10-Q

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

ý	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF
	THE SECURITIES EXCHANGE ACT OF 1934

For The Quarterly Period Ended June 30, 2014

OR

o	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF
	THE SECURITIES EXCHANGE ACT OF 1934

For the Transition Period from _____________ to ______________

Commission file number 1-3480

MDU Resources Group, Inc.

(Exact name of registrant as specified in its charter)

Delaware	41-0423660
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

1200 West Century Avenue

P.O. Box 5650

Bismarck, North Dakota 58506-5650

(Address of principal executive offices)

(Zip Code)

(701) 530-1000

(Registrant's telephone number, including area code)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ý No o.

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes ý No o.

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definition of "large accelerated filer," "accelerated filer" and "smaller reporting company" in Rule 12b-2 of the Exchange Act (Check one):

Large accelerated filer ý	Accelerated filer o
Non-accelerated filer o	Smaller reporting company o

(Do not check if a smaller reporting company)

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes o No ý.

Indicate the number of shares outstanding of each of the issuer's classes of common stock, as of August 1, 2014: 193,946,489 shares.

DEFINITIONS

The following abbreviations and acronyms used in this Form 10-Q are defined below:

Abbreviation or Acronym
2013 Annual Report	Company's Annual Report on Form 10-K for the year ended December 31, 2013
ASC	FASB Accounting Standards Codification
Bbl	Barrel
Bicent	Bicent Power LLC
Big Stone Station	475-MW coal-fired electric generating facility near Big Stone City, South Dakota (22.7 percent ownership)
BLM	Bureau of Land Management
BOE	One barrel of oil equivalent - determined using the ratio of one barrel of crude oil, condensate or natural gas liquids to six Mcf of natural gas
BOPD	Barrels of oil per day
Brazilian Transmission Lines	Company's investment in the company owning ECTE, ENTE and ERTE (ownership interests in ENTE and ERTE were sold in the fourth quarter of 2010 and portions of the ownership interest in ECTE were sold in the third quarters of 2013 and 2012 and the fourth quarters of 2011 and 2010)
Btu	British thermal unit
California Superior Court	Superior Court of the State of California, County of Los Angeles (South District - Long Beach)
Calumet	Calumet Specialty Products Partners, L.P.
Cascade	Cascade Natural Gas Corporation, an indirect wholly owned subsidiary of MDU Energy Capital
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 Resources	Centennial Energy Resources LLC, a direct wholly owned subsidiary of Centennial
Colorado State District Court	Colorado Thirteenth Judicial District Court, Yuma County
Company	MDU Resources Group, Inc.
Connolly-Pacific	Connolly-Pacific Co., an indirect wholly owned subsidiary of Knife River
Coyote Creek	Coyote Creek Mining Company, LLC, a subsidiary of The North American Coal Corporation
Coyote Station	427-MW coal-fired electric generating facility near Beulah, North Dakota (25 percent ownership)
Dakota Prairie Refinery	20,000-barrel-per-day diesel topping plant being built by Dakota Prairie Refining in southwestern North Dakota
Dakota Prairie Refining	Dakota Prairie Refining, LLC, a limited liability company jointly owned by WBI Energy and Calumet
dk	Decatherm
Dodd-Frank Act	Dodd-Frank Wall Street Reform and Consumer Protection Act
EBITDA	Earnings before interest, taxes, depreciation, depletion and amortization
ECTE	Empresa Catarinense de Transmissão de Energia S.A. (2.5 percent ownership interest at June 30, 2014, 2.5, 2.5, 2.5 and 14.99 percent ownership interests were sold in the third quarters of 2013 and 2012 and the fourth quarters of 2011 and 2010, respectively)
ENTE	Empresa Norte de Transmissão de Energia S.A. (entire 13.3 percent ownership interest sold in the fourth quarter of 2010)
EPA	U.S. Environmental Protection Agency
ERTE	Empresa Regional de Transmissão de Energia S.A. (entire 13.3 percent ownership interest sold in the fourth quarter of 2010)
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
GAAP	Accounting principles generally accepted in the United States of America
GHG	Greenhouse gas
Great Plains	Great Plains Natural Gas Co., a public utility division of the Company
Intermountain	Intermountain Gas Company, an indirect wholly owned subsidiary of MDU Energy Capital

2

JTL	JTL Group, Inc., an indirect wholly owned subsidiary of Knife River
Knife River	Knife River Corporation, a direct wholly owned subsidiary of Centennial
Knife River - Northwest	Knife River Corporation - Northwest, an indirect wholly owned subsidiary of Knife River
kWh	Kilowatt-hour
LPP	Lea Power Partners, LLC, a former indirect wholly owned subsidiary of Centennial Resources (member interests were sold in October 2006)
LWG	Lower Willamette Group
MBbls	Thousands of barrels
MBOE	Thousands of BOE
Mcf	Thousand cubic feet
MDU Brasil	MDU Brasil Ltda., an indirect wholly owned subsidiary of Centennial Resources
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
MISO	Midcontinent Independent System Operator, Inc.
MMBbls	Millions of barrels
MMBtu	Million Btu
MMcf	Million cubic feet
MMdk	Million decatherms
Montana-Dakota	Montana-Dakota Utilities Co., a public utility division of the Company
Montana DEQ	Montana Department of Environmental Quality
Montana First Judicial District Court	Montana First Judicial District Court, Lewis and Clark County
Montana Seventeenth Judicial District Court	Montana Seventeenth Judicial District Court, Phillips County
MW	Megawatt
NDPSC	North Dakota Public Service Commission
New York Supreme Court	Supreme Court of the State of New York, County of New York
NGL	Natural gas liquids
NSPS	New Source Performance Standards
Oil	Includes crude oil and condensate
Omimex	Omimex Canada, Ltd.
OPUC	Oregon Public Utility Commission
Oregon DEQ	Oregon State Department of Environmental Quality
Prairielands	Prairielands Energy Marketing, Inc., an indirect wholly owned subsidiary of WBI Holdings
PRP	Potentially Responsible Party
RCRA	Resource Conservation and Recovery Act
ROD	Record of Decision
SEC	U.S. Securities and Exchange Commission
Securities Act	Securities Act of 1933, as amended
SourceGas	SourceGas Distribution LLC
VIE	Variable interest entity
WBI Energy	WBI Energy, Inc., an indirect wholly owned subsidiary of WBI Holdings
WBI Energy Midstream	WBI Energy Midstream, LLC, an indirect wholly owned subsidiary of WBI Holdings
WBI Energy Transmission	WBI Energy Transmission, Inc., an indirect wholly owned subsidiary of WBI Holdings
WBI Holdings	WBI Holdings, Inc., a direct wholly owned subsidiary of Centennial
WUTC	Washington Utilities and Transportation Commission

3

INTRODUCTION

The Company is a diversified natural resource company, which was incorporated under the laws of the state of Delaware in 1924. Its principal executive offices are at 1200 West Century Avenue, P.O. Box 5650, Bismarck, North Dakota 58506-5650, telephone (701) 530-1000.

Montana-Dakota, through the electric and natural gas distribution segments, generates, transmits and distributes electricity and distributes natural gas in Montana, North Dakota, South Dakota and Wyoming. Cascade distributes natural gas in Oregon and Washington. Intermountain distributes natural gas in Idaho. Great Plains distributes natural gas in western Minnesota and southeastern North Dakota. These operations also supply related value-added services.

