x
|
QUARTERLY
REPORT PURSUANT TO SECTION 13 OR 15(d) OF
|
|
THE
SECURITIES EXCHANGE ACT OF 1934
|
o
|
TRANSITION
REPORT PURSUANT TO SECTION 13 OR 15(d) OF
|
Delaware
|
41-0423660
|
|
(State
or other jurisdiction of incorporation
or organization)
|
(I.R.S.
Employer Identification No.)
|
Large
accelerated filer
x
|
Accelerated
filer
o
|
Non-accelerated
filer
o
|
Smaller
reporting company
o
|
2007
Annual Report
|
Company's
Annual Report on Form 10-K for the year ended December 31,
2007
|
ALJ
|
Administrative
Law Judge
|
Anadarko
|
Anadarko
Petroleum Corporation
|
APB
|
Accounting
Principles Board
|
APB
Opinion No. 28
|
Interim
Financial Reporting
|
Badger
Hills Project
|
Tongue
River-Badger Hills Project
|
Bbl
|
Barrel
of oil or other liquid hydrocarbons
|
Bcf
|
Billion
cubic feet
|
BER
|
Montana
Board of Environmental Review
|
Big
Stone Station
|
450-MW
coal-fired electric generating facility located near Big Stone City, South
Dakota (22.7 percent ownership)
|
Big
Stone Station II
|
Proposed
coal-fired electric generating facility located near Big Stone City, South
Dakota (the Company anticipates ownership of at least 116
MW)
|
BLM
|
Bureau
of Land Management
|
Brazilian
Transmission Lines
|
Centennial
Resources’ equity method investment in companies owning ECTE, ENTE and
ERTE
|
Btu
|
British
thermal unit
|
Cascade
|
Cascade
Natural Gas Corporation, an indirect wholly owned subsidiary of MDU Energy
Capital
|
CBNG
|
Coalbed
natural gas
|
CEM
|
Colorado
Energy Management, LLC, a former direct wholly owned subsidiary of
Centennial Resources (sold in the third quarter of
2007)
|
Centennial
|
Centennial
Energy Holdings, Inc., a direct wholly owned subsidiary of the
Company
|
Centennial
Capital
|
Centennial
Holdings Capital LLC, a direct wholly owned subsidiary of
Centennial
|
Centennial
International
|
Centennial
Energy Resources International, Inc., a direct wholly owned subsidiary of
Centennial Resources
|
Centennial
Power
|
Centennial
Power, Inc., a former direct wholly owned subsidiary of Centennial
Resources (sold in the third quarter of 2007)
|
Centennial
Resources
|
Centennial
Energy Resources LLC, a direct wholly owned subsidiary of
Centennial
|
Clean
Air Act
|
Federal
Clean Air Act
|
Clean
Water Act
|
Federal
Clean Water Act
|
Colorado
Federal District Court
|
U.S.
District Court for the District of Colorado
|
Company
|
MDU
Resources Group, Inc.
|
D.C.
Appeals Court
|
U.S.
Court of Appeals for the District of Columbia Circuit
|
dk
|
Decatherm
|
DRC
|
Dakota
Resource Council
|
EBSR
|
Elk
Basin Storage Reservoir, one of Williston Basin's natural gas storage
reservoirs, which is located in Montana and Wyoming
|
ECTE
|
Empresa
Catarinense de Transmissão de Energia S.A.
|
EIS
|
Environmental
Impact Statement
|
ENTE
|
Empresa
Norte de Transmissão de Energia S.A.
|
EPA
|
U.S.
Environmental Protection Agency
|
ERTE
|
Empresa
Regional de Transmissão de Energia S.A.
|
Exchange
Act
|
Securities
Exchange Act of 1934, as amended
|
FASB
|
Financial
Accounting Standards Board
|
FERC
|
Federal
Energy Regulatory Commission
|
Fidelity
|
Fidelity
Exploration & Production Company, a direct wholly owned subsidiary of
WBI Holdings
|
FSP
|
FASB
Staff Position
|
FSP
FAS 157-2
|
Effective
Date of FASB Statement No. 157
|
Great
Plains
|
Great
Plains Natural Gas Co., a public utility division of the
Company
|
Hart-Scott-Rodino
Act
|
Hart-Scott-Rodino
Antitrust Improvements Act
|
Hartwell
|
Hartwell
Energy Limited Partnership, a former equity method investment of the
Company (sold in the third quarter of 2007)
|
Howell
|
Howell
Petroleum Corporation, a wholly owned subsidiary of
Anadarko
|
Indenture
|
Indenture
dated as of December 15, 2003, as supplemented, from the Company to The
Bank of New York as Trustee
|
Innovatum
|
Innovatum
Inc., a former indirect wholly owned subsidiary of WBI Holdings (the stock
and Innovatum’s assets have been sold)
|
Intermountain
|
Intermountain
Gas Company, a regulated natural gas distribution
company
|
Knife
River
|
Knife
River Corporation, a direct wholly owned subsidiary of
Centennial
|
kWh
|
Kilowatt-hour
|
LWG
|
Lower
Willamette Group
|
MBbls
|
Thousands
of barrels of oil or other liquid hydrocarbons
|
MBI
|
Morse
Bros., Inc., an indirect wholly owned subsidiary of Knife
River
|
Mcf
|
Thousand
cubic feet
|
MDU
Brasil
|
MDU
Brasil Ltda., an indirect wholly owned subsidiary of Centennial
International
|
MDU
Construction Services
|
MDU
Construction Services Group, Inc., a direct wholly owned subsidiary of
Centennial
|
MDU
Energy Capital
|
MDU
Energy Capital, LLC, a direct wholly owned subsidiary of the
Company
|
MEPA
|
Montana
Environmental Policy Act
|
MMBtu
|
Million
Btu
|
MMcf
|
Million
cubic feet
|
MMdk
|
Million
decatherms
|
MNPUC
|
Minnesota
Public Utilities Commission
|
Montana-Dakota
|
Montana-Dakota
Utilities Co., a public utility division of the
Company
|
Montana
BOGC
|
Montana
Board of Oil & Gas Conservation
|
Montana
DEQ
|
Montana
State Department of Environmental Quality
|
Montana
Federal District Court
|
U.S.
District Court for the District of Montana
|
Montana
State District Court
|
Montana
Twenty-Second Judicial District Court, Big Horn County
|
Mortgage
|
Indenture
of Mortgage dated May 1, 1939, as supplemented, amended and restated, from
the Company to The Bank of New York and Douglas J. MacInnes, successor
trustees
|
MPX
|
MPX
Termoceara Ltda. (49 percent ownership, sold in June
2005)
|
MW
|
Megawatt
|
ND
Health Department
|
North
Dakota Department of Health
|
NDPSC
|
North
Dakota Public Service Commission
|
NEPA
|
National
Environmental Policy Act
|
Ninth
Circuit
|
U.S.
Ninth Circuit Court of Appeals
|
NPRC
|
Northern
Plains Resource Council
|
NSPS
|
New
Source Performance Standards
|
OPUC
|
Oregon
Public Utilities Commission
|
Order
on Rehearing
|
Order
on Rehearing and Compliance and Remanding Certain Issues for
Hearing
|
Oregon
DEQ
|
Oregon
State Department of Environmental Quality
|
Prairielands
|
Prairielands
Energy Marketing, Inc., an indirect wholly owned subsidiary of WBI
Holdings
|
PSD
|
Prevention
of Significant Deterioration
|
ROD
|
Record
of Decision
|
SEC
|
U.S.
Securities and Exchange Commission
|
Securities
Act
|
Securities
Act of 1933, as amended
|
SEIS
|
Supplemental
Environmental Impact Statement
|
SFAS
|
Statement
of Financial Accounting Standards
|
SFAS
No. 71
|
Accounting
for the Effects of Certain Types of Regulation
|
SFAS
No. 115
|
Accounting
for Certain Investments in Debt and Equity Securities
|
SFAS
No. 141 (revised)
|
Business
Combinations (revised 2007)
|
SFAS
No. 157
|
Fair
Value Measurements
|
SFAS
No. 159
|
The
Fair Value Option for Financial Assets and Financial
Liabilities
|
SFAS
No. 160
|
Noncontrolling
Interests in Consolidated Financial Statements - an amendment of ARB No.
51 (Consolidated Financial Statements)
|
SFAS
No. 161
|
Disclosures
about Derivative Instruments and Hedging Activities - an amendment of FASB
Statement No. 133
|
South Dakota Federal District Court
|
U.S.
District Court for the District of South Dakota
|
South
Dakota SIP
|
South
Dakota State Implementation Plan
|
TRWUA
|
Tongue
River Water Users’ Association
|
WBI
Holdings
|
WBI
Holdings, Inc., a direct wholly owned subsidiary of
Centennial
|
Williston
Basin
|
Williston
Basin Interstate Pipeline Company, an indirect wholly owned subsidiary of
WBI Holdings
|
WUTC
|
Washington
Utilities and Transportation
Commission
|
Part I -- Financial
Information
|
Page
|
|||
Consolidated
Statements of Income --
|
||||
Three
and Six Months Ended June 30, 2008 and 2007
|
7 | |||
Consolidated
Balance Sheets --
|
||||
June
30, 2008 and 2007, and December 31, 2007
|
9 | |||
Consolidated
Statements of Cash Flows --
|
||||
Six
Months Ended June 30, 2008 and 2007
|
10 | |||
Notes
to Consolidated Financial Statements
|
11 | |||
Management's
Discussion and Analysis of Financial Condition and Results of
Operations
|
36 | |||
Quantitative
and Qualitative Disclosures About Market Risk
|
57 | |||
Controls
and Procedures
|
58 | |||
Part
II -- Other Information
|
||||
Legal
Proceedings
|
58 | |||
Risk
Factors
|
59 | |||
Unregistered
Sales of Equity Securities and Use of Proceeds
|
62 | |||
Exhibits
|
62 | |||
Signatures
|
63 | |||
Exhibit
Index
|
64 | |||
Exhibits
|
Three Months
Ended
June 30,
|
Six Months
Ended
June 30,
|
|||||||||||||||
2008
|
2007
|
2008
|
2007
|
|||||||||||||
(In
thousands, except per share amounts)
|
||||||||||||||||
Operating
revenues:
|
||||||||||||||||
Electric,
natural gas distribution and pipeline and energy
services
|
$ | 376,324 | $ | 195,488 | $ | 893,586 | $ | 463,500 | ||||||||
Construction
services, natural gas and oil production, construction materials and
contracting, and other
|
875,448 | 786,877 | 1,480,093 | 1,306,356 | ||||||||||||
1,251,772 | 982,365 | 2,373,679 | 1,769,856 | |||||||||||||
Operating
expenses:
|
||||||||||||||||
Fuel
and purchased power
|
15,718 | 15,489 | 34,495 | 32,607 | ||||||||||||
Purchased
natural gas sold
|
145,060 | 40,294 | 421,684 | 139,129 | ||||||||||||
Operation
and maintenance:
|
||||||||||||||||
Electric, natural gas distribution and pipeline and energy
services
|
61,828 | 46,659 | 121,390 | 91,315 | ||||||||||||
Construction
services, natural gas and oil production, construction materials and
contracting, and other
|
687,479 | 629,782 | 1,185,097 | 1,075,631 | ||||||||||||
Depreciation,
depletion and amortization
|
89,678 | 70,044 | 176,909 | 139,846 | ||||||||||||
Taxes,
other than income
|
53,518 | 37,312 | 108,041 | 69,574 | ||||||||||||
1,053,281 | 839,580 | 2,047,616 | 1,548,102 | |||||||||||||
Operating
income
|
198,491 | 142,785 | 326,063 | 221,754 | ||||||||||||
Earnings
from equity method investments
|
2,039 | 4,030 | 3,864 | 6,084 | ||||||||||||
Other
income (expense)
|
(37 | ) | 883 | 1,528 | 2,215 | |||||||||||
Interest
expense
|
19,186 | 17,478 | 37,842 | 34,854 | ||||||||||||
Income
before income taxes
|
181,307 | 130,220 | 293,613 | 195,199 | ||||||||||||
Income
taxes
|
65,800 | 48,184 | 107,055 | 71,756 | ||||||||||||
Income
from continuing operations
|
115,507 | 82,036 | 186,558 | 123,443 | ||||||||||||
Income
from discontinued operations, net of tax (Note 3)
|
--- | 7,439 | --- | 12,694 | ||||||||||||
Net
income
|
115,507 | 89,475 | 186,558 | 136,137 | ||||||||||||
Dividends
on preferred stocks
|
171 | 171 | 343 | 343 | ||||||||||||
Earnings
on common stock
|
$ | 115,336 | $ | 89,304 | $ | 186,215 | $ | 135,794 |
Three
Months Ended
June
30,
|
Six
Months Ended
June
30,
|
|||||||||||||||
2008
|
2007
|
2008
|
2007
|
|||||||||||||
(In
thousands, except per share amounts)
|
||||||||||||||||
Earnings
per common share -- basic
|
||||||||||||||||
Earnings before discontinued operations
|
$ | .63 | $ | .45 | $ | 1.02 | $ | .68 | ||||||||
Discontinued operations, net of tax
|
--- | .04 | --- | .07 | ||||||||||||
Earnings
per common share -- basic
|
$ | .63 | $ | .49 | $ | 1.02 | $ | .75 | ||||||||
Earnings
per common share -- diluted
|
||||||||||||||||
Earnings before discontinued operations
|
$ | .63 | $ | .45 | $ | 1.01 | $ | .67 | ||||||||
