in Receivables
|
(23,651 | ) | (9,775 | ) | ||||
Change in Inventories
|
(6,298 | ) | (3,323 | ) | ||||
Change in Other Current Assets
|
(1,769 | ) | (252 | ) | ||||
Change in Payables and Other Current Liabilities
|
(15,094 | ) | 4,170 | |||||
Change in Interest and Income Taxes Receivable/Payable
|
1,028 | 1,156 | ||||||
Net Cash Provided by Continuing Operations
|
47,369 | 95,849 | ||||||
Net Cash Used in Discontinued Operations
|
(341 | ) | (2,499 | ) | ||||
Net Cash Provided by Operating Activities
|
47,028 | 93,350 | ||||||
Cash Flows from Investing Activities
|
||||||||
Capital Expenditures
|
(125,164 | ) | (109,690 | ) | ||||
Proceeds from Disposal of Noncurrent Assets
|
3,262 | 2,615 | ||||||
Net Increase in Other Investments
|
(2,148 | ) | (680 | ) | ||||
Net Cash Used in Investing Activities - Continuing Operations
|
(124,050 | ) | (107,755 | ) | ||||
Net Proceeds from Sale of Discontinued Operations
|
-- | 12,842 | ||||||
Net Cash Provided by Investing Activities - Discontinued Operations
|
284 | 505 | ||||||
Net Cash Used in Investing Activities
|
(123,766 | ) | (94,408 | ) | ||||
Cash Flows from Financing Activities
|
||||||||
Net Short-Term (Repayments) Borrowings
|
(12,195 | ) | 40,335 | |||||
Proceeds from Issuance of Common Stock
|
13,331 | 1,496 | ||||||
Common Stock Issuance Expenses
|
(412 | ) | -- | |||||
Payments for Retirement of Capital Stock
|
(459 | ) | (15,723 | ) | ||||
Proceeds from Issuance of Long-Term Debt
|
150,000 | 40,900 | ||||||
Short-Term and Long-Term Debt Issuance Expenses
|
(516 | ) | (126 | ) | ||||
Payments for Retirement of Long-Term Debt
|
(41,039 | ) | (25,266 | ) | ||||
Dividends Paid and Other Distributions
|
(33,119 | ) | (33,027 | ) | ||||
Net Cash Provided by Financing Activities - Continuing Operations
|
75,591 | 8,589 | ||||||
Net Cash Used in Financing Activities - Discontinued Operations
|
-- | -- | ||||||
Net Cash Provided by Financing Activities
|
75,591 | 8,589 | ||||||
Net Change in Cash and Cash Equivalents – Discontinued Operations
|
(3 | ) | (776 | ) | ||||
Net Change in Cash and Cash Equivalents
|
(1,150 | ) | 6,755 | |||||
Cash and Cash Equivalents at Beginning of Period
|
1,150 | 52,362 | ||||||
Cash and Cash Equivalents at End of Period
|
$ | -- | $ | 59,117 |
14 |