The Company, through its wholly owned subsidiary, Centennial, owns WBI Holdings (comprised of the pipeline and energy services and the exploration and production segments), Knife River (construction materials and contracting segment), MDU Construction Services (construction services segment), Centennial Resources and Centennial Capital (both reflected in the Other category). For more information on the Company's business segments, see Note 18.

4

INDEX

Part I -- Financial Information	Page
Consolidated Statements of Income -- Three and Six Months Ended June 30, 2014 and 2013	6
Consolidated Statements of Comprehensive Income -- Three and Six Months Ended June 30, 2014 and 2013	7
Consolidated Balance Sheets -- June 30, 2014 and 2013, and December 31, 2013	8
Consolidated Statements of Cash Flows -- Six Months Ended June 30, 2014 and 2013	9
Notes to Consolidated Financial Statements	10
Management's Discussion and Analysis of Financial Condition and Results of Operations	32
Quantitative and Qualitative Disclosures About Market Risk	49
Controls and Procedures	50
Part II -- Other Information
Legal Proceedings	50
Risk Factors	51
Mine Safety Disclosures	53
Exhibits	53
Signatures	54
Exhibit Index	55
Exhibits

5

PART I -- FINANCIAL INFORMATION

ITEM 1.  FINANCIAL STATEMENTS

MDU RESOURCES GROUP, INC.

CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2014			2013			2014			2013
	(In thousands, except per share amounts)
Operating revenues:
Electric, natural gas distribution and pipeline and energy services	$	254,689		$	227,442		$	746,231		$	651,565
Exploration and production, construction materials and contracting, construction services and other	839,357			833,153			1,390,668			1,340,633
Total operating revenues	1,094,046			1,060,595			2,136,899			1,992,198
Operating expenses:
Fuel and purchased power	21,046			18,169			47,590			39,777
Purchased natural gas sold	84,415			70,255			329,307			269,442
Operation and maintenance:
Electric, natural gas distribution and pipeline and energy services	61,764			76,627			129,047			142,730
Exploration and production, construction materials and contracting, construction services and other	675,330			661,495			1,121,282			1,055,511
Depreciation, depletion and amortization	103,126			95,289			202,683			188,850
Taxes, other than income	49,431			47,382			105,152			99,979
Total operating expenses	995,112			969,217			1,935,061			1,796,289
Operating income	98,934			91,378			201,838			195,909
Loss from equity method investments	(297		)	(7		)	(245		)	(319		)
Other income	2,777			1,436			4,908			2,677
Interest expense	21,516			21,427			42,487			42,300
Income before income taxes	79,898			71,380			164,014			155,967
Income taxes	27,118			24,988			55,050			52,983
Income from continuing operations	52,780			46,392			108,964			102,984
Income (loss) from discontinued operations, net of tax (Note 11)	547			(59		)	502			(136		)
Net income	53,327			46,333			109,466			102,848
Net loss attributable to noncontrolling interest	(779		)	(179		)	(1,302		)	(179		)
Dividends declared on preferred stocks	171			171			342			342
Earnings on common stock	$	53,935		$	46,341		$	110,426		$	102,685
Earnings per common share - basic:
Earnings before discontinued operations	$	.28		$	.25		$	.58		$	.54
Discontinued operations, net of tax	—			—			—			—
Earnings per common share - basic	$	.28		$	.25		$	.58		$	.54
Earnings per common share - diluted:
Earnings before discontinued operations	$	.28		$	.24		$	.58		$	.54
Discontinued operations, net of tax	—			—			—			—
Earnings per common share - diluted	$	.28		$	.24		$	.58		$	.54
Dividends declared per common share	$	.1775		$	.1725		$	.3550		$	.3450
Weighted average common shares outstanding - basic	192,060			188,831			190,946			188,831
Weighted average common shares outstanding - diluted	192,659			189,463			191,543			189,460

The accompanying notes are an integral part of these consolidated financial statements.

6

MDU RESOURCES GROUP, INC.

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2014			2013			2014			2013
	(In thousands)
Net income	$	53,327		$	46,333		$	109,466		$	102,848
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 $0 and $52 for the three months ended and $0 and $(3,116) for the six months ended in 2014 and 2013, respectively	—			254			—			(5,594		)
Reclassification adjustment for (gain) loss on derivative instruments included in net income, net of tax of $10 and $(322) for the three months ended and $213 and $(1,948) for the six months ended in 2014 and 2013, respectively	13			(395		)	357			(3,168		)
Net unrealized gain (loss) on derivative instruments qualifying as hedges	13			(141		)	357			(8,762		)
Amortization of postretirement liability losses included in net periodic benefit cost, net of tax of $150 and $543 for the three months ended and $318 and $862 for the six months ended in 2014 and 2013, respectively	245			424			520			1,072
Foreign currency translation adjustment recognized during the period, net of tax of $26 and $(234) for the three months ended and $54 and $(197) for the six months ended in 2014 and 2013, respectively	42			(390		)	88			(302		)
Net unrealized gain (loss) on available-for-sale investments:
Net unrealized gain (loss) on available-for-sale investments arising during the period, net of tax of $4 and $(77) for the three months ended and $5 and $(100) for the six months ended in 2014 and 2013, respectively	8			(142		)	10			(187		)
Reclassification adjustment for loss on available-for-sale investments included in net income, net of tax of $17 and $23 for the three months ended and $17 and $42 for the six months ended in 2014 and 2013, respectively	32			43			32			79
Net unrealized gain (loss) on available-for-sale investments	40			(99		)	42			(108		)
Other comprehensive income (loss)	340			(206		)	1,007			(8,100		)
Comprehensive income	53,667			46,127			110,473			94,748
Comprehensive loss attributable to noncontrolling interest	(779		)	(179		)	(1,302		)	(179		)
Comprehensive income attributable to common stockholders	$	54,446		$	46,306		$	111,775		$	94,927

The accompanying notes are an integral part of these consolidated financial statements.

7

MDU RESOURCES GROUP, INC.

CONSOLIDATED BALANCE SHEETS

(Unaudited)

	June 30, 2014			June 30, 2013			December 31, 2013
(In thousands, except shares and per share amounts)
ASSETS
Current assets:
Cash and cash equivalents	$	90,318		$	114,971		$	45,225
Receivables, net	731,247			734,765			713,067
Inventories	331,422			345,885			282,391
Deferred income taxes	29,110			27,959			25,048
Commodity derivative instruments	129			9,797			1,447
Prepayments and other current assets	93,980			58,870			49,510
Total current assets	1,276,206			1,292,247			1,116,688
Investments	116,594			106,508			112,939
Property, plant and equipment	9,390,538			8,454,204			8,803,866
Less accumulated depreciation, depletion and amortization	4,011,858			3,709,679			3,872,487
Net property, plant and equipment	5,378,680			4,744,525			4,931,379
Deferred charges and other assets:
Goodwill	636,039			636,039			636,039
Other intangible assets, net	11,266			15,312			13,099
Other	249,532			297,040			251,188
Total deferred charges and other assets	896,837			948,391			900,326
Total assets	$	7,668,317		$	7,091,671		$	7,061,332
LIABILITIES AND EQUITY
Current liabilities:
Short-term borrowings	$	—		$	31,600		$	11,500
Long-term debt due within one year	42,215			69,091			12,277
Accounts payable	424,201			411,621			404,961
Taxes payable	48,985			89,896			74,175
Dividends payable	34,388			32,745			33,737
Accrued compensation	50,024			44,159			69,661
Commodity derivative instruments	17,449			1,388			7,483
Other accrued liabilities	179,402			185,389			171,106
Total current liabilities	796,664			865,889			784,900
Long-term debt	2,144,879			1,937,663			1,842,286
Deferred credits and other liabilities:
Deferred income taxes	925,813			782,838			859,306
Other liabilities	736,519			810,639			718,938
Total deferred credits and other liabilities	1,662,332			1,593,477			1,578,244
Commitments and contingencies
Equity:
Preferred stocks	15,000			15,000			15,000
Common stockholders' equity:
Common stock
Authorized - 500,000,000 shares, $1.00 par value
Shares issued - 194,138,654 at June 30, 2014, 189,369,450 at June 30, 2013 and 189,868,780 at December 31, 2013	194,139			189,369			189,869
Other paid-in capital	1,186,900			1,040,379			1,056,996
Retained earnings	1,645,291			1,494,419			1,603,130
Accumulated other comprehensive loss	(37,198		)	(56,821		)	(38,205		)
Treasury stock at cost - 538,921 shares	(3,626		)	(3,626		)	(3,626		)
Total common stockholders' equity	2,985,506			2,663,720			2,808,164
Total stockholders' equity	3,000,506			2,678,720			2,823,164
Noncontrolling interest	63,936			15,922			32,738
Total equity	3,064,442			2,694,642			2,855,902
Total liabilities and equity	$	7,668,317		$	7,091,671		$	7,061,332