Discontinued operations, net of tax
|
--- | .04 | --- | .07 | ||||||||||||
Earnings
per common share -- diluted
|
$ | .63 | $ | . 49 | $ | 1.01 | $ | . 74 | ||||||||
Dividends
per common share
|
$ | .1450 | $ | .1350 | $ | .2900 | $ | .2700 | ||||||||
Weighted
average common shares outstanding -- basic
|
182,972 | 181 ,847 | 182,785 | 181,595 | ||||||||||||
Weighted
average common shares outstanding -- diluted
|
183,727 | 182,746 | 183,513 | 182 ,469 |
June
30,
2008
|
June
30,
2007
|
December
31,
2007
|
||||||||||
(In thousands, except shares
and per share amounts)
|
||||||||||||
ASSETS
|
||||||||||||
Current
assets:
|
||||||||||||
Cash
and cash equivalents
|
$ | 82,039 | $ | 68,134 | $ | 105,820 | ||||||
Receivables,
net
|
769,379 | 642,559 | 715,484 | |||||||||
Inventories
|
267,125 | 221,179 | 229,255 | |||||||||
Deferred
income taxes
|
47,442 | --- | 7,046 | |||||||||
Short-term
investments
|
13,768 | 16,700 | 91,550 | |||||||||
Prepayments
and other current assets
|
175,293 | 78,535 | 64,998 | |||||||||
Current
assets held for sale and related to discontinued
operations
|
--- | 69,662 | 179 | |||||||||
1,355,046 | 1,096,769 | 1,214,332 | ||||||||||
Investments
|
121,279 | 136,585 | 118,602 | |||||||||
Property,
plant and equipment
|
6,507,164 | 4,953,171 | 5,930,246 | |||||||||
Less
accumulated depreciation, depletion and amortization
|
2,408,093 | 1,851,825 | 2,270,691 | |||||||||
4,099,071 | 3,101,346 | 3,659,555 | ||||||||||
Deferred
charges and other assets:
|
||||||||||||
Goodwill
|
437,832 | 227,029 | 425,698 | |||||||||
Other
intangible assets, net
|
32,485 | 17,150 | 27,792 | |||||||||
Other
|
166,019 | 113,193 | 146,455 | |||||||||
Noncurrent
assets held for sale and related to discontinued
operations
|
--- | 410,662 | --- | |||||||||
636,336 | 768,034 | 599,945 | ||||||||||
$ | 6,211,732 | $ | 5,102,734 | $ | 5,592,434 | |||||||
LIABILITIES
AND STOCKHOLDERS’ EQUITY
|
||||||||||||
Current
liabilities:
|
||||||||||||
Short-term
borrowings
|
$ | 79,960 | $ | --- | $ | 1,700 | ||||||
Long-term
debt due within one year
|
87,366 | 131,661 | 161,682 | |||||||||
Accounts
payable
|
396,715 | 284,208 | 369,235 | |||||||||
Taxes
payable
|
46,200 | 38,769 | 60,407 | |||||||||
Deferred
income taxes
|
--- | 1,396 | --- | |||||||||
Dividends
payable
|
26,723 | 24,725 | 26,619 | |||||||||
Accrued
compensation
|
55,631 | 47,440 | 66,255 | |||||||||
Other
accrued liabilities
|
295,153 | 108,450 | 163,990 | |||||||||
Current
liabilities held for sale and related to discontinued
operations
|
--- | 14,156 | --- | |||||||||
987,748 | 650,805 | 849,888 | ||||||||||
Long-term
debt
|
1,474,908 | 1,224,286 | 1,146,781 | |||||||||
Deferred
credits and other liabilities:
|
||||||||||||
Deferred
income taxes
|
685,480 | 570,590 | 668,016 | |||||||||
Other
liabilities
|
472,989 | 349,895 | 396,430 | |||||||||
Noncurrent
liabilities held for sale and related to discontinued
operations
|
--- | 35,488 | --- | |||||||||
1,158,469 | 955,973 | 1,064,446 | ||||||||||
Commitments
and contingencies
|
||||||||||||
Stockholders’
equity
:
|
||||||||||||
Preferred
stocks
|
15,000 | 15,000 | 15,000 | |||||||||
Common
stockholders’ equity:
|
||||||||||||
Common
stock
|
||||||||||||
Shares
issued -- $1.00 par value, 183,706,236 at June 30, 2008, 182,416,029
at June 30, 2007 and 182,946,528 at December 31, 2007
|
183,706 | 182,416 | 182,947 | |||||||||
Other
paid-in capital
|
925,784 | 895,838 | 912,806 | |||||||||
Retained
earnings
|
1,567,035 | 1,190,935 | 1,433,585 | |||||||||
Accumulated
other comprehensive loss
|
(97,292 | ) | (8,893 | ) | (9,393 | ) | ||||||
Treasury
stock at cost – 538,921 shares
|
(3,626 | ) | (3,626 | ) | (3,626 | ) | ||||||
Total
common stockholders’ equity
|
2,575,607 | 2,256,670 | 2,516,319 | |||||||||
Total
stockholders’ equity
|
2,590,607 | 2,271,670 | 2,531,319 | |||||||||
$ | 6,211,732 | $ | 5,102,734 | $ | 5,592,434 |
Six
Months Ended
June
30,
|
||||||||
2008
|
2007
|
|||||||
(In
thousands)
|
||||||||
Operating
activities:
|
||||||||
Net
income
|
$ | 186,558 | $ | 136,137 | ||||
Income
from discontinued operations, net of tax
|
--- | 12,694 | ||||||
Income
from continuing operations
|
186,558 | 123,443 | ||||||
Adjustments
to reconcile net income to net cash provided by operating
activities:
|
||||||||
Depreciation,
depletion and amortization
|
176,909 | 139,846 | ||||||
Earnings,
net of distributions, from equity method investments
|
(1,844 | ) | (722 | ) | ||||
Deferred
income taxes
|
34,870 | 24,756 | ||||||
Changes
in current assets and liabilities, net of acquisitions:
|
||||||||
Receivables
|
(46,550 | ) | (14,083 | ) | ||||
Inventories
|
(36,482 | ) | (16,690 | ) | ||||
Other
current assets
|
(111,199 | ) | (25,259 | ) | ||||
Accounts
payable
|
18,953 | (11,644 | ) | |||||
Other
current liabilities
|
11,209 | (38,040 | ) | |||||
Other
noncurrent changes
|
6,381 | (1,107 | ) | |||||
Net
cash provided by continuing operations
|
238,805 | 180,500 | ||||||
Net
cash used in discontinued operations
|
--- | (41,884 | ) | |||||
Net
cash provided by operating activities
|
238,805 | 138,616 | ||||||
Investing
activities:
|
||||||||
Capital
expenditures
|
(386,014 | ) | (242,729 | ) | ||||
Acquisitions,
net of cash acquired
|
(271,191 | ) | (329 | ) | ||||
Net
proceeds from sale or disposition of property
|
26,379 | 10,848 | ||||||
Investments
|
80,389 | 17,309 | ||||||
Net
cash used in continuing operations
|
(550,437 | ) | (214,901 | ) | ||||
Net
cash used in discontinued operations
|
--- | (1,379 | ) | |||||
Net
cash used in investing activities
|
(550,437 | ) | (216,280 | ) | ||||
Financing
activities:
|
||||||||
Issuance
of short-term borrowings
|
79,960 | --- | ||||||
Repayment
of short-term borrowings
|
(1,700 | ) | --- | |||||
Issuance
of long-term debt
|
379,644 | 186,578 | ||||||
Repayment
of long-term debt
|
(125,637 | ) | (85,028 | ) | ||||
Proceeds
from issuance of common stock
|
4,945 | 15,775 | ||||||
Dividends
paid
|
(53,296 | ) | (49,300 | ) | ||||
Tax
benefit on stock-based compensation
|
3,737 | 4,505 | ||||||
Net
cash provided by continuing operations
|
287,653 | 72,530 | ||||||
Net
cash provided by discontinued operations
|
--- | --- | ||||||
Net
cash provided by financing activities
|
287,653 | 72,530 | ||||||
Effect
of exchange rate changes on cash and cash equivalents
|
198 | 190 | ||||||
Decrease
in cash and cash equivalents
|
(23,781 | ) | (4,944 | ) | ||||
Cash
and cash equivalents -- beginning of year
|
105,820 | 73,078 | ||||||
Cash
and cash equivalents -- end of period
|
$ | 82,039 | $ | 68,134 |
Three
Months Ended
|
Six
Months
Ended
|
|||||||
June
30, 2007
|
June
30, 2007
|
|||||||
(In thousands)
|
||||||||
Operating
revenues
|
$ | 439 | $ | 689 | ||||
Income
from discontinued operations before income tax expense
(benefit)
|
104 | 28 | ||||||
Income
tax expense (benefit)
|
15 | (29 | ) | |||||
Income
from discontinued operations, net of tax
|
$ | 89 | $ | 57 |
Three
Months Ended
|
Six
Months
Ended
|
|||||||
June
30, 2007
|
June
30, 2007
|
|||||||
|
(In thousands)
|
|||||||
Operating
revenues
|
$ | 64,291 | $ | 98,887 | ||||
Income
from discontinued operations before income tax expense
|
9,532 | 16,923 | ||||||
Income
tax expense
|
2,182 | 4,286 | ||||||
Income
from discontinued operations, net of tax
|
$ | 7,350 | $ | 12,637 |
June
30,
|
December
31,
|
|||||||
2007
|
2007
|
|||||||
(In
thousands)
|
||||||||
Cash
and cash equivalents
|
$ | 1,575 | $ | --- | ||||
Receivables,
net
|
7,878 | --- | ||||||
Inventories
|
555 | 179 | ||||||
Prepayments
and other current assets
|
59,654 | --- | ||||||
Total
current assets held for sale and related to discontinued
operations
|
$ | 69,662 | $ | 179 | ||||
Net
property, plant and equipment
|
$ | 391,708 | $ | --- | ||||
Goodwill
|
11,167 | --- | ||||||
Other
intangible assets, net
|
7,241 | --- | ||||||
Other
|
546 | --- | ||||||
Total
noncurrent assets held for sale and related to discontinued
operations
|
$ | 410,662 | $ | --- | ||||
Accounts
payable
|
$ | 7,264 | $ | --- | ||||
Other
accrued liabilities
|
6,892 | --- | ||||||
Total
current liabilities held for sale and related to discontinued
operations
|
$ | 14,156 | $ | --- | ||||
Deferred
income taxes
|
$ | 32,888 | $ | --- | ||||
Other
liabilities
|
2,600 | --- | ||||||
Total
noncurrent liabilities held for sale and related to discontinued
operations
|
$ | 35,488 | $ | --- |
Six
Months Ended
June
30,
|
||||||||
2008
|
2007
|
|||||||
(In
thousands)
|
||||||||
Interest,
net of amount capitalized
|
$ | 37,504 | $ | 35,028 | ||||
Income
taxes
|
$ | 91,398 | $ | 113,919 |
Three
Months Ended
June
30,
|
||||||||
2008
|
2007
|
|||||||
(In
thousands)
|
||||||||
Net
income
|
$ | 115,507 | $ | 89,475 | ||||
Other
comprehensive income (loss):
|
||||||||
Net
unrealized gain (loss) on derivative instruments qualifying as
hedges:
|
||||||||
Net
unrealized gain (loss) on derivative instruments arising during the
period, net of tax of $(37,169) and $6,096 in 2008 and 2007,
respectively
|
(60,644 | ) | 9,739 | |||||
Less:
Reclassification adjustment for gain (loss) on derivative instruments
included in net income, net of tax of $(5,045) and $1,509 in 2008 and
2007, respectively
|
(8,230 | ) | 2,411 | |||||
Net
unrealized gain (loss) on derivative instruments qualifying as
hedges
|
(52,414 | ) | 7,328 | |||||
Foreign
currency translation adjustment, net of tax of $2,570 in
2008
|
3,977 | 3,576 | ||||||
(48,437 | ) | 10,904 | ||||||
Comprehensive
income
|
$ | 67,070 | $ | 100,379 |
|
Six
Months Ended
June
30,
|
||||||||
2008
|
2007
|
|||||||
(In
thousands)
|
||||||||
Net
income
|
$ | 186,558 | $ | 136,137 | ||||
Other
comprehensive loss:
|
||||||||
Net
unrealized loss on derivative instruments qualifying as
hedges:
|
||||||||
Net
unrealized gain (loss) on derivative instruments arising during the
period, net of tax of $(53,537) and $1,204 in 2008 and 2007,
respectively
|
(87,433 | ) | 1,923 | |||||
Less:
Reclassification adjustment for gain on derivative instruments included in
net income, net of tax of $2,786 and $6,272 in 2008 and 2007,
respectively
|
4,522 | 10,018 | ||||||
Net
unrealized loss on derivative instruments qualifying as
hedges
|
(91,955 | ) | (8,095 | ) | ||||
Foreign
currency translation adjustment, net of tax of $2,876 in
2008
|
4,461 | 5,684 | ||||||
(87,494 | ) | (2,411 | ) | |||||
Comprehensive
income
|
$ | 99,064 | $ | 133,726 |
June
30,
|
June
30,
|
December
31,
|
||||||||||
2008
|
2007
|
2007
|
||||||||||
(In
thousands)
|
||||||||||||
Customer
relationships
|
$ | 25,262 | $ | 13,959 | $ | 21,834 | ||||||
Accumulated
amortization
|
(5,979 | ) | (3,234 | ) | (4,444 | ) | ||||||
19,283 | 10,725 | 17,390 | ||||||||||
Noncompete
agreements
|
10,823 | 7,434 | 10,655 | |||||||||
Accumulated
amortization
|
(4,493 | ) | (2,926 | ) | (3,654 | ) | ||||||
6,330 | 4,508 | 7,001 | ||||||||||
Other
|
8,370 | 3,745 | 5,943 | |||||||||
Accumulated
amortization
|
(1,498 | ) | (1,828 | ) | (2,542 | ) | ||||||
6,872 | 1,917 | 3,401 | ||||||||||
Total
|
$ | 32,485 | $ | 17,150 | $ | 27,792 |
14.