The accompanying notes are an integral part of these consolidated financial statements.

8

MDU RESOURCES GROUP, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Six Months Ended
	June 30,
	2014			2013
	(In thousands)
Operating activities:
Net income	$	109,466		$	102,848
Income (loss) from discontinued operations, net of tax	502			(136		)
Income from continuing operations	108,964			102,984
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	202,683			188,850
Loss, net of distributions, from equity method investments	245			1,491
Deferred income taxes	60,141			19,790
Unrealized (gain) loss on commodity derivatives	11,908			(7,215		)
Excess tax benefit on stock-based compensation	(4,729		)	—
Changes in current assets and liabilities, net of acquisitions:
Receivables	(8,501		)	(65,637		)
Inventories	(48,857		)	(29,923		)
Other current assets	(37,460		)	(18,044		)
Accounts payable	(23,277		)	18,940
Other current liabilities	(36,447		)	23,071
Other noncurrent changes	(13,638		)	(741		)
Net cash provided by continuing operations	211,032			233,566
Net cash provided by (used in) discontinued operations	(491		)	360
Net cash provided by operating activities	210,541			233,926
Investing activities:
Capital expenditures	(390,126		)	(431,439		)
Acquisitions, net of cash acquired	(206,304		)	—
Net proceeds from sale or disposition of property and other	11,917			20,884
Investments	(1,208		)	16
Net cash used in continuing operations	(585,721		)	(410,539		)
Net cash provided by discontinued operations	—			—
Net cash used in investing activities	(585,721		)	(410,539		)
Financing activities:
Issuance of short-term borrowings	—			29,600
Repayment of short-term borrowings	(11,500		)	—
Issuance of long-term debt	441,447			450,461
Repayment of long-term debt	(111,539		)	(214,473		)
Proceeds from issuance of common stock	132,268			—
Dividends paid	(67,717		)	(32,915		)
Excess tax benefit on stock-based compensation	4,729			—
Contribution from noncontrolling interest	32,500			10,000
Net cash provided by continuing operations	420,188			242,673
Net cash provided by discontinued operations	—			—
Net cash provided by financing activities	420,188			242,673
Effect of exchange rate changes on cash and cash equivalents	85			(131		)
Increase in cash and cash equivalents	45,093			65,929
Cash and cash equivalents -- beginning of year	45,225			49,042
Cash and cash equivalents -- end of period	$	90,318		$	114,971

The accompanying notes are an integral part of these consolidated financial statements.

9

MDU RESOURCES GROUP, INC.

NOTES TO CONSOLIDATED

FINANCIAL STATEMENTS

June 30, 2014 and 2013

(Unaudited)

Note 1 - Basis of presentation

The accompanying consolidated interim financial statements were prepared in conformity with the basis of presentation reflected in the consolidated financial statements included in the Company's 2013 Annual Report, and the standards of accounting measurement set forth in the interim reporting guidance in the ASC and any amendments thereto adopted by the FASB. Interim financial statements do not include all disclosures provided in annual financial statements and, accordingly, these financial statements should be read in conjunction with those appearing in the 2013 Annual Report. The information is unaudited but includes all adjustments that are, in the opinion of management, necessary for a fair presentation of the accompanying consolidated interim financial statements and are of a normal recurring nature. Depreciation, depletion and amortization expense is reported separately on the Consolidated Statements of Income and therefore is excluded from the other line items within operating expenses. Management has also evaluated the impact of events occurring after June 30, 2014, up to the date of issuance of these consolidated interim financial statements.

Note 2 - Seasonality of operations

Some of the Company's operations are highly seasonal and revenues from, and certain expenses for, such operations may fluctuate significantly among quarterly periods. Accordingly, the interim results for particular businesses, and for the Company as a whole, may not be indicative of results for the full fiscal year.

Note 3 - Accounts receivable and allowance for doubtful accounts

Accounts receivable consist primarily of trade receivables from the sale of goods and services which are recorded at the invoiced amount net of allowance for doubtful accounts, and costs and estimated earnings in excess of billings on uncompleted contracts. The total balance of receivables past due 90 days or more was $29.6 million, $35.1 million and $36.4 million at June 30, 2014 and 2013, and December 31, 2013, respectively.

The allowance for doubtful accounts is determined through a review of past due balances and other specific account data. Account balances are written off when management determines the amounts to be uncollectible. The Company's allowance for doubtful accounts at June 30, 2014 and 2013, and December 31, 2013, was $9.6 million, $10.6 million and $10.1 million, respectively.

Note 4 - Inventories and natural gas in storage

Inventories, other than natural gas in storage for the Company's regulated operations, are stated at the lower of average cost or market value. Natural gas in storage for the Company's regulated operations is generally carried at average cost, or cost using the last-in, first-out method. The portion of the cost of natural gas in storage expected to be used within one year is included in inventories. Inventories consisted of:

	June 30, 2014		June 30, 2013		December 31, 2013
	(In thousands)
Aggregates held for resale	$	112,129	$	103,503	$	101,568
Asphalt oil	76,525		91,837		38,099
Materials and supplies	70,938		74,648		69,808
Merchandise for resale	25,507		27,330		21,720
Natural gas in storage (current)	10,903		14,287		16,417
Other	35,420		34,280		34,779
Total	$	331,422	$	345,885	$	282,391

The remainder of natural gas in storage, which largely represents the cost of gas required to maintain pressure levels for normal operating purposes, is included in other assets and was $47.4 million, $48.6 million and $48.3 million at June 30, 2014 and 2013, and December 31, 2013, respectively.

10

Note 5 - Impairment of long-lived assets

During the second quarter of 2013, the Company recognized an impairment of coalbed natural gas gathering assets at the pipeline and energy services segment of $14.5 million ($9.0 million after tax), which is recorded in operation and maintenance expense on the Consolidated Statements of Income. The impairment is related to coalbed natural gas gathering assets located in Wyoming and Montana where there has been a significant decline in natural gas development and production activity largely due to low natural gas prices. The coalbed natural gas gathering assets were written down to fair value that was determined using the income approach. For more information on this nonrecurring fair value measurement, see Note 15.

Note 6 - Earnings per common share

Basic earnings per common share were computed by dividing earnings on common stock by the weighted average number of shares of common stock outstanding during the applicable period. Diluted earnings per common share were computed by dividing earnings on common stock by the total of the weighted average number of shares of common stock outstanding during the applicable period, plus the effect of outstanding performance share awards. Common stock outstanding includes issued shares less shares held in treasury. Net income was the same for both the basic and diluted earnings per share calculations. A reconciliation of the weighted average common shares outstanding used in the basic and diluted earnings per share calculations was as follows:

	Three Months Ended		Six Months Ended
	June 30,		June 30,
	2014	2013	2014	2013
	(In thousands)
Weighted average common shares outstanding - basic	192,060	188,831	190,946	188,831
Effect of dilutive performance share awards	599	632	597	629
Weighted average common shares outstanding - diluted	192,659	189,463	191,543	189,460
Shares excluded from the calculation of diluted earnings per share	—	—	—	—

Note 7 - Cash flow information

Cash expenditures for interest and income taxes were as follows:

	Six Months Ended
	June 30,
	2014		2013
	(In thousands)
Interest, net of amount capitalized	$	39,441	$	41,440
Income taxes paid (refunded), net	$	39,984	$	(2,649	)

Noncash investing transactions were as follows:

	June 30,
	2014		2013
	(In thousands)
Property, plant and equipment additions in accounts payable	$	95,833	$	77,073

Note 8 - New Accounting Standard

Revenue from Contracts with Customers In May 2014, the FASB issued guidance on accounting for revenue from contracts with customers. The guidance provides for a single comprehensive model for entities to use in accounting for revenue arising from contracts with customers and supersedes most current revenue recognition guidance, including industry specific guidance. This guidance will be effective for the Company on January 1, 2017. Entities will have the option of using either a full retrospective or modified retrospective approach to adopting the guidance. Under the modified approach, an entity would recognize the cumulative effect of initially applying the guidance with an adjustment to the opening balance of retained earnings in the period of adoption. In addition, the modified approach will require additional disclosures. The Company is evaluating the effects the adoption of the new revenue guidance will have on its results of operations, financial position, cash flows and disclosures, as well as its method of adoption.

11

Note 9 - Comprehensive income (loss)

The after-tax changes in the components of accumulated other comprehensive loss were as follows:

Three Months Ended June 30, 2014	Net Unrealized Gain (Loss) on Derivative  Instruments  Qualifying as Hedges			Postretirement  Liability Adjustment			Foreign Currency Translation Adjustment			Net Unrealized Gain (Loss) on Available-for-sale Investments		Total Accumulated  Other Comprehensive  Loss
	(In thousands)
Balance at beginning of period	$	(3,421	)	$	(33,532	)	$	(621	)	$	36	$	(37,538	)
Other comprehensive income (loss) before reclassifications	—			—			42			8		50
Amounts reclassified from accumulated other comprehensive loss	13			245			—			32		290
Net current-period other comprehensive income	13			245			42			40		340
Balance at end of period	$	(3,408	)	$	(33,287	)	$	(579	)	$	76	$	(37,198	)

Three Months Ended June 30, 2013	Net Unrealized Gain (Loss) on Derivative  Instruments  Qualifying as Hedges			Postretirement  Liability Adjustment			Foreign Currency Translation Adjustment			Net Unrealized Gain (Loss) on Available-for-sale Investments			Total Accumulated  Other Comprehensive  Loss
	(In thousands)
Balance at beginning of period	$	(2,603	)	$	(53,699	)	$	(423	)	$	110		$	(56,615	)
Other comprehensive income (loss) before reclassifications	254			—			(390		)	(142		)	(278		)
Amounts reclassified from accumulated other comprehensive loss	(395		)	424			—			43			72
Net current-period other comprehensive income (loss)	(141		)	424			(390		)	(99		)	(206		)
Balance at end of period	$	(2,744	)	$	(53,275	)	$	(813	)	$	11		$	(56,821	)

Six Months Ended June 30, 2014	Net Unrealized Gain (Loss) on Derivative  Instruments  Qualifying as Hedges			Postretirement  Liability Adjustment			Foreign Currency Translation Adjustment			Net Unrealized Gain (Loss) on Available-for-sale Investments		Total Accumulated  Other Comprehensive  Loss
	(In thousands)
Balance at beginning of period	$	(3,765	)	$	(33,807	)	$	(667	)	$	34	$	(38,205	)
Other comprehensive income (loss) before reclassifications	—			—			88			10		98
Amounts reclassified from accumulated other comprehensive loss	357			520			—			32		909
Net current-period other comprehensive income	357			520			88			42		1,007
Balance at end of period	$	(3,408	)	$	(33,287	)	$	(579	)	$	76	$	(37,198	)

12

Six Months Ended June 30, 2013	Net Unrealized Gain (Loss) on Derivative  Instruments  Qualifying as Hedges			Postretirement  Liability Adjustment			Foreign Currency Translation Adjustment			Net Unrealized Gain (Loss) on Available-for-sale Investments			Total Accumulated  Other Comprehensive  Loss
	(In thousands)
Balance at beginning of period	$	6,018		$	(54,347	)	$	(511	)	$	119		$	(48,721	)
Other comprehensive income (loss) before reclassifications	(5,594		)	—			(302		)	(187		)	(6,083		)
Amounts reclassified from accumulated other comprehensive loss	(3,168		)	1,072			—			79			(2,017		)
Net current-period other comprehensive income (loss)	(8,762		)	1,072			(302		)	(108		)	(8,100		)
Balance at end of period	$	(2,744	)	$	(53,275	)	$	(813	)	$	11		$	(56,821	)

Reclassifications out of accumulated other comprehensive loss were as follows:

	Three Months Ended						Six Months Ended						Location on Consolidated Statements of Income
	June 30,						June 30,
	2014			2013			2014			2013
	(In thousands)
Reclassification adjustment for gain (loss) on derivative instruments included in net income:
Commodity derivative instruments	$	137		$	1,381		$	(250	)	$	5,896		Operating revenues
Interest rate derivative instruments	(160		)	(664		)	(320		)	(780		)	Interest expense
	(23		)	717			(570		)	5,116
	10			(322		)	213			(1,948		)	Income taxes
	(13		)	395			(357		)	3,168
Amortization of postretirement liability losses included in net periodic benefit cost	(395		)	(967		)	(838		)	(1,934		)	(a)
	150			543			318			862			Income taxes
	(245		)	(424		)	(520		)	(1,072		)
Reclassification adjustment for loss on available-for-sale investments included in net income	(49		)	(66		)	(49		)	(121		)	Other income
	17			23			17			42			Income taxes
	(32		)	(43		)	(32		)	(79		)
Total reclassifications	$	(290	)	$	(72	)	$	(909	)	$	2,017

(a) Included in net periodic benefit cost (credit). For more information, see Note 19.

Note 10 - Acquisition

On February 10, 2014, the Company entered into agreements to purchase working interests and leasehold positions in oil and natural gas production assets in the southern Powder River Basin of Wyoming. The effective date of the acquisition was October 1, 2013, and the closing occurred on March 6, 2014. The purchase price was $206.3 million, including purchase price adjustments.