|
Fair
value measurements
|
|
Upon
the adoption of SFAS No. 159, the Company elected to measure its
investments in certain fixed-income and equity securities at fair value.
These investments had previously been accounted for as available-for-sale
investments in accordance with SFAS No. 115. The Company anticipates using
these investments to satisfy its obligations under its unfunded,
nonqualified benefit plans for executive officers and certain key
management employees, and invests in these fixed-income and equity
securities for the purpose of earning investment returns and capital
appreciation. These investments totaled $34.0 million as of June 30, 2008.
The decrease in the fair value of these investments for the three and six
months ended June 30, 2008, was $184,000 (before tax) and $2.3 million
(before tax), respectively, which is considered part of the cost of the
plan, and is classified in operation and
maintenance
|
Fair
Value Measurements at June 30, 2008, Using
|
||||||||||||||||
Balance
at June 30,
|
Quoted
Prices in Active Markets for Identical Assets
|
Significant
Other Observable Inputs
|
Significant
Unobservable Inputs
|
|||||||||||||
2008
|
(Level 1)
|
(Level 2)
|
(Level 3)
|
|||||||||||||
(In
thousands)
|
||||||||||||||||
Assets:
|
||||||||||||||||
Available-for-sale
securities
|
$ | 45,390 | $ | 33,990 | $ | 11,400 | $ | --- | ||||||||
Commodity
derivative agreements
|
89,136 | --- | 89,136 | --- | ||||||||||||
Total
assets measured at fair value
|
$ | 134,526 | $ | 33,990 | $ | 100,536 | $ | --- | ||||||||
Liabilities:
|
||||||||||||||||
Commodity derivative agreements
|
$ | 138,615 | $ | --- | $ | 138,615 | $ | --- | ||||||||
Total
liabilities measured at fair value
|
$ | 138,615 | $ | --- | $ | 138,615 | $ | --- |
|
The
estimated fair value of the Company’s Level 1 available-for-sale
securities is based on quoted market prices in active markets for
identical equity and fixed-income securities. The estimated fair value of
the Company’s Level 2 available-for-sale securities is based on comparable
market transactions. The estimated fair value of the Company’s commodity
derivative instruments reflects the estimated amounts the Company would
receive or pay to terminate the contracts at the reporting date based upon
quoted market prices of comparable
contracts.
|
Inter-
|
||||||||||||
External
|
segment
|
Earnings
|
||||||||||
Three
Months
|
Operating
|
Operating
|
on
Common
|
|||||||||
Ended
June 30, 2008
|
Revenues
|
Revenues
|
Stock
|
|||||||||
(In
thousands)
|
||||||||||||
Electric
|
$ | 45,873 | $ | --- | $ | 2,787 | ||||||
Natural
gas distribution
|
196,956 | --- | 5,443 | |||||||||
Pipeline
and energy services
|
133,495 | 21,621 | 6,842 | |||||||||
376,324 | 21,621 | 15,072 | ||||||||||
Construction
services
|
324,632 | 38 | 14,089 | |||||||||
Natural
gas and oil production
|
123,370 | 91,824 | 71,687 | |||||||||
Construction
materials and contracting
|
427,446 | --- | 12,735 | |||||||||
Other
|
--- | 2,660 | 1,753 | |||||||||
875,448 | 94,522 | 100,264 | ||||||||||
Intersegment
eliminations
|
--- | (116,143 | ) | --- | ||||||||
Total
|
$ | 1,251,772 | $ | --- | $ | 115,336 | ||||||
Inter-
|
||||||||||||
External
|
segment
|
Earnings
|
||||||||||
Three
Months
|
Operating
|
Operating
|
on
Common
|
|||||||||
Ended
June 30, 2007
|
Revenues
|
Revenues
|
Stock
|
|||||||||
(In
thousands)
|
||||||||||||
Electric
|
$ | 44,591 | $ | --- | $ | 3,568 | ||||||
Natural
gas distribution
|
53,403 | --- | (559 | ) | ||||||||
Pipeline
and energy services
|
97,494 | 14,660 | 6,228 | |||||||||
195,488 | 14,660 | 9,237 | ||||||||||
Construction
services
|
263,483 | 349 | 13,026 | |||||||||
Natural
gas and oil production
|
67,924 | 59,471 | 35,166 | |||||||||
Construction
materials and contracting
|
455,470 | --- | 25,541 | |||||||||
Other
|
--- | 2,440 | 6,334 | |||||||||
786,877 | 62,260 | 80,067 | ||||||||||
Intersegment
eliminations
|
--- | (76,920 | ) | --- | ||||||||
Total
|
$ | 982,365 | $ | --- | $ | 89,304 |
Inter-
|
||||||||||||
External
|
segment
|
Earnings
|
||||||||||
Six
Months
|
Operating
|
Operating
|
on
Common
|
|||||||||
Ended
June 30, 2008
|
Revenues
|
Revenues
|
Stock
|
|||||||||
(In
thousands)
|
||||||||||||
Electric
|
$ | 98,129 | $ | --- | $ | 8,267 | ||||||
Natural
gas distribution
|
559,101 | --- | 21,828 | |||||||||
Pipeline
and energy services
|
236,356 | 52,553 | 13,996 | |||||||||
893,586 | 52,553 | 44,091 | ||||||||||
Construction
services
|
632,019 | 82 | 24,903 | |||||||||
Natural
gas and oil production
|
219,351 | 165,430 | 122,333 | |||||||||
Construction
materials and contracting
|
628,723 | --- | (8,362 | ) | ||||||||
Other
|
--- | 5,296 | 3,250 | |||||||||
1,480,093 | 170,808 | 142,124 | ||||||||||
Intersegment
eliminations
|
--- | (223,361 | ) | --- | ||||||||
Total
|
$ | 2,373,679 | $ | --- | $ | 186,215 | ||||||
Inter-
|
||||||||||||
External
|
segment
|
Earnings
|
||||||||||
Six
Months
|
Operating
|
Operating
|
on
Common
|
|||||||||
Ended
June 30, 2007
|
Revenues
|
Revenues
|
Stock
|
|||||||||
(In
thousands)
|
||||||||||||
Electric
|
$ | 91,695 | $ | --- | $ | 7,353 | ||||||
Natural
gas distribution
|
189,465 | --- | 5,584 | |||||||||
Pipeline
and energy services
|
182,340 | 42,952 | 11,938 | |||||||||
463,500 | 42,952 | 24,875 | ||||||||||
Construction
services
|
500,120 | 474 | 20,260 | |||||||||
Natural
gas and oil production
|
123,193 | 122,781 | 65,787 | |||||||||
Construction
materials and contracting
|
683,043 | --- | 15,745 | |||||||||
Other
|
--- | 4,880 | 9,127 | |||||||||
1,306,356 | 128,135 | 110,919 | ||||||||||
Intersegment
eliminations
|
--- | (171,087 | ) | --- | ||||||||
Total
|
$ | 1,769,856 | $ | --- | $ | 135,794 |
Other
|
||||||||||||||||
Postretirement
|
||||||||||||||||
Three
Months
|
Pension
Benefits
|
Benefits
|
||||||||||||||
Ended
June 30,
|
2008
|
2007
|
2008
|
2007
|
||||||||||||
(In
thousands)
|
||||||||||||||||
Components
of net periodic benefit cost:
|
||||||||||||||||
Service
cost
|
$ | 2,191 | $ | 2,011 | $ | 660 | $ | 447 | ||||||||
Interest
cost
|
6,505 | 4,222 | 1,797 | 1,180 | ||||||||||||
Expected
return on assets
|
(8,458 | ) | (5,094 | ) | (1,691 | ) | (1,279 | ) | ||||||||
Amortization
of prior service cost (credit)
|
198 | 207 | (988 | ) | 14 | |||||||||||
Amortization
net actuarial loss
|
332 | 426 | 246 | 164 | ||||||||||||
Amortization
of net transition obligation
|
--- | --- | 763 | 635 | ||||||||||||
Net
periodic benefit cost, including amount capitalized
|
768 | 1,772 | 787 | 1,161 | ||||||||||||
Less
amount capitalized
|
217 | 217 | 124 | 90 | ||||||||||||
Net
periodic benefit cost
|
$ | 551 | $ | 1,555 | $ | 663 | $ | 1,071 | ||||||||
Other
|
||||||||||||||||
Postretirement
|
||||||||||||||||
Six
Months
|
Pension
Benefits
|
Benefits
|
||||||||||||||
Ended
June 30,
|
2008
|
2007
|
2008
|
2007
|
||||||||||||
(In
thousands)
|
||||||||||||||||
Components
of net periodic benefit cost:
|
||||||||||||||||
Service
cost
|
$ | 4,820 | $ | 4,261 | $ | 1,150 | $ | 980 | ||||||||
Interest
cost
|
11,629 | 8,363 | 2,982 | 2,118 | ||||||||||||
Expected
return on assets
|
(14,494 | ) | (10,164 | ) | (3,388 | ) | (2,372 | ) | ||||||||
Amortization
of prior service cost (credit)
|
364 | 416 | (1,677 | ) | 25 | |||||||||||
Amortization
net actuarial (gain) loss
|
574 | 500 | 361 | (149 | ) | |||||||||||
Amortization
of net transition obligation
|
--- | --- | 1,294 | 1,166 | ||||||||||||
Net
periodic benefit cost, including amount capitalized
|
2,893 | 3,376 | 722 | 1,768 | ||||||||||||
Less
amount capitalized
|
396 | 368 | 189 | 141 | ||||||||||||
Net
periodic benefit cost
|
$ | 2,497 | $ | 3,008 | $ | 533 | $ | 1,627 |
19.