The acquisition was accounted for under the acquisition method of accounting and, accordingly, the acquired assets and liabilities assumed have been recorded at their respective fair values as of the date of acquisition. The results of operations of the acquired properties are included in the financial statements since the date of the acquisition. Pro forma financial amounts reflecting the effects of the acquisition are not presented, as such acquisition was not material to the Company's financial position or results of operations.

Note 11 - Discontinued operations

In 2007, Centennial Resources sold CEM to Bicent. In connection with the sale, Centennial Resources agreed to indemnify Bicent and its affiliates from certain third party claims arising out of or in connection with Centennial Resources' ownership or

13

operation of CEM prior to the sale. In addition, Centennial had previously guaranteed CEM's obligations under a construction contract. The Company incurs legal expenses and had a benefit related to the resolution of this matter in the second quarter of 2014, which are reflected in discontinued operations in the consolidated financial statements and accompanying notes. Discontinued operations are included in the Other category. For more information, see Note 21.

Note 12 - Equity method investments

Investments in companies in which the Company has the ability to exercise significant influence over operating and financial policies are accounted for using the equity method. At June 30, 2014, the Company had no significant equity method investments.

In August 2006, MDU Brasil acquired ownership interests in the Brazilian Transmission Lines. The electric transmission lines are primarily in northeastern and southern Brazil. The transmission contracts provide for revenues denominated in the Brazilian Real, annual inflation adjustments and change in tax law adjustments. The functional currency for the Brazilian Transmission Lines is the Brazilian Real.

In 2009, multiple sales agreements were signed for the Company to sell its ownership interests in the Brazilian Transmission Lines. In November 2010, the Company completed the sale of its entire ownership interest in ENTE and ERTE and 59.96 percent of the Company's ownership interest in ECTE. The Company's remaining interest in ECTE is being sold over a four-year period. In August 2013 and 2012, and November 2011, the Company completed the sale of one-fourth of the remaining interest in each year. The Company recognized an immaterial gain in 2013. The Company's remaining ownership interest in ECTE is being accounted for under the cost method.

At June 30, 2013, the equity method investments had total assets of $114.8 million and long-term debt of $56.2 million. The Company's investment in its equity method investments was approximately $5.5 million, including undistributed earnings of $2.0 million, at June 30, 2013.

Note 13 - Goodwill and other intangible assets

The changes in the carrying amount of goodwill were as follows:

Six Months Ended June 30, 2014	Balance as of January 1, 2014*		Goodwill Acquired During the Year		Balance as of June 30, 2014*
	(In thousands)
Natural gas distribution	$	345,736	$	—	$	345,736
Pipeline and energy services	9,737		—		9,737
Construction materials and contracting	176,290		—		176,290
Construction services	104,276		—		104,276
Total	$	636,039	$	—	$	636,039

* Balance is presented net of accumulated impairment of $12.3 million at the pipeline and energy services segment, which occurred in prior periods.

Six Months Ended June 30, 2013	Balance as of January 1, 2013*		Goodwill Acquired During the Year		Balance as of June 30, 2013*
	(In thousands)
Natural gas distribution	$	345,736	$	—	$	345,736
Pipeline and energy services	9,737		—		9,737
Construction materials and contracting	176,290		—		176,290
Construction services	104,276		—		104,276
Total	$	636,039	$	—	$	636,039

* Balance is presented net of accumulated impairment of $12.3 million at the pipeline and energy services segment, which occurred in prior periods.

14

Year Ended December 31, 2013	Balance as of January 1, 2013*		Goodwill Acquired During the Year		Balance as of December 31, 2013*
	(In thousands)
Natural gas distribution	$	345,736	$	—	$	345,736
Pipeline and energy services	9,737		—		9,737
Construction materials and contracting	176,290		—		176,290
Construction services	104,276		—		104,276
Total	$	636,039	$	—	$	636,039

  * Balance is presented net of accumulated impairment of $12.3 million at the pipeline and energy services segment, which occurred in prior periods.

Other amortizable intangible assets were as follows:

	June 30, 2014			June 30, 2013			December 31, 2013
	(In thousands)
Customer relationships	$	21,310		$	21,310		$	21,310
Accumulated amortization	(14,734		)	(12,715		)	(13,726		)
	6,576			8,595			7,584
Noncompete agreements	5,080			6,186			6,186
Accumulated amortization	(3,936		)	(4,557		)	(4,840		)
	1,144			1,629			1,346
Other	10,921			10,979			10,995
Accumulated amortization	(7,375		)	(5,891		)	(6,826		)
	3,546			5,088			4,169
Total	$	11,266		$	15,312		$	13,099

Amortization expense for amortizable intangible assets for the three and six months ended June 30, 2014, was $1.0 million and $1.8 million, respectively. Amortization expense for amortizable intangible assets for the three and six months ended June 30, 2013, was $1.0 million and $1.8 million, respectively. Estimated amortization expense for amortizable intangible assets is $3.3 million in 2014, $2.5 million in 2015, $2.2 million in 2016, $1.9 million in 2017, $1.0 million in 2018 and $2.2 million thereafter.

Note 14 - Derivative instruments

The Company's policy allows the use of derivative instruments as part of an overall energy price, foreign currency and interest rate risk management program to efficiently manage and minimize commodity price, foreign currency and interest rate risk. As of June 30, 2014, the Company had no outstanding foreign currency or interest rate hedges.

The fair value of derivative instruments must be estimated as of the end of each reporting period and is recorded on the Consolidated Balance Sheets as an asset or a liability.

Fidelity

At June 30, 2014 and 2013, and December 31, 2013, Fidelity held oil swap and collar agreements with total forward notional volumes of 2.5 million, 3.1 million and 2.9 million Bbl, respectively, and natural gas swap agreements with total forward notional volumes of 11.0 million, 21.4 million and 18.3 million MMBtu, respectively. Fidelity utilizes these derivative instruments to manage a portion of the market risk associated with fluctuations in the price of oil and natural gas on its forecasted sales of oil and natural gas production.

Effective April 1, 2013, Fidelity elected to de-designate all commodity derivative contracts previously designated as cash flow hedges and elected to discontinue hedge accounting prospectively for all of its commodity derivative instruments. When the criteria for hedge accounting is not met or when hedge accounting is not elected, realized gains and losses and unrealized gains and losses are both recorded in operating revenues on the Consolidated Statements of Income. As a result of discontinuing hedge accounting on commodity derivative instruments, gains and losses on the oil and natural gas derivative instruments remain in accumulated other comprehensive income (loss) as of the de-designation date and are reclassified into earnings in future periods as the underlying hedged transactions affect earnings. At April 1, 2013, accumulated other comprehensive income (loss) included $1.8 million of unrealized gains, representing the mark-to-market value of the Company's commodity

15

derivative instruments that qualified as cash flow hedges as of the balance sheet date. The Company expects to reclassify into earnings from accumulated other comprehensive income (loss) the remaining value related to de-designating commodity derivative instruments over the next 6 months.

Prior to April 1, 2013, changes in the fair value attributable to the effective portion of the hedging instruments, net of tax, were recorded in stockholders' equity as a component of accumulated other comprehensive income (loss). To the extent that the hedges were not effective or did not qualify for hedge accounting, the ineffective portion of the changes in fair market value was recorded directly in earnings. Gains and losses on the oil and natural gas derivative instruments were reclassified from accumulated other comprehensive income (loss) into operating revenues on the Consolidated Statements of Income at the date the oil and natural gas quantities were settled.

There were no components of the derivative instruments' gain or loss excluded from the assessment of hedge effectiveness. Gains and losses must be reclassified into earnings as a result of the discontinuance of cash flow hedges if it is probable that the original forecasted transactions will not occur, and there were no such reclassifications.

Certain of Fidelity's derivative instruments contain cross-default provisions that state if Fidelity or any of its affiliates fails to make payment with respect to certain indebtedness, in excess of specified amounts, the counterparties could require early settlement or termination of the derivative instruments in liability positions. The aggregate fair value of Fidelity's derivative instruments with credit-risk-related contingent features that are in a liability position at June 30, 2014 and 2013, and December 31, 2013, were $17.4 million, $1.4 million and $7.5 million, respectively. The aggregate fair value of assets that would have been needed to settle the instruments immediately if the credit-risk-related contingent features were triggered on June 30, 2014 and 2013, and December 31, 2013, were $17.4 million, $1.4 million and $7.5 million, respectively.

Centennial

Centennial has historically entered into interest rate derivative instruments to manage a portion of its interest rate exposure on the forecasted issuance of long-term debt. As of June 30, 2014 and 2013, and December 31, 2013, Centennial had no outstanding interest rate swap agreements.

Fidelity and Centennial

The gains and losses on derivative instruments were as follows:

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2014			2013			2014			2013
	(In thousands)
Commodity derivatives designated as cash flow hedges:
Amount of loss recognized in accumulated other comprehensive loss (effective portion), net of tax	$	—		$	—		$	—		$	(6,154	)
Amount of (gain) loss reclassified from accumulated other comprehensive loss into operating revenues (effective portion), net of tax	(86		)	(871		)	158			(3,714		)
Amount of loss recognized in operating revenues (ineffective portion), before tax	—			—			—			(1,422		)
Interest rate derivatives designated as cash flow hedges:
Amount of gain recognized in accumulated other comprehensive loss (effective portion), net of tax	—			254			—			560
Amount of loss reclassified from accumulated other comprehensive loss into interest expense (effective portion), net of tax	99			475			199			546
Amount of loss recognized in interest expense (ineffective portion), before tax	—			(610		)	—			(769		)
Commodity derivatives not designated as hedging instruments:
Amount of gain (loss) recognized in operating revenues, before tax	(5,196		)	13,047			(11,908		)	8,637

Over the next 12 months net losses of approximately $535,000 (after tax) are estimated to be reclassified from accumulated other comprehensive income (loss) into earnings, as the hedged transactions affect earnings.

16

The location and fair value of the gross amount of the Company's derivative instruments on the Consolidated Balance Sheets were as follows:

Asset Derivatives	Location on Consolidated Balance Sheets	Fair Value at June 30, 2014		Fair Value at June 30, 2013		Fair Value at December 31, 2013
		(In thousands)
Not designated as hedges:
Commodity derivatives	Commodity derivative instruments	$	129	$	9,797	$	1,447
	Other assets - noncurrent	131		1,447		503
Total asset derivatives		$	260	$	11,244	$	1,950

Liability Derivatives	Location on Consolidated Balance Sheets	Fair Value at June 30, 2014		Fair Value at June 30, 2013		Fair Value at December 31, 2013
		(In thousands)
Not designated as hedges:
Commodity derivatives	Commodity derivative instruments	$	17,449	$	1,388	$	7,483
Total liability derivatives		$	17,449	$	1,388	$	7,483

All of the Company's commodity derivative instruments at June 30, 2014 and 2013, and December 31, 2013, were subject to legally enforceable master netting agreements. However, the Company's policy is to not offset fair value amounts for derivative instruments and, as a result, the Company's derivative assets and liabilities are presented gross on the Consolidated Balance Sheets. The gross derivative assets and liabilities (excluding settlement receivables and payables that may be subject to the same master netting agreements) presented on the Consolidated Balance Sheets and the amount eligible for offset under the master netting agreements is presented in the following table:

June 30, 2014	Gross Amounts Recognized on the Consolidated Balance Sheets		Gross Amounts Not Offset on the Consolidated Balance Sheets			Net
	(In thousands)
Assets:
Commodity derivatives	$	260	$	(260	)	$	—
Total assets	$	260	$	(260	)	$	—
Liabilities:
Commodity derivatives	$	17,449	$	(260	)	$	17,189
Total liabilities	$	17,449	$	(260	)	$	17,189

June 30, 2013	Gross Amounts Recognized on the Consolidated Balance Sheets		Gross Amounts Not Offset on the Consolidated Balance Sheets			Net
	(In thousands)
Assets:
Commodity derivatives	$	11,244	$	(1,388	)	$	9,856
Total assets	$	11,244	$	(1,388	)	$	9,856
Liabilities:
Commodity derivatives	$	1,388	$	(1,388	)	$	—
Total liabilities	$	1,388	$	(1,388	)	$	—

17

December 31, 2013	Gross Amounts Recognized on the Consolidated Balance Sheets		Gross Amounts Not Offset on the Consolidated Balance Sheets			Net
	(In thousands)
Assets:
Commodity derivatives	$	1,950	$	(1,950	)	$	—
Total assets	$	1,950	$	(1,950	)	$	—
Liabilities:
Commodity derivatives	$	7,483	$	(1,950	)	$	5,533
Total liabilities	$	7,483	$	(1,950	)	$	5,533

Note 15 - Fair value measurements

The Company measures its investments in certain fixed-income and equity securities at fair value with changes in fair value recognized in income. The Company anticipates using these investments, which consist of an insurance contract, 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, which totaled $64.4 million, $54.0 million and $62.4 million, at June 30, 2014 and 2013, and December 31, 2013, respectively, are classified as Investments on the Consolidated Balance Sheets. The net unrealized gains on these investments were $1.1 million and $2.0 million for the three and six months ended June 30, 2014, respectively. The net unrealized gains on these investments were $700,000 and $5.1 million for the three and six months ended June 30, 2013, respectively. The change in fair value, which is considered part of the cost of the plan, is classified in operation and maintenance expense on the Consolidated Statements of Income.

The Company did not elect the fair value option, which records gains and losses in income, for its available-for-sale securities, which include mortgage-backed securities and U.S. Treasury securities. These available-for-sale securities are recorded at fair value and are classified as Investments on the Consolidated Balance Sheets. Unrealized gains or losses are recorded in accumulated other comprehensive income (loss). Details of available-for-sale securities were as follows:

June 30, 2014	Cost		Gross Unrealized Gains		Gross Unrealized Losses			Fair Value
	(In thousands)
Mortgage-backed securities	$	7,989	$	91	$	(5	)	$	8,075
U.S. Treasury securities	2,066		30		—			2,096
Total	$	10,055	$	121	$	(5	)	$	10,171

June 30, 2013	Cost		Gross Unrealized Gains		Gross Unrealized Losses			Fair Value
	(In thousands)
Mortgage-backed securities	$	8,035	$	58	$	(41	)	$	8,052
U.S. Treasury securities	1,920		15		(15		)	1,920
Total	$	9,955	$	73	$	(56	)	$	9,972

December 31, 2013	Cost		Gross Unrealized Gains		Gross Unrealized Losses			Fair Value
	(In thousands)
Mortgage-backed securities	$	8,151	$	69	$	(27	)	$	8,193
U.S. Treasury securities	1,906		15		(4		)	1,917
Total	$	10,057	$	84	$	(31	)	$	10,110

The fair value of the Company's money market funds approximates cost.