|
Contingencies
|
ITEM
2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION
|
|
AND RESULTS OF
OPERATIONS
|
·
|
Organic
growth as well as a continued disciplined approach to the acquisition of
well-managed companies and
properties
|
·
|
The
elimination of system-wide cost redundancies through increased focus on
integration of operations and standardization and consolidation of various
support services and functions across companies within the
organization
|
·
|
The
development of projects that are accretive to earnings per share and
return on invested capital
|
Three
Months Ended
|
Six
Months Ended
|
|||||||||||||||||
June
30,
|
June
30,
|
|||||||||||||||||
2008
|
2007
|
2008
|
2007
|
|
||||||||||||||
(Dollars
in millions, where applicable)
|
||||||||||||||||||
Electric
|
$ | 2.8 | $ | 3.6 | $ | 8.3 | $ | 7.4 | ||||||||||
Natural
gas distribution
|
5.4 | (.6 | ) | 21.8 | 5.6 | |||||||||||||
Construction
services
|
14.1 | 13.0 | 24.9 | 20.3 | ||||||||||||||
Pipeline
and energy services
|
6.8 | 6.1 | 14.0 | 11.8 | ||||||||||||||
Natural
gas and oil production
|
71.7 | 35.2 | 122.3 | 65.8 | ||||||||||||||
Construction
materials and contracting
|
12.7 | 25.5 | (8.4 | ) | 15.7 | |||||||||||||
Other
|
1.8 | (1.0 | ) | 3.3 | (3.5 | ) | ||||||||||||
Earnings
before discontinued operations
|
115.3 | 81.8 | 186.2 | 123.1 | ||||||||||||||
Income
from discontinued operations, net of tax
|
--- | 7.5 | --- | 12.7 | ||||||||||||||
Earnings
on common stock
|
$ | 115.3 | $ | 89.3 | $ | 186.2 | $ | 135.8 | ||||||||||
Earnings
per common share – basic:
|
||||||||||||||||||
Earnings before discontinued
operations
|
$ | .63 | $ | .45 | $ | 1.02 | $ | .68 | ||||||||||
Discontinued operations, net of
tax
|
--- | .04 | --- | .07 | ||||||||||||||
Earnings per common share –
basic
|
$ | .63 | $ | .49 | $ | 1.02 | $ | .75 | ||||||||||
Earnings
per common share – diluted:
|
||||||||||||||||||
Earnings before discontinued
operations
|
$ | .63 | $ | .45 | $ | 1.01 | $ | .67 | ||||||||||
Discontinued operations, net of
tax
|
--- | .04 | --- | .07 | ||||||||||||||
Earnings per common share
–
diluted
|
$ | .63 | $ | .49 | $ | 1.01 | $ | .74 | ||||||||||
Return
on average common equity for the 12 months ended
|
19.3 | % | 15.2 | % |
·
|
Higher
average realized natural gas and oil prices of 35 percent and 97 percent,
respectively, and increased oil and natural gas production of 22 percent
and 9 percent, respectively, partially offset by higher depreciation,
depletion and amortization expense at the natural gas and oil production
business
|
·
|
Increased
earnings at the natural gas distribution business, largely earnings at
Cascade, which was acquired on July 2,
2007
|
·
|
Higher
average realized oil and natural gas prices of 94 percent and 26 percent,
respectively, and increased natural gas and oil production of 8 percent
and 17 percent, respectively, partially offset by higher depreciation,
depletion and amortization expense at the natural gas and oil production
business
|
·
|
Increased
earnings at the natural gas distribution business, largely earnings at
Cascade as previously discussed
|
·
|
Higher
construction workloads at the construction services
business
|
Three
Months Ended
|
Six
Months Ended
|
|||||||||||||||
June
30,
|
June
30,
|
|||||||||||||||
2008
|
2007
|
2008
|
2007
|
|||||||||||||
(Dollars
in millions, where applicable)
|
||||||||||||||||
Operating
revenues
|
$ |
|
$ | 44.6 | $ | 98.1 | $ | 91.7 | ||||||||
Operating
expenses:
|
||||||||||||||||
Fuel
and purchased power
|
15.7
|
15.5 | 34.5 | 32.6 | ||||||||||||
Operation
and maintenance
|
16.5 | 14.5 | 31.4 | 29.5 | ||||||||||||
Depreciation,
depletion and amortization
|
6.1 | 5.6 | 12.1 | 11.2 | ||||||||||||
Taxes,
other than income
|
2.2 | 2.1 | 4.4 | 4.3 | ||||||||||||
40.5 | 37.7 | 82.4 | 77.6 | |||||||||||||
Operating
income
|
5.4 | 6.9 | 15.7 | 14.1 | ||||||||||||
Earnings
|
$ | 2.8 | $ | 3.6 | $ | 8.3 | $ | 7.4 | ||||||||
Retail
sales (million kWh)
|
577.7 | 596.3 | 1,285.5 | 1,242.0 | ||||||||||||
Sales
for resale (million kWh)
|
51.5 | 47.0 | 99.9 | 91.2 | ||||||||||||
Average
cost of fuel and purchased power per kWh
|
$ | .024 | $ | .024 | $ | .024 | $ | .024 |
·
|
Increased
retail sales margins and volumes of $2.3 million (after tax), largely due
to the resolution of a rate proceeding and higher system
load
|
·
|
Higher
sales for resale volumes of 10 percent, largely due to the addition of the
wind-powered electric generating station near Baker, Montana, and higher
plant availability
|
·
|
Higher
operations and maintenance costs of $1.1 million (after tax), primarily
higher payroll and benefit related costs, as well as electric generating
station costs associated with scheduled
maintenance
|
·
|
Increased
depreciation, depletion and amortization expense of $600,000 (after tax),
as previously discussed
|
Three
Months Ended
|
Six
Months Ended
|
|||||||||||||||
June
30,
|
June
30,
|
|||||||||||||||
2008
|
2007
|
2008
|
2007
|
|||||||||||||
(Dollars
in millions, where applicable)
|
||||||||||||||||
Operating
revenues
|
$ | 197.0 | $ | 53.4 | $ | 559.1 | $ | 189.5 | ||||||||
Operating
expenses:
|
||||||||||||||||
Purchased
natural gas sold
|
137.4 | 34.3 | 420.0 | 140.5 | ||||||||||||
Operation
and maintenance
|
28.7 | 15.6 | 55.7 | 31.2 | ||||||||||||
Depreciation,
depletion and amortization
|
7.2 | 2.5 | 14.3 | 5.0 | ||||||||||||
Taxes,
other than income
|
11.0 | 1.5 | 25.6 | 3.2 | ||||||||||||
184.3 | 53.9 | 515.6 | 179.9 | |||||||||||||
Operating
income (loss)
|
12.7 | (.5 | ) | 43.5 | 9.6 | |||||||||||
Earnings
(loss)
|
$ | 5.4 | $ | (.6 | ) | $ | 21.8 | $ | 5.6 | |||||||
Volumes
(MMdk):
|
||||||||||||||||
Sales
|
15.4 | 5.3 | 46.6 | 21.2 | ||||||||||||
Transportation
|
18.5 | 2.9 | 45.1 | 6.3 | ||||||||||||
Total
throughput
|
33.9 | 8.2 | 91.7 | 27.5 | ||||||||||||
Degree
days (% of normal)*
|
||||||||||||||||
Montana-Dakota
|
117 | % | 94 | % | 104 | % | 94 | % | ||||||||
Cascade
|
120 | % | --- | 111 | % | --- | ||||||||||
Average
cost of natural gas, including transportation, per dk**
|
||||||||||||||||
Montana-Dakota
|
$ | 9.45 | $ | 6.44 | $ | 8.16 | $ | 6.64 | ||||||||
Cascade
|
$ | 8.55 | --- | $ | 8.07 | --- |
·
|
Earnings
of $5.3 million, including a $4.4 million (after tax) gain on the sale of
its natural gas management service, at Cascade which was acquired on July
2, 2007
|
·
|
Increased
retail sales volumes from existing operations resulting from 25 percent
colder weather than last year
|
·
|
Higher
nonregulated energy-related services of $200,000 (after
tax)
|
·
|
Earnings
of $15.2 million at Cascade, as previously
discussed
|
·
|
Increased
retail sales volumes from existing operations resulting from 12 percent
colder weather than last year
|
·
|
Higher
nonregulated energy-related services of $400,000 (after
tax)
|
Three
Months Ended
|
Six
Months Ended
|
|||||||||||||||
June
30,
|
June
30,
|
|||||||||||||||
2008
|
2007
|
2008
|
2007
|
|||||||||||||
(In
millions)
|
||||||||||||||||
Operating
revenues
|
$ | 324.7 | $ | 263.8 | $ | 632.1 | $ | 500.6 | ||||||||
Operating
expenses:
|
||||||||||||||||
Operation
and maintenance
|
286.6 | 230.6 | 560.5 | 442.4 | ||||||||||||
Depreciation,
depletion and amortization
|
3.1 | 3.4 | 6.5 | 6.9 | ||||||||||||
Taxes,
other than income
|
10.4 | 7.5 | 22.4 | 16.2 | ||||||||||||
300.1 | 241.5 | 589.4 | 465.5 | |||||||||||||
Operating
income
|
24.6 | 22.3 | 42.7 | 35.1 | ||||||||||||
Earnings
|
$ | 14.1 | $ | 13.0 | $ | 24.9 | $ | 20.3 |
·
|
Higher
construction workloads of $9.5 million (after tax), largely in the
Southwest region
|
·
|
Increased
equipment sales and rentals
|
Three
Months Ended
|
Six
Months Ended
|
|||||||||||||||
June
30,
|
June
30,
|
|||||||||||||||
2008
|
2007
|
2008
|
2007
|
|||||||||||||
(Dollars
in millions)
|
||||||||||||||||
Operating
revenues
|
$ | 155.1 | $ | 112.2 | $ | 288.9 | $ | 225.3 | ||||||||
Operating
expenses:
|
||||||||||||||||
Purchased
natural gas sold
|
116.6 | 75.8 | 210.7 | 155.4 | ||||||||||||
Operation
and maintenance
|
16.7 | 16.6 | 34.3 | 30.6 | ||||||||||||
Depreciation,
depletion and amortization
|
5.9 | 5.2 | 11.5 | 10.6 | ||||||||||||
Taxes,
other than income
|
2.8 | 2.7 | 5.6 | 5.5 | ||||||||||||
142.0 | 100.3 | 262.1 | 202.1 | |||||||||||||
Operating
income
|
13.1 | 11.9 | 26.8 | 23.2 | ||||||||||||
Income
from continuing operations
|
6.8 | 6.1 | 14.0 | 11.8 | ||||||||||||
Income
from discontinued operations, net of tax
|
--- | .1 | --- | .1 | ||||||||||||
Earnings
|
$ | 6.8 | $ | 6.2 | $ | 14.0 | $ | 11.9 | ||||||||
Transportation
volumes (MMdk):
|
||||||||||||||||
Montana-Dakota
|
7.2 | 7.1 | 15.5 | 15.1 | ||||||||||||
Other
|
26.8 | 29.7 | 48.2 | 50.2 | ||||||||||||
34.0 | 36.8 | 63.7 | 65.3 | |||||||||||||
Gathering
volumes (MMdk)
|
25.5 | 22.5 | 49.5 | 44.7 |
·
|
Higher
storage and gathering rates of $700,000 (after tax), partially offset by
lower storage balances
|
·
|
Increased
gathering volumes of 14 percent
|
·
|
Increased
on- and off-system transportation and demand fees of $600,000 (after tax),
largely offset by a decrease in volumes transported to
storage
|
·
|
Higher
storage and gathering rates of $1.4 million (after tax), partially offset
by lower storage balances
|
·
|
Increased
gathering volumes of 11 percent
|
·
|
Increased
off-system transportation and demand fees mainly related to an expansion
of the Grasslands system ($1.2 million after tax), partially offset by a
decrease in volumes transported to
storage
|
Three
Months Ended
|
Six
Months Ended
|
|||||||||||||||
June
30,
|
June
30,
|
|||||||||||||||
2008
|
2007
|
2008
|
2007
|
|||||||||||||
(Dollars
in millions, where applicable)
|
||||||||||||||||
Operating
revenues:
|
||||||||||||||||
Natural
gas
|
$ | 140.5 | $ | 96.1 | $ | 258.0 | $ | 190.0 | ||||||||
Oil
|
74.6 | 31.2 | 126.7 | 55.8 | ||||||||||||
Other
|
.1 | .1 | .1 | .2 | ||||||||||||
215.2 | 127.4 | 384.8 | 246.0 | |||||||||||||
Operating
expenses:
|
||||||||||||||||
Purchased
natural gas sold
|
.1 | --- | .1 | .3 | ||||||||||||
Operation
and maintenance:
|
||||||||||||||||
Lease
operating costs
|
19.2 | 15.6 | 37.5 | 31.1 | ||||||||||||
Gathering
and transportation
|
6.2 | 5.0 | 11.9 | 9.5 | ||||||||||||
Other
|
13.7 | 9.1 | 22.6 | 17.5 | ||||||||||||
Depreciation,
depletion and amortization
|
41.7 | 29.8 | 81.0 | 59.6 | ||||||||||||
Taxes,
other than income:
|
||||||||||||||||
Production
and property taxes
|
16.3 | 9.3 | 29.9 | 18.2 | ||||||||||||
Other
|
.3 | .3 | .5 | .5 | ||||||||||||
97.5 | 69.1 | 183.5 | 136.7 | |||||||||||||
Operating
income
|
117.7 | 58.3 | 201.3 | 109.3 | ||||||||||||
Earnings
|
$ | 71.7 | $ | 35.2 | $ | 122.3 | $ | 65.8 | ||||||||
Production:
|
||||||||||||||||
Natural
gas (MMcf)
|
16,531 | 15,231 | 33,092 | 30,671 | ||||||||||||
Oil
(MBbls)
|
717 | 589 | 1,338 | 1,145 | ||||||||||||
Total
Production (MMcf equivalent)
|
20,830 | 18,770 | 41,118 | 37,543 | ||||||||||||
Average
realized prices (including hedges):
|
||||||||||||||||
Natural
gas (per Mcf)
|
$ | 8.50 | $ | 6.31 | $ | 7.80 | $ | 6.20 | ||||||||
Oil
(per barrel)
|
$ | 104.19 | $ | 52.83 | $ | 94.72 | $ | 48.71 | ||||||||
Average
realized prices (excluding hedges):
|
||||||||||||||||
Natural
gas (per Mcf)
|
$ | 9.33 | $ | 5.82 | $ | 8.11 | $ | 5.78 | ||||||||
Oil
(per barrel)
|
$ | 105.34 | $ | 52.83 | $ | 95.60 | $ | 48.71 | ||||||||
Average
depreciation, depletion and amortization rate, per equivalent
Mcf
|
$ | 1.94 | $ | 1.52 | $ | 1.91 | $ | 1.52 | ||||||||
Production
costs, including taxes, per equivalent Mcf:
|
||||||||||||||||
Lease
operating costs
|
$ | .92 | $ | .83 | $ | .91 | $ | .83 | ||||||||
Gathering
and transportation
|
.30 | .27 | .29 | .25 | ||||||||||||
Production
and property taxes
|
.78 | .50 | .73 | .49 | ||||||||||||
$ | 2.00 | $ | 1.60 | $ | 1.93 | $ | 1.57 |
·
|
Higher
average realized natural gas prices of 35 percent and higher average
realized oil prices of 97 percent
|
·
|
Increased
oil and natural gas production of 22 percent and 9 percent, respectively,
largely related to the East Texas property acquired in January 2008 and
additional drilling activity including wells in the Bakken formation and
Paradox Basin
|
·
|
Higher
depreciation, depletion and amortization expense of $7.4 million (after
tax) due to higher depletion rates and increased
production
|
·
|
Higher
production taxes of $4.3 million (after tax) associated with increased
revenue
|
·
|
Increased
lease operating expenses of $2.2 million (after
tax)
|
·
|
Higher
average realized oil prices of 94 percent and higher average realized
natural gas prices of 26 percent
|
·
|
Increased
natural gas and oil production of 8 percent and 17 percent, respectively,
as previously discussed
|
·
|
Higher
depreciation, depletion and amortization expense of $13.3 million (after
tax) due to higher depletion rates and increased
production
|
·
|
Higher
production taxes of $7.3 million (after tax) associated with increased
revenue
|
·
|
Increased
lease operating expenses of $4.0 million (after
tax)
|
Three
Months Ended
|
Six
Months Ended
|
|||||||||||||||
June
30,
|
June
30,
|
|||||||||||||||
2008
|
2007
|
2008
|
2007
|
|||||||||||||
(Dollars
in millions)
|
||||||||||||||||
Operating
revenues
|
$ | 427.4 | $ | 455.5 | $ | 628.7 | $ | 683.0 | ||||||||
Operating
expenses:
|
||||||||||||||||
Operation
and maintenance
|
366.1 | 372.8 | 561.3 | 581.6 | ||||||||||||
Depreciation,
depletion and amortization
|
25.4 | 23.2 | 50.9 | 45.8 | ||||||||||||
Taxes,
other than income
|
10.4 | 13.9 | 19.5 | 21.6 | ||||||||||||
401.9 | 409.9 | 631.7 | 649.0 | |||||||||||||
Operating
income (loss)
|
25.5 | 45.6 | (3.0 | ) | 34.0 | |||||||||||
Earnings
(loss)
|
$ | 12.7 | $ | 25.5 | $ | (8.4 | ) | $ | 15.7 | |||||||
Sales
(000's):
|
||||||||||||||||
Aggregates
(tons)
|
8,719 | 10,339 | 12,960 | 15,896 | ||||||||||||
Asphalt
(tons)
|
1,452 | 1,769 | 1,648 | 2,105 | ||||||||||||
Ready-mixed
concrete (cubic yards)
|
1,052 | 1,092 | 1,663 | 1,718 |
·
|
Decreased
construction workloads, margins and product volumes that were
significantly lower as a result of the economic slowdown and unfavorable
weather conditions as well as significantly higher diesel fuel costs at
existing operations had a combined negative effect on earnings of $13.4
million (after tax)
|
·
|
Higher
depreciation, depletion and amortization expense, largely the result of
higher property, plant and equipment
balances
|
·
|
Decreased
construction workloads, margins and product volumes that were
significantly lower as previously described as well as significantly
higher diesel fuel costs at existing operations had a combined negative
effect on earnings of $23.2 million (after
tax)
|
·
|
Higher
depreciation, depletion and amortization expense, as previously
discussed
|
Three
Months Ended
|
Six
Months Ended
|
|||||||||||||||
June
30,
|
June
30,
|
|||||||||||||||
2008
|
2007
|
2008
|
2007
|
|||||||||||||
(In
millions)
|
||||||||||||||||
Other:
|
||||||||||||||||
Operating
revenues
|
$ | 2.7 | $ | 2.4 | $ | 5.3 | $ | 4.9 | ||||||||
Operation
and maintenance
|
2.8 | 3.7 | 5.5 | 7.5 | ||||||||||||
Depreciation,
depletion and amortization
|
.3 | .4 | .6 | .8 | ||||||||||||
Taxes,
other than income
|
.1 | --- | .1 | .1 | ||||||||||||
Intersegment
transactions:
|
||||||||||||||||
Operating
revenues
|
$ | 116.2 | $ | 76.9 | $ | 223.3 | $ | 171.1 | ||||||||
Purchased
natural gas sold
|
109.0 | 69.8 | 209.1 | 157.1 | ||||||||||||
Operation
and maintenance
|
7.2 | 7.1 | 14.2 | 14.0 |
·
|
Earnings
per common share for 2008 are projected in the range of $2.10 to $2.35.
The Company expects the percentage of 2008 earnings per common share by
quarter to be in the following approximate
ranges:
|
o
|
Third
quarter – 30 percent to
35 percent
|
o
|
Fourth
quarter – 25 percent to
30 percent
|
·
|
Long-term
compound annual growth goals on earnings per share from operations are in
the range of 7 percent to
10 percent.
|
·
|
The
Company is analyzing potential projects for accommodating load growth and
replacing an expired purchased power contract with company-owned
generation, which will add to base-load capacity and rate base. The
Company is a participant in the Big Stone Station II project. A final
decision on construction of the Big Stone Station II project will be made
when major permits are issued and certain regulatory approvals are
obtained. Those permits and approvals include a certificate of need
and route permit from the MNPUC for construction and operation of a
portion of the transmission line for delivery of the electric energy from
the Big Stone Station II. In May 2008, administrative law judges from
the Minnesota Office of Administrative Hearings recommended the MNPUC deny
issuance of the certificate of need and route permit, or alternatively
impose certain conditions on project participants subject to rate
regulation by the MNPUC. On June 5, 2008, the MNPUC voted to delay
its decision on the Big Stone Station II application for a transmission
certificate of need and a route permit. The decision to delay was made so
that the MNPUC can receive information from an independent expert on
construction costs, natural gas prices and potential costs related to
carbon dioxide. A hearing and decision is expected by the fall of 2008. If
the decision is to proceed with construction of the plant, it is projected
to be completed in 2013. The Company anticipates it would own at
least 116 MW of this plant or other generation
sources.
|
·
|
This
business continues to pursue expansion of energy-related
services.
|
·
|
As
discussed in Note 20, the Company has entered into an agreement to acquire
Intermountain for approximately $328 million, pending regulatory
approvals. It is anticipated that closing will occur during the fourth
quarter of 2008.
|
·
|
This
business continues to pursue expansion of energy-related services and
expects continued strong customer growth in Washington and
Oregon.
|
·
|
The
Company anticipates margins in 2008 to be slightly lower than
2007.
|
·
|
The
Company continues to focus on costs and efficiencies to enhance
margins.
|
·
|
Work
backlog as of June 30, 2008, was approximately $655 million,
compared to $765 million at
June 30, 2007.
|
·
|
This
business continually seeks opportunities to expand through strategic
acquisitions and organic growth
opportunities.
|
·
|
Based
on indicated demand from a recent open season, an incremental expansion to
the Grasslands Pipeline in the range of 40,000 Mcf per day or more is now
anticipated for 2009. Through additional compression, the pipeline firm
capacity could ultimately reach 200,000 Mcf per day, an increase from
the current firm capacity of 138,000 Mcf per
day.
|
·
|
The
Company is pursuing the development of the Bakken Pipeline, a new natural
gas pipeline designed to transport natural gas from the fast-growing
Bakken Play in northwestern North Dakota and northeastern Montana to a new
pipeline interconnect with Alliance Pipeline. The Bakken Pipeline is
anticipated to have an initial capacity of approximately 100,000 Mcf
per day, with the flexibility to expand capacity to 200,000 Mcf per
day. The pipeline project remains subject to shipper commitment and
regulatory approvals.
|
·
|
In
2008, total gathering and transportation throughput is expected to be
slightly higher than 2007 record
levels.
|
·
|
The
Company expects a combined natural gas and oil production increase in 2008
in the range of 10 percent to 14 percent over 2007 levels.