18

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability (an exit price) in an orderly transaction between market participants at the measurement date. The ASC establishes a hierarchy for grouping assets and liabilities, based on the significance of inputs.

The estimated fair values of the Company's assets and liabilities measured on a recurring basis are determined using the market approach.

The Company's Level 2 money market funds consist of investments in short-term unsecured promissory notes and the value is based on comparable market transactions taking into consideration the credit quality of the issuer. The estimated fair value of the Company's Level 2 mortgage-backed securities and U.S. Treasury securities are based on comparable market transactions, other observable inputs or other sources, including pricing from outside sources.

The estimated fair value of the Company's Level 2 insurance contract is based on contractual cash surrender values that are determined primarily by investments in managed separate accounts of the insurer. These amounts approximate fair value. The managed separate accounts are valued based on other observable inputs or corroborated market data.

The estimated fair value of the Company's Level 2 commodity derivative instruments is based upon futures prices, volatility and time to maturity, among other things. Counterparty statements are utilized to determine the value of the commodity derivative instruments and are reviewed and corroborated using various methodologies and significant observable inputs. The Company's and the counterparties' nonperformance risk is also evaluated.

The estimated fair value of the Company's Level 2 interest rate derivative instruments is measured using quoted market prices or pricing models using prevailing market interest rates as of the measurement date. Counterparty statements are utilized to determine the value of the interest rate derivative instruments and are reviewed and corroborated using various methodologies and significant observable inputs. The Company's and the counterparties' nonperformance risk is also evaluated.

Though the Company believes the methods used to estimate fair value are consistent with those used by other market participants, the use of other methods or assumptions could result in a different estimate of fair value. For the six months ended June 30, 2014 and 2013, there were no transfers between Levels 1 and 2.

The Company's assets and liabilities measured at fair value on a recurring basis were as follows:

	Fair Value Measurements at June 30, 2014, Using
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Balance at June 30, 2014
	(In thousands)
Assets:
Money market funds	$	—	$	19,990	$	—	$	19,990
Insurance contract*	—		64,449		—		64,449
Available-for-sale securities:
Mortgage-backed securities	—		8,075		—		8,075
U.S. Treasury securities	—		2,096		—		2,096
Commodity derivative instruments	—		260		—		260
Total assets measured at fair value	$	—	$	94,870	$	—	$	94,870
Liabilities:
Commodity derivative instruments	$	—	$	17,449	$	—	$	17,449
Total liabilities measured at fair value	$	—	$	17,449	$	—	$	17,449

*  The insurance contract invests approximately 21 percent in common stock of mid-cap companies, 18 percent in common stock of small-cap companies, 29 percent in common stock of large-cap companies, 31 percent in fixed-income investments and 1 percent in cash equivalents.

19

	Fair Value Measurements at June 30, 2013, Using
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Balance at June 30, 2013
	(In thousands)
Assets:
Money market funds	$	—	$	29,902	$	—	$	29,902
Insurance contract*	—		54,039		—		54,039
Available-for-sale securities:
Mortgage-backed securities	—		8,052		—		8,052
U.S. Treasury securities	—		1,920		—		1,920
Commodity derivative instruments	—		11,244		—		11,244
Total assets measured at fair value	$	—	$	105,157	$	—	$	105,157
Liabilities:
Commodity derivative instruments	$	—	$	1,388	$	—	$	1,388
Total liabilities measured at fair value	$	—	$	1,388	$	—	$	1,388

*  The insurance contract invests approximately 28 percent in common stock of mid-cap companies, 28 percent in common stock of small-cap companies, 28 percent in common stock of large-cap companies and 16 percent in fixed-income investments.

	Fair Value Measurements at December 31, 2013, Using
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs  (Level 3)		Balance at December 31, 2013
	(In thousands)
Assets:
Money market funds	$	—	$	19,227	$	—	$	19,227
Insurance contract*	—		62,370		—		62,370
Available-for-sale securities:
Mortgage-backed securities	—		8,193		—		8,193
U.S. Treasury securities	—		1,917		—		1,917
Commodity derivative instruments	—		1,950		—		1,950
Total assets measured at fair value	$	—	$	93,657	$	—	$	93,657
Liabilities:
Commodity derivative instruments	$	—	$	7,483	$	—	$	7,483
Total liabilities measured at fair value	$	—	$	7,483	$	—	$	7,483

* The insurance contract invests approximately 29 percent in common stock of mid-cap companies, 28 percent in common stock of small-cap companies, 28 percent in common stock of large-cap companies and 15 percent in fixed-income investments.

The Company applies the provisions of the fair value measurement standard to its nonrecurring, non-financial measurements, including long-lived asset impairments. These assets are not measured at fair value on an ongoing basis but are subject to fair value adjustments only in certain circumstances. The Company reviews the carrying value of its long-lived assets, excluding goodwill and oil and natural gas properties, whenever events or changes in circumstances indicate that such carrying amounts may not be recoverable. During the second quarter of 2013, coalbed natural gas gathering assets were reviewed for impairment and found to be impaired and were written down to their estimated fair value using the income approach. Under this approach, fair value is determined by using the present value of future estimated cash flows. The factors used to determine the estimated future cash flows include, but are not limited to, internal estimates of gathering revenue, future commodity prices and operating costs and equipment salvage values. The estimated cash flows are discounted using a rate that approximates the weighted average cost of capital of a market participant. These fair value inputs are not typically observable. At June 30, 2013, coalbed

20

natural gas gathering assets were written down to the nonrecurring fair value measurement of $9.7 million. The fair value of these coalbed natural gas gathering assets have been categorized as Level 3 (Significant Unobservable Inputs) in the fair value hierarchy.

The Company's long-term debt is not measured at fair value on the Consolidated Balance Sheets and the fair value is being provided for disclosure purposes only. The fair value was based on discounted future cash flows using current market interest rates. The estimated fair value of the Company's Level 2 long-term debt was as follows:

	Carrying Amount		Fair Value
	(In thousands)
Long-term debt at June 30, 2014	$	2,187,094	$	2,283,351
Long-term debt at June 30, 2013	$	2,006,754	$	2,090,208
Long-term debt at December 31, 2013	$	1,854,563	$	1,912,590

The carrying amounts of the Company's remaining financial instruments included in current assets and current liabilities approximate their fair values.

Note 16 - Long-term debt

On May 8, 2014, the Company amended its revolving credit agreement to increase the borrowing limit to $175.0 million and extend the termination date to May 8, 2019.

The Company entered into a $150.0 million note purchase agreement on January 28, 2014, and issued $50.0 million of Senior Notes on April 15, 2014, with a due date of April 15, 2044, at an interest rate of 5.2 percent. The remaining $100.0 million of Senior Notes was issued on July 15, 2014, with due dates ranging from July 15, 2024 to July 15, 2026, at a weighted average interest rate of 4.3 percent.

On May 8, 2014, Centennial entered into an amended and restated revolving credit agreement which increased the borrowing limit to $650.0 million and extended the termination date to May 8, 2019. The credit agreement contains customary covenants and provisions, including a covenant of Centennial not to permit, as of the end of any fiscal quarter, the ratio of total consolidated debt to total consolidated capitalization to be greater than 65 percent. Other covenants include restrictions on the sale of certain assets, limitations on subsidiary indebtedness and the making of certain loans and investments.

Centennial's revolving credit agreement contains cross-default provisions. These provisions state that if Centennial or any subsidiary of Centennial fails to make any payment with respect to any indebtedness or contingent obligation, in excess of a specified amount, under any agreement that causes such indebtedness to be due prior to its stated maturity or the contingent obligation to become payable, then Centennial will be in default under the revolving credit agreement.