Meeting these targets will depend on the success of exploration activities
and the timely receipt of regulatory
approvals.
|
·
|
The
Company is involved in exploratory drilling in the Bakken area in North
Dakota and in the Paradox Basin in Utah. Net acreage in the Bakken
includes over 65,000 acres with plans to participate in 50 to 60 wells in
2008, roughly half of which will be operated. If the Three Forks/Sanish
formation proves to be a separate reservoir from the middle Bakken, the
Company expects the Three Forks/Sanish will provide additional
opportunities to grow reserves and production within our existing
leasehold position. In the Paradox Basin, the Company has net acreage of
approximately 90,000 acres with plans to drill approximately 5 wells in
2008.
|
·
|
Currently,
this segment's net combined natural gas and oil production is
approximately 225,000 Mcf equivalent to 240,000 Mcf equivalent per
day.
|
·
|
The
Company’s combined proved natural gas and oil reserves as of
December 31, 2007, were 707 Bcf equivalent. In January,
97 Bcf equivalent of proved reserves were added with the East Texas
property acquisition. The Company is pursuing continued reserve growth
through further exploitation of its existing properties, exploratory
drilling and property
acquisitions.
|
·
|
Earnings
guidance reflects estimated natural gas prices for August through December
as follows:
|
·
|
Earnings
guidance reflects estimated NYMEX crude oil prices for August through
December in the range of $110 to $115 per
barrel.
|
·
|
For
the last six months of 2008, the Company has hedged approximately
45 percent to 50 percent of its estimated natural gas production
and less than 5 percent of its estimated oil production. Of its estimated
2009 natural gas production, the Company has hedged approximately
30 percent to 35 percent and less than 5 percent for 2010
and 2011. The hedges that are in place as of August 1, 2008, are
summarized in the following chart:
|
Commodity
|
Type
|
Index
*
|
Period
Outstanding
|
Forward
Notional Volume
(MMBtu/Bbl)
|
Price
(Per
MMBtu/Bbl)
|
|||||
Natural
Gas
|
Collar
|
Ventura
|
7/08
- 10/08
|
615,000 | $7.00-$8.05 | |||||
Natural
Gas
|
Collar
|
Ventura
|
7/08
- 10/08
|
615,000 | $7.00-$8.06 | |||||
Natural
Gas
|
Swap
|
Ventura
|
7/08
- 10/08
|
615,000 | $7.45 | |||||
Natural
Gas
|
Collar
|
Ventura
|
7/08
- 10/08
|
615,000 | $7.50-$8.70 | |||||
Natural
Gas
|
Swap
|
Ventura
|
7/08
- 10/08
|
615,000 | $8.005 | |||||
Natural
Gas
|
Collar
|
Ventura
|
7/08
- 10/08
|
430,500 | $7.25-$8.02 | |||||
Natural
Gas
|
Collar
|
CIG
|
7/08
- 10/08
|
430,500 | $5.75-$7.40 | |||||
Natural
Gas
|
Collar
|
Ventura
|
7/08
- 12/08
|
920,000 | $7.00-$8.45 | |||||
Natural
Gas
|
Collar
|
Ventura
|
7/08
- 12/08
|
920,000 | $7.50-$8.34 | |||||
Natural
Gas
|
Swap
|
Ventura
|
7/08
- 12/08
|
1,656,000 | $8.55 | |||||
Natural
Gas
|
Collar
|
NYMEX
|
7/08
- 12/08
|
920,000 | $7.50-$10.15 | |||||
Natural
Gas
|
Swap
|
HSC
|
7/08
- 12/08
|
1,251,200 | $7.91 | |||||
Natural
Gas
|
Collar
|
CIG
|
7/08
- 12/08
|
920,000 | $6.75-$7.04 | |||||
Natural
Gas
|
Swap
|
CIG
|
7/08
- 12/08
|
920,000 | $6.35 | |||||
Natural
Gas
|
Swap
|
CIG
|
7/08
- 12/08
|
920,000 | $6.41 | |||||
Natural
Gas
|
Swap
|
Ventura
|
7/08
- 12/08
|
2,576,000 | $9.10 | |||||
Natural
Gas
|
Collar
|
NYMEX
|
7/08
- 12/08
|
920,000 | $9.00-$10.50 | |||||
Natural
Gas
|
Swap
|
Ventura
|
11/08
- 12/08
|
427,000 | $9.25 | |||||
Natural
Gas
|
Swap
|
Ventura
|
11/08
- 12/08
|
610,000 | $8.85 | |||||
Natural
Gas
|
Swap
|
Ventura
|
11/08
- 12/08
|
915,000 | $12.465 | |||||
Natural
Gas
|
Swap
|
CIG
|
1/09
- 3/09
|
225,000 | $8.45 | |||||
Natural
Gas
|
Swap
|
HSC
|
1/09
- 12/09
|
2,482,000 | $8.16 | |||||
Natural
Gas
|
Collar
|
Ventura
|
1/09
- 12/09
|
1,460,000 | $7.90-$8.54 | |||||
Natural
Gas
|
Collar
|
Ventura
|
1/09
- 12/09
|
4,380,000 | $8.25-$8.92 | |||||
Natural
Gas
|
Swap
|
Ventura
|
1/09
- 12/09
|
3,650,000 | $9.02 | |||||
Natural
Gas
|
Collar
|
CIG
|
1/09
- 12/09
|
3,650,000 | $6.50-$7.20 | |||||
Natural
Gas
|
Swap
|
CIG
|
1/09
- 12/09
|
912,500 | $7.27 | |||||
Natural
Gas
|
Collar
|
NYMEX
|
1/09
- 12/09
|
1,825,000 | $8.75-$10.15 | |||||
Natural
Gas
|
Swap
|
Ventura
|
1/09
- 12/09
|
3,650,000 | $9.20 | |||||
Natural
Gas
|
Collar
|
NYMEX
|
1/09
- 12/09
|
3,650,000 | $11.00-$12.78 | |||||
Natural
Gas
|
Basis
|
NYMEX
to Ventura
|
1/09
- 12/09
|
3,650,000 | $0.61 | |||||
Natural
Gas
|
Swap
|
HSC
|
1/10
- 12/10
|
1,606,000 | $8.08 | |||||
Natural
Gas
|
Swap
|
HSC
|
1/11
- 12/11
|
1,350,500 | $8.00 | |||||
Crude
Oil
|
Collar
|
NYMEX
|
7/08
- 12/08
|
36,800 | $67.50-$78.70 |
*
|
Ventura
is an index pricing point related to Northern Natural Gas Co.’s system;
CIG is an index pricing point related to Colorado Interstate Gas Co.’s
system; HSC is the Houston Ship Channel hub in southeast Texas which
connects to several
pipelines.
|
·
|
The
economic slowdown has adversely impacted operations. It is expected that
2008 earnings will be significantly lower than
2007.
|
·
|
The
Company continues its strong emphasis on industrial, energy and public
works projects and cost containment. It is also pursuing expansion of its
liquid asphalt materials business to cost effectively meet the liquid
asphalt and diesel requirements of the Company, as well as third party
customers.
|
·
|
Work
backlog as of June 30, 2008, was approximately $634 million,
compared to $662 million at June 30, 2007. Margins on the
backlog have declined as a result of a shift to more public sector work
and increased competition.
|
·
|
A
key long-term strategy for the Company is its 1.2 billion tons of
strategically located aggregate
reserves.
|
·
|
Higher
income from continuing operations of $63.1 million, largely reflecting
increases at the natural gas and oil production and natural gas
distribution businesses, partially offset by the loss at the construction
materials and contracting business
|
·
|
The
absence in 2008 of cash used in 2007 by discontinued operations of $41.9
million, primarily the result of quarterly income tax payments due to the
estimated gain on the sale of the domestic independent power production
assets
|
·
|
Higher
depreciation, depletion and amortization expense of $37.1 million, largely
at the natural gas and oil production
business
|
·
|
Completed
acquisitions
|
·
|
Anticipated
acquisition of Intermountain
|
·
|
System
upgrades
|
·
|
Routine
replacements
|
·
|
Service
extensions
|
·
|
Routine
equipment maintenance and
replacements
|
·
|
Buildings,
land and building improvements
|
·
|
Pipeline
and gathering projects
|
·
|
Further
enhancement of natural gas and oil production and reserve
growth
|
·
|
Power
generation opportunities, including certain costs for additional electric
generating capacity
|
·
|
Other
growth opportunities
|
Off
balance sheet arrangements
|
Period
|
(a)
Total
Number of Shares
(or
Units) Purchased (1)
|
(b)
Average
Price Paid
per
Share
(or
Unit)
|
(c)
Total
Number of Shares (or Units) Purchased as Part of Publicly Announced Plans
or Programs (2)
|
(d)
Maximum
Number (or Approximate Dollar Value) of Shares (or Units) that May Yet Be
Purchased Under the Plans or Programs (2)
|
||||||
April
1 through April 30, 2008
|
36,625 | $ | 28.51 | |||||||
May
1 through May 31, 2008
|
||||||||||
June
1 through June 30, 2008
|
||||||||||
Total
|
36,625 |
ARTICLE
I
|
DEFINITIONS
|
1
|
Section
1.1
|
Definitions
|
1
|
ARTICLE
II
|
PURCHASE
AND SALE OF SHARES
|
13
|
Section
2.1
|
Purchase
and Sale of Shares.
|
13
|
Section
2.2
|
Purchase
Price Adjustments.
|
14
|
Section
2.3
|
Closing.
|
17
|
ARTICLE
III
|
REPRESENTATIONS
AND WARRANTIES OF SELLER
|
19
|
Section
3.1
|
Corporate
Status
|
19
|
Section
3.2
|
Authorization
|
19
|
Section
3.3
|
No
Conflict
|
19
|
Section
3.4
|
Governmental
Filings
|
20
|
Section
3.5
|
Capital
Structure; Subsidiaries.
|
20
|
Section
3.6
|
Financial
Statements
|
20
|
Section
3.7
|
Undisclosed
Liabilities
|
21
|
Section
3.8
|
Absence
of Certain Changes
|
21
|
Section
3.9
|
Legal
Proceedings
|
22
|
Section
3.10
|
Compliance
with Laws; Permits; Certain Filings.
|
22
|
Section
3.11
|
Environmental
Matters.
|
23
|
Section
3.12
|
Taxes
|
23
|
Section
3.13
|
Labor
|
25
|
Section
3.14
|
Employee
Benefit Plans.
|
25
|
Section
3.15
|
Company
Material Contracts.
|
27
|
Section
3.16
|
Insurance
|
27
|
Section
3.17
|
Regulation
as a Utility
|
28
|
Section
3.18
|
Regulatory
Proceedings
|
28
|
Section
3.19
|
Real
Property.
|
28
|
Section
3.20
|
Intellectual
Property.
|
29
|
Section
3.21
|
Intercompany
Arrangements
|
29
|
Section
3.22
|
Brokers'
Fees
|
30
|
Section
3.23
|
Disclaimer
of Other Warranties
|
30
|
ARTICLE
IV
|
REPRESENTATIONS
AND WARRANTIES OF PURCHASER
|
30
|
Section
4.1
|
Status
|
30
|
Section
4.2
|
Authorization
|
30
|
Section
4.3
|
No
Conflict
|
31
|
Section
4.4
|
Governmental
Filings
|
31
|
Section
4.5
|
Legal
Proceedings
|
31
|
Section
4.6
|
Acquisition
for Investment
|
32
|
Section
4.7
|
Funding
|
32
|
Section
4.8
|
Solvency
|
32
|
Section
4.9
|
Foreign
Persons
|
33
|
Section
4.10
|
Brokers'
Fees
|
33
|
Section
4.11
|
No
Reliance
|
33
|
ARTICLE
V
|
COVENANTS
|
33
|
Section
5.1
|
Conduct
of the Business
|
33
|
Section
5.2
|
Employment
Matters.
|
36
|
Section
5.3
|
Publicity
|
38
|
Section
5.4
|
Confidentiality
|
39
|
Section
5.5
|
Access
to Information
|
39
|
Section
5.6
|
Filings,
Authorizations and Consents.
|
39
|
Section
5.7
|
Director
and Officer Liability; Indemnification
|
41
|
Section
5.8
|
Reasonable
Best Efforts
|
41
|
Section
5.9
|
Insurance
|
42
|
Section
5.10
|
Indebtedness;
Termination of Affiliate Agreements.
|
42
|
Section
5.11
|
Names
|
43
|
Section
5.12
|
Tax
Matters.
|
43
|
Section
5.13
|
Non-Solicitation
of Employees
|
45
|
Section
5.14
|
Purchaser's
Financing Activities.
|
46
|
ARTICLE
VI
|
CONDITIONS
OF CLOSING
|
46
|
Section
6.1
|
Conditions
to Obligations of Purchaser and Seller
|
46
|
Section
6.2
|
Additional
Conditions to Obligations of Purchaser
|
47
|
Section
6.3
|
Additional
Conditions to Obligations of Seller
|
48
|
ARTICLE
VII
|
TERMINATION
|
49
|
Section
7.1
|
Termination
of Agreement
|
49
|
Section
7.2
|
Effect
of Termination
|
50
|
ARTICLE
VIII
|
INDEMNIFICATION
|
50
|
Section
8.1
|
Indemnification
of Purchaser by Seller
|
50
|
Section
8.2
|
Indemnification
of Seller by Purchaser
|
51
|
Section
8.3
|
Survival
|
51
|
Section
8.4
|
Limitation
on Liability.
|
52
|
Section
8.5
|
Notice
and Opportunity to Defend
|
53
|
Section
8.6
|
No
Knowledge of Breach; Mitigation; Other Indemnification
Provisions.
|
54
|
Section
8.7
|
Tax
Treatment of Indemnification Provisions
|
54
|
Section
8.8
|
Exclusivity
|
54
|
ARTICLE
IX
|
MISCELLANEOUS
|
55
|
Section
9.1
|
Assignment;
Binding Effect
|
55
|
Section
9.2
|
Choice
of Law
|
55
|
Section
9.3
|
Consent
to Jurisdiction; Waiver of Jury Trial
|
55
|
Section
9.4
|
Notices
|
55
|
Section
9.5
|
Headings
|
56
|
Section
9.6
|
Fees
and Expenses
|
56
|
Section
9.7
|
Entire
Agreement
|
57
|
Section
9.8
|
Interpretation.
|
57
|
Section
9.9
|
Seller
Disclosure Schedule
|
57
|
Section
9.10
|
Waiver
and Amendment
|
58
|
Section
9.11
|
Counterparts;
Facsimile Signatures
|
58
|
Section
9.12
|
Third-Party
Beneficiaries
|
58
|
Section
9.13
|
Specific
Performance
|
58
|
Section
9.14
|
Severability
|
59
|
AAA
|
1
|
Action
|
1
|
Adjusted
Net Working Capital
|
1
|
Adjustment
Date
|
2
|
Affiliate
|
2
|
Affiliated
Group
|
2
|
Aggregate
Net Company Indebtedness
|
2
|
Aggregate
SERP Adjustment Amount
|
2
|
Agreement
|
1,
2
|
Balance
Sheet
|
2
|
Balance
Sheet Date
|
2
|
Base
Claim
|
2
|
Base
Purchase Price
|
13
|
Business
|
2
|
Business
Day
|
3
|
Closing
|
3,
17
|
Closing
Adjustment Statement
|
3
|
Closing
Balance Sheet
|
3
|
Closing
Date
|
3,
18
|
Closing
Date Financial Statements
|
3
|
Closing
Date Purchase Price
|
3
|
Code
|
3
|
Company
|
1,
3
|
Company
Deferred Compensation Plan
|
3
|
Company
Employees
|
3,
36
|
Company
Indemnitees
|
3,
41
|
Company
Intellectual Property
|
3
|
Company
Leases
|
3,
28
|
Company
Material Contracts
|
4,
27
|
Company
Owned Intellectual Property
|
4,
29
|
Company
Plans
|
4,
25
|
Company
Retiree
|
4
|
Company
Savings Plan
|
4
|
Company
Savings Plan
|
37
|
Company
SERP
|
4,
37
|
Company
Severance Plan
|
4,
36
|
Confidentiality
Agreement
|
4,
39
|
Contract
|
4
|
Copyrights
|
4
|
Credit
Agreement
|
4
|
Debenture
Purchase Agreement
|
4
|
Debt
|
4
|
Deductible
|
5
|
Determination
Date
|
5
|
Dispute
Notice
|
5
|
Electronic
Data Room
|
5
|
Encumbrance
|
5
|
Environmental
Law
|
5,
23
|
ERISA
|
5,
25
|
ERISA
Affiliate
|
5,
26
|
Estimated
Adjusted Net Working Capital
|
5
|
Estimated
Adjustment Statement
|
5
|
Estimated
Aggregate Net Company Indebtedness
|
5
|
Estimated
Closing Balance Sheet
|
5
|
Estimated
Financial Statements
|
5
|
Estimated
Net PP&E Amount
|
5
|
Excluded
SERP Employees
|
6
|
Excluded
Warranties
|
6
|
Existing
CBA
|
35
|
Final
Adjusted Net Working Capital
|
6
|
Final
Aggregate Net Company Indebtedness
|
6
|
Final
Net PP&E Amount
|
6
|
Final
Order
|
6
|
Final
Purchase Price
|
6
|
Final
Report
|
6
|
Financial
Statements
|
6
|
GAAP
|
6
|
Governmental
Entity
|
6
|
Governmental
Filings
|
7,
20
|
Governmental
Order
|
7
|
Hazardous
Substance
|
7,
23
|
Hedging
Transaction
|
7
|
HSR
Act
|
7,
20
|
Indemnitee
|
7
|
Indemnitor
|
7
|
Independent
Accounting Firm
|
7
|
Initial
Outside Date
|
7,
49
|
Intellectual
Property
|
7
|
IPUC
|
7
|
IPUC
Notification Filing
|
7
|
IRS
|
7
|
Knowledge
of Seller
|
7
|
Law
|
7
|
Leased
Real Property
|
8,
28
|
License
Agreements
|
8,
29
|
Losses
|
8
|
March
31 Calculations
|
8
|
Marks
|
8
|
Material
Adverse Effect
|
8
|
Material
Easement Agreements
|
9,
28
|
Multiemployer
Plan
|
9
|
Net
PP&E Amount
|
9
|
Offering
Materials
|
9,
46
|
Owned
Real Property
|
9,
28
|
Patents
|
9
|
Permits
|
9,
22
|
Permitted
Encumbrance
|
9
|
Person
|
10
|
Pre-Closing
Straddle Period Taxes
|
10
|
Pre-Closing
Tax Period
|
10
|
Pre-Closing
Tax Returns
|
10
|
Purchase
Price
|
10
|
Purchaser
|
1,
10
|
Purchaser
Governmental Filings
|
10,
31
|
Purchaser
Indemnified Parties
|
10
|
Purchaser
Material Adverse Effect
|
10
|
Purchaser
Savings Plan
|
10,
37
|
Purchaser
Warranty Claim
|
10
|
Real
Property
|
11
|
Refund
|
11,
45
|
Representatives
|
11
|
Seller
|
1,
11
|
Seller
Deferred Compensation Plan
|
11
|
Seller
Disclosure Schedule
|
11
|
Seller
Indemnified Parties
|
11
|
SERP
Accrual
|
11
|
Shares
|
1,
11
|
Solvent
|
11
|
Straddle
Period
|
12
|
Straddle
Period Tax Returns
|
12
|
Subsidiary
|
12
|
Target
Adjusted Net Working Capital
|
12
|
Target
Aggregate Net Company Indebtedness
|
12
|
Target
Net PP&E Amount
|
12
|
Tax
|
12
|
Tax
Benefits
|
12
|
Tax
Return
|
12
|
Taylor
Litigation
|
12
|
Terminating
Contracts
|
12,
42
|
Title
IV Plan
|
12,
25
|
Trade
Secrets
|
13
|
Trademarks
|
13
|
Transfer
Taxes
|
13
|
|
|
By: /s/ William C. Glynn |
|
Name:
William C. Glynn
|
|
Title:
President
|
|
|
By: /s/ Vernon A. Raile |
|
Name:
Vernon A. Raile
|
|
Title:
Executive Vice President, Treasurer and Chief Financial
Officer
|
|
A.
|
Beneficiary
. “Beneficiary”
means the person or persons designated as such in accordance with Article
X.
|
|
B.
|
Change in
Control
. “Change in Control” means the earliest of the
following to occur: (a) any person (which shall not include the Company,
any subsidiary of the Company or any employee benefit plan of the Company
or of any subsidiary of the Company) ("Person") or group (as that term is
defined in Treasury Regulation Section 1.409A-3(i)(5)(v)(B)) acquires (or
has acquired during the 12-month period ending on the date of the most
recent acquisition by such Person or Persons) ownership of stock of the
Company possessing 30% or more of the total voting power of the stock of
the Company; (b) any Person or group (as that term is defined in Treasury
Regulation Section 1.409A-3(i)(5)(v)(B)) acquires ownership of the stock
of the Company that, together with stock held by such Person or group,
constitutes more than 50% of the total fair market value or total voting
power of the stock of the Company (this part (b) applies only when there
is a transfer of stock of the Company and the Company's stock remains
outstanding after the transaction); (c) a majority of the members of the
Board of Directors of the Company is replaced during any 12-month period
by directors whose appointment or election is not endorsed by a majority
of the members of the Board of Directors
of
the Company; or (d) any Person or group (as that term is defined in
Treasury Regulation Section 1.409A-3(i)(5)(v)(B)) acquires (or has
acquired during the 12-month period ending on the date of the most recent
acquisition by such Person or Persons) assets from the Company that have a
gross fair market value equal to or more than 40% of the total gross fair
market value of all of the assets of the Company immediately before such
acquisition or acquisitions.
|
|
C.
|
Code
. “Code”
means the Internal Revenue Code of 1986, as
amended.
|
|
D.
|
Compensation
. “Compensation”
means any cash retainer, meeting fees and any other cash compensation
payable to Eligible Directors by the Company for services as a
Director.
|
|
E.
|
Deferral
Amount
. “Deferral Amount” means the Compensation
Participants elect to defer and have credited to their Deferred
Compensation Accounts.
|
|
F.
|
Deferred Compensation
Account
. “Deferred Compensation Account” means the
account maintained on the books of account of the Company for each
Participant pursuant to Article VI.
|
|
G.
|
Disability
. “Disability”
means those circumstances where the Participant is unable to engage in any
substantial gainful activity by reason of any medically determinable
physical or mental impairment that can be expected to result in death or
can be expected to last for a continuous period of not less than twelve
(12) months.
|
|
H.
|
Effective
Date. “Effective Date” means May 15, 2008, the date on which
the amendment and restatement of the Plan became
effective.
|
|
I.
|
Eligible
Director
. “Eligible Director” means those Directors of
the Company who are not employees of the
Company.
|
|
J.
|
Investment
Units
. This term shall have the meaning defined in
Article VI.B.
|
|
K.
|
Market
Price
. “Market Price” means the average of the highest
and lowest transaction prices for the Company's common stock on the New
York Stock Exchange for a given
day.
|
|
L.
|
Participant
. “Participant”
means an Eligible Director participating in the Plan in accordance with
the provisions of Article IV.
|
|
M.
|
Separation from
Service
. “Separation from Service” means a Participant's
separation from service (as that term is used in Section 409A(a)(2)(A)(i)
of the Code) with the Company.
|
|
A.
|
Deferred Compensation
Accounts
. The Board of Directors shall establish and
maintain a separate Deferred Compensation Account for each
Participant. The Participant’s Deferral Amount shall be
credited to the Participant’s Deferred Compensation Account quarterly on
the last business day of March, June, September, and December in amounts
as nearly equal as possible.
|
|
B.
|
Conversion to
Investment Units
. At the time a Deferral Amount or
dividend equivalent under Article VII is credited to the Deferred
Compensation Account, it shall be converted to Investment Units, by
dividing the amount credited by the Market Price of the Company's stock on
the first trading day immediately preceding the date the amount is
credited. Fractional share Investment Units will be maintained
in the Account.
|
|
A.
|
Conversion of
Investment Units to Dollars
.
When a Participant
has a Separation from Service, dies, or experiences a Disability,
Investment Units in the Participant’s Deferred Compensation Account shall
be converted into dollars, on the dates set forth below, based on the
Market Price of the Company’s common stock on the date of
conversion. If the New York Stock Exchange is not open that
day, then it shall be the Market Price on the next day the New York Stock
Exchange is open. Participants shall remain eligible to receive
dividend equivalents pursuant to Article VII with respect to any
Investment Units that have not been converted into dollars as of the
dividend record date.
|
|
B.
|
Payment
. During
the first week (the “Payment Commencement Week”) of the first full month
that begins at least six months after the date of the Participant's
Separation from Service, death or Disability (the “Payment Commencement
Month”), 20 percent of the value of the Investment Units credited to
the Participant’s Deferred Compensation Account shall be converted to
dollars and paid to the Participant in equal monthly payments over a
one-year period, with the first such monthly payment made during the
Payment Commencement Week and the following monthly payments made during
the first week of each of the next 11 months. During the first
week of the 12
th
month following the Payment Commencement Month, 25 percent of the
remaining value of the Investment Units credited to the Participant's
Deferred Compensation Account shall be converted to dollars and paid to
the Participant in equal monthly payments over a one-year period, with the
first such monthly payment made during that week and the following monthly
payments made during the first week of each of the next 11
months. During the first week of the 24
th
month following the Payment Commencement Month, 33 1/3 percent of the
remaining value of the Investment Units credited to the Participant's
Deferred Compensation Account shall be converted to dollars and paid to
the Participant in equal monthly payments over a one-year period, with the
first such monthly payment made during that week and the following monthly
payments made during the first week of each of the next 11
months. During the first week of the 36
th
month following the Payment Commencement Month, 50 percent of the
remaining value of the Investment Units credited to the Participant's
Deferred Compensation Account shall be converted to dollars and paid to
the Participant in equal monthly payments over a one-year period, with the
first
such monthly payment made during that week and the following monthly
payments made during the first week of each of the next 11
months. During the first week of the 48
th
month following the Payment Commencement Month, the remaining balance of
the Participant's Deferred Compensation Account shall be converted to
dollars and paid to the Participant in equal monthly payments over a
one-year period, with the first such monthly payment made during that week
and the following monthly payments made during the first week of each of
the next 11 months. For avoidance of doubt, if a dividend is
paid on the common stock of the Company, an equivalent amount shall be
credited to Participants' Deferred Compensation Accounts pursuant to
Article VII with respect to any Investment Units that have not been
converted into dollars as of the dividend record date. No
interest will be paid on amounts in the Deferred Compensation
Accounts.
|
|
C.
|
Change in
Control
. The terms of this Article VIII.C shall
immediately become operative, without further action or consent by any
person or entity, upon a Change in Control, and once operative shall
supersede and take control over any other provisions of the
Plan.
|
|
Upon
a Change in Control, all Investment Units in a Participant's Deferred
Compensation Account shall be multiplied by the Market Price of the
Company's common stock on such day. If the New York Stock
Exchange is not open on that day, then it shall be the Market Price on the
next day the New York Stock Exchange is open. The dollar value
of the Investment Units contained in each Participant's Deferred
Compensation Account shall be paid out immediately thereafter to the
Participant (a “Change in Control
Payment”).
|
|
A.
|
Amendment
. The
Company may at any time amend the Plan in whole or in part, provided,
however, that except as provided in Article XI.B., no amendment shall act
to reduce the benefits under the Plan payable to any Participant with
respect to any Deferral Amount credited to the Participant's Deferred
Compensation Account prior to the date of the
amendment. Written notice of any amendments shall be given to
each Participant.
|
|
B.
|
Termination of
Plan
|
|
1.
|
Company's Right to
Terminate
. The Board of Directors may at any time
terminate the Plan.
|
|
2.
|
Payments Upon
Termination
. To the extent consistent with the rules
relating to plan terminations and liquidations in Treasury Regulation
Section 1.409A-3(j)(4)(ix) or otherwise consistent with Section 409A of
the Code, the Board of Directors may provide that, without the prior
written consent of Participants, the
Investment
Units recorded in the Participants' Deferred Compensation Accounts shall
be converted into dollars pursuant to Article VIII.A and all of the
Participants’ Deferred Compensation Accounts shall be distributed in a
lump sum upon (or as soon as is permitted following) termination of the
Plan. Unless so distributed, in the event of a Plan
termination, the Company shall continue to maintain the Deferred
Compensation Accounts until distributed pursuant to the terms of the Plan
and Participants shall remain 100% vested in all amounts credited to their
Deferred Compensation
Accounts.
|
|
A.
|
Unsecured General
Creditor
. Participants and their beneficiaries, heirs,
successors, and assigns shall have no legal or equitable rights,
interests, or other claims in any property or assets of the Company, nor
shall they be beneficiaries of, or have any rights, claims, or interests
in any specified assets of the Company. Any and all of the
Company's assets shall be and remain general, unpledged, unrestricted
assets of the Company. The Company's obligation under the Plan shall be
that of an unfunded and unsecured promise of Company to pay money in the
future.
|
|
B.
|
No Right to Nomination
or Reelection
. Establishment of this Plan and the
participation by any person shall not be construed to confer any right on
the part of such person to be nominated for reelection, or to be
reelected, to the Board of Directors of the
Company.
|
|
C.
|
Nonassignability
. Neither
a Participant nor any other person shall have any right to commute, sell,
assign, transfer, pledge, anticipate, mortgage, or otherwise encumber,
transfer, hypothecate, or convey in advance of actual receipt the amounts,
if any, payable hereunder, or any part thereof, which are, and all rights
to which are, expressly declared to be unassignable and
nontransferable. No part of the amounts payable shall, prior to
actual payment, be subject to seizure or sequestration for the payment of
any debts, judgments, alimony or separate maintenance owed by a
Participant or any other person, nor be transferable by operation of law
in the event of a Participant's or any other person's bankruptcy or
insolvency.
|
|
E.
|
Gender, Singular and
Plural
. Wherever the context so requires, words in the
masculine include the feminine and words in the feminine include the
masculine and the definition of any term in the singular may include the
plural.
|
|
F.
|
Captions
. The
captions to the articles, sections, and paragraphs of this Plan are for
convenience only and shall not control or affect the meaning or
construction of any of its
provisions.
|
|
G.
|
Applicable
Law
. This Plan shall be construed, administered and
governed in accordance with the laws of the State of North
Dakota.
|
|
H.
|
Validity
. In
the event any provision of this Plan is held invalid, void, or
unenforceable, the same shall not affect, in any respect whatsoever, the
validity of any other provision of this
Plan.
|
|
I.
|
Notice
. Any
notice or filing required or permitted to be given to the Board of
Directors shall be sufficient if in writing and hand delivered, or sent by
registered or certified mail, to the principal office of the Company,
directed to the attention of the Secretary of the Company. Such
notice shall be deemed given as of the date of delivery or, if delivery is
made by mail, as of the date shown on the postmark on the receipt for
registration or certification.
|
|
J.
|
Section
409A
. It is intended that this Plan will comply with
Section 409A of Code and any regulations and guidelines issued thereunder,
to the extent the Plan is subject thereto, and the Plan shall be
interpreted accordingly.
|
|
1.
|
General
liability and automobile liability
insurance:
|
|
2.
|
Fiduciary
and employee benefit liability
insurance:
|
|
3.
|
Aircraft
liability insurance:
|
|
4.
|
Travel
and sojourn insurance:
|
|
5.
|
Group
life insurance:
|
|
(a)
|
the
excess of (i) the Fair Market Value of a Share on the date of exercise
over (ii) the Base Value multiplied
by
|
|
(b)
|
the
number of Shares with respect to which the SAR is
exercised.
|
|
"The
sale or other transfer of the shares of stock represented by this
certificate, whether voluntary, involuntary or by operation of law, is
subject to certain restrictions on transfer as set forth in MDU Resources
Group, Inc. Non-Employee Director Long-Term Incentive Compensation Plan,
and in a Restricted Stock Award Agreement. A copy of such Plan
and such Agreement may be obtained from MDU Resources Group,
Inc."
|
|
(a)
|
Any
and all Options and SARs granted hereunder shall become immediately
exercisable;
|
|
(b)
|
Any
restriction periods and restrictions imposed on Restricted Stock or Awards
granted pursuant to Article 10 (if not performance-based) shall be deemed
to have expired and such Restricted Stock or Awards shall become
immediately vested in full; and
|
|
(c)
|
The
target payout opportunity attainable under all outstanding Awards of
Performance Units, Performance Shares and Awards granted pursuant to
Article 10 (if performance-based) shall be deemed to have been fully
earned for the entire Performance Period(s) as of the effective date of
the Change in Control, and shall be paid out promptly in Shares or cash
pursuant to the terms of the Award Agreement, or in the absence of such
designation, as the Committee shall
determine.
|
Twelve
Months Ended
June 30, 2008
|
Year
Ended
December 31, 2007
|
|||||||
(In
thousands of dollars)
|
||||||||
Earnings
Available for Fixed Charges:
|
||||||||
Net
Income (a)
|
$ | 371,331 | $ | 308,288 | ||||
Income
Taxes
|
225,322 | 190,024 | ||||||
596,653 | 498,312 | |||||||
Rents
(b)
|
11,348 | 11,947 | ||||||
Interest
(c)
|
79,746 | 76,248 | ||||||
Total
Earnings Available for Fixed Charges
|
$ | 687,747 | $ | 586,507 | ||||
Preferred
Dividend Requirements
|
$ | 685 | $ | 685 | ||||
Ratio
of Income Before Income Taxes to Net Income
|
161 | % | 159 | % | ||||
Preferred
Dividend Factor on Pretax Basis
|
1,103 | 1,089 | ||||||
Fixed
Charges (d)
|
93,717 | 90,545 | ||||||
Combined
Fixed Charges and Preferred Stock Dividends
|
$ | 94,820 | $ | 91,634 | ||||
Ratio
of Earnings to Fixed Charges
|
7.3 | x | 6.5 | x | ||||
Ratio
of Earnings to Combined Fixed Charges and Preferred Stock
Dividends
|
7.3 | x | 6.4 | x |
(a)
|
Net
income excludes undistributed income for equity
investees.
|
(b)
|
Represents
interest portion of rents estimated at 33
1/3%.
|
(c)
|
Represents
interest, amortization of debt discount and expense on all indebtedness
and amortization of interest capitalized, and excludes amortization of
gains or losses on reacquired debt (which, under the Federal Energy
Regulatory Commission Uniform System of Accounts, is classified as a
reduction of, or increase in, interest expense in the Consolidated
Statements of Income) and interest
capitalized.
|
(d)
|
Represents
rents (as defined above), interest, amortization of debt discount and
expense on all indebtedness, and excludes amortization of gains or losses
on reacquired debt (which, under the Federal Energy Regulatory Commission
Uniform System of Accounts, is classified as a reduction of, or increase
in, interest expense in the Consolidated Statements of
Income).
|
|
1.
|
I
have reviewed this quarterly report on Form 10-Q of MDU Resources Group,
Inc.;
|
|
2.
|
Based
on my knowledge, this report does not contain any untrue statement of a
material fact or omit to state a material fact necessary to make the
statements made, in light of the circumstances under which such statements
were made, not misleading with respect to the period covered by this
report;
|
|
3.
|
Based
on my knowledge, the financial statements, and other financial information
included in this report, fairly present in all material respects the
financial condition, results of operations and cash flows of the
registrant as of, and for, the periods presented in this
report;
|
|
4.
|
The
registrant's other certifying officer and I are responsible for
establishing and maintaining disclosure controls and procedures (as
defined in Exchange Act Rules 13a-15(e) and 15d-15(e))
and
internal control over financial reporting (as defined in Exchange Act
Rules 13a-15(f) and 15d-15(f)) for the registrant and
have:
|
|
5.
|
The
registrant's other certifying officer and I have disclosed, based on our
most recent evaluation of internal control over financial reporting, to
the registrant's auditors and the audit committee of the registrant's
board of directors (or persons performing the equivalent
functions):
|
|
1.
|
I
have reviewed this quarterly report on Form 10-Q of MDU Resources Group,
Inc.;
|
|
2.
|
Based
on my knowledge, this report does not contain any untrue statement of a
material fact or omit to state a material fact necessary to make the
statements made, in light of the circumstances under which such statements
were made, not misleading with respect to the period covered by this
report;
|
|
3.
|
Based
on my knowledge, the financial statements, and other financial information
included in this report, fairly present in all material respects the
financial condition, results of operations and cash flows of the
registrant as of, and for, the periods presented in this
report;
|
|
4.
|
The
registrant's other certifying officer and I are responsible for
establishing and maintaining disclosure controls and procedures (as
defined in Exchange Act Rules 13a-15(e) and 15d-15(e))
and
internal control over financial reporting (as defined in Exchange Act
Rules 13a-15(f) and 15d-15(f)) for the registrant and
have:
|
|
(a)
Designed such disclosure controls and procedures, or caused such
disclosure controls and procedures to be designed under our supervision,
to ensure that material information relating to the registrant, including
its consolidated subsidiaries, is made known to us by others within those
entities, particularly during the period in which this report is being
prepared;
|
|
(b)
Designed such internal control over financial reporting, or caused such
internal control over financial reporting to be designed under our
supervision, to provide reasonable assurance regarding the reliability of
financial reporting and the preparation of financial statements for
external purposes in accordance with generally accepted accounting
principles;
|
|
(c)
Evaluated the effectiveness of the registrant's disclosure controls and
procedures and presented in this report our conclusions about the
effectiveness of the disclosure controls and procedures, as of the end of
the period covered by this report based on such evaluation;
and
|
|
(d)
Disclosed in this report any change in the registrant's internal control
over financial reporting that occurred during the registrant's most recent
fiscal quarter (the registrant's fourth fiscal quarter in the case of an
annual report) that has materially affected, or is reasonably likely to
materially affect, the registrant's internal control over financial
reporting; and
|
|
5.
|
The
registrant's other certifying officer and I have disclosed, based on our
most recent evaluation of internal control over financial reporting, to
the registrant's auditors and the audit committee of the registrant's
board of directors (or persons performing the equivalent
functions):
|
|
(a)
All significant deficiencies and material weaknesses in the design or
operation of internal control over financial reporting which are
reasonably likely to adversely affect the registrant's ability to record,
process, summarize and report financial information;
and
|
|
(b)
Any fraud, whether or not material, that involves management or other
employees who have a significant role in the registrant's internal control
over financial reporting.
|