Centennial entered into two separate two year $125.0 million term loan agreements with variable interest rates on March 31, 2014 and April 2, 2014, respectively. These agreements contain customary covenants and default provisions, including covenants not to permit, as of the end of any fiscal quarter, the ratio of Centennial's total debt to total capitalization to be greater than 65 percent. The covenants also include certain limitations on subsidiary indebtedness and restrictions on the sale of certain assets and on the making of certain loans and investments.

In addition, borrowings outstanding that were classified as long-term debt under the Company’s and Centennial’s commercial paper programs totaled $268.0 million at June 30, 2014, compared to $153.9 million at December 31, 2013, respectively.

21

Note 17 - Equity

A summary of the changes in equity was as follows:

Six Months Ended June 30, 2014	Total Stockholders' Equity			Noncontrolling Interest			Total Equity
	(In thousands)
Balance at December 31, 2013	$	2,823,164		$	32,738		$	2,855,902
Net income (loss)	110,768			(1,302		)	109,466
Other comprehensive income	1,007			—			1,007
Dividends declared on preferred stocks	(342		)	—			(342		)
Dividends declared on common stock	(68,025		)	—			(68,025		)
Stock-based compensation	2,796			—			2,796
Issuance of common stock upon vesting of performance shares, net of shares used for tax withholdings	(5,564		)	—			(5,564		)
Net tax benefit on stock-based compensation	4,729			—			4,729
Issuance of common stock	131,973			—			131,973
Contribution from noncontrolling interest	—			32,500			32,500
Balance at June 30, 2014	$	3,000,506		$	63,936		$	3,064,442

Six Months Ended June 30, 2013	Total Stockholders' Equity			Noncontrolling Interest			Total Equity
	(In thousands)
Balance at December 31, 2012	$	2,648,248		$	—		$	2,648,248
Net income (loss)	103,027			(179		)	102,848
Other comprehensive loss	(8,100		)	—			(8,100		)
Dividends declared on preferred stocks	(342		)	—			(342		)
Dividends declared on common stock	(65,147		)	—			(65,147		)
Stock-based compensation	2,453			—			2,453
Net tax deficit on stock-based compensation	(1,419		)	—			(1,419		)
Contribution from noncontrolling interest	—			16,101			16,101
Balance at June 30, 2013	$	2,678,720		$	15,922		$	2,694,642

Note 18 - Business segment data

The Company's reportable segments are those that are based on the Company's method of internal reporting, which generally segregates the strategic business units due to differences in products, services and regulation. The internal reporting of these operating segments is defined based on the reporting and review process used by the Company's chief executive officer. The vast majority of the Company's operations are located within the United States. The Company also has an investment in a foreign country, which consists of Centennial Resources' investment in ECTE.

The electric segment generates, transmits and distributes electricity in Montana, North Dakota, South Dakota and Wyoming. The natural gas distribution segment distributes natural gas in those states as well as in Idaho, Minnesota, Oregon and Washington. These operations also supply related value-added services.

The pipeline and energy services segment provides natural gas transportation, underground storage, processing and gathering services, as well as oil gathering, through regulated and nonregulated pipeline systems and processing facilities primarily in the Rocky Mountain and northern Great Plains regions of the United States. This segment is constructing the Dakota Prairie Refinery in conjunction with Calumet to refine crude oil and also provides cathodic protection and other energy-related services.

The exploration and production segment is engaged in oil and natural gas acquisition, exploration, development and production activities in the Rocky Mountain and Mid-Continent/Gulf States regions of the United States.

The construction materials and contracting segment mines aggregates and markets crushed stone, sand, gravel and related construction materials, including ready-mixed concrete, cement, asphalt, liquid asphalt and other value-added products. It also performs integrated contracting services. This segment operates in the central, southern and western United States and Alaska and Hawaii.

22

The construction services segment specializes in constructing and maintaining electric and communication lines, gas pipelines, fire suppression systems, and external lighting and traffic signalization equipment. This segment also provides utility excavation services and inside electrical wiring, cabling and mechanical services, sells and distributes electrical materials, and manufactures and distributes specialty equipment.

The Other category includes the activities of Centennial Capital, which insures various types of risks as a captive insurer for certain of the Company's subsidiaries. The function of the captive insurer is to fund the deductible layers of the insured companies' general liability, automobile liability and pollution liability coverages. Centennial Capital also owns certain real and personal property. The Other category also includes Centennial Resources' investment in ECTE.

The information below follows the same accounting policies as described in Note 1 of the Company's Notes to Consolidated Financial Statements in the 2013 Annual Report. Information on the Company's businesses was as follows:

Three Months Ended June 30, 2014	External Operating Revenues		Inter- segment Operating Revenues			Earnings on Common Stock
	(In thousands)
Electric	$	65,149	$	—		$	7,823
Natural gas distribution	146,077		—			(4,494		)
Pipeline and energy services	43,463		7,888			5,789
	254,689		7,888			9,118
Exploration and production	129,309		10,271			19,180
Construction materials and contracting	434,452		8,106			10,554
Construction services	275,109		7,273			14,307
Other	487		1,744			1,608
	839,357		27,394			45,649
Intersegment eliminations	—		(35,282		)	(832		)
Total	$	1,094,046	$	—		$	53,935

Three Months Ended June 30, 2013	External Operating Revenues		Inter- segment Operating Revenues			Earnings on Common Stock
	(In thousands)
Electric	$	56,981	$	—		$	4,410
Natural gas distribution	127,584		—			(5,893		)
Pipeline and energy services	42,877		7,999			(6,395		)
	227,442		7,999			(7,878		)
Exploration and production	137,053		12,556			32,995
Construction materials and contracting	418,345		12,958			10,025
Construction services	277,259		2,340			12,915
Other	496		1,839			340
	833,153		29,693			56,275
Intersegment eliminations	—		(37,692		)	(2,056		)
Total	$	1,060,595	$	—		$	46,341

23

Six Months Ended June 30, 2014	External Operating Revenues		Inter- segment Operating Revenues			Earnings on Common Stock
	(In thousands)
Electric	$	138,796	$	—		$	18,856
Natural gas distribution	520,311		—			22,768
Pipeline and energy services	87,124		26,164			10,138
	746,231		26,164			51,762
Exploration and production	245,976		31,139			40,120
Construction materials and contracting	598,875		12,123			(13,019		)
Construction services	545,002		11,010			30,875
Other	815		3,468			1,872
	1,390,668		57,740			59,848
Intersegment eliminations	—		(83,904		)	(1,184		)
Total	$	2,136,899	$	—		$	110,426

Six Months Ended June 30, 2013	External Operating Revenues		Inter- segment Operating Revenues			Earnings on Common Stock
	(In thousands)
Electric	$	121,635	$	—		$	14,235
Natural gas distribution	459,337		—			26,624
Pipeline and energy services	70,593		26,717			(4,064		)
	651,565		26,717			36,795
Exploration and production	252,415		22,369			53,279
Construction materials and contracting	580,323		17,251			(10,557		)
Construction services	507,065		3,914			24,579
Other	830		3,657			645
	1,340,633		47,191			67,946
Intersegment eliminations	—		(73,908		)	(2,056		)
Total	$	1,992,198	$	—		$	102,685

Earnings from electric, natural gas distribution and pipeline and energy services are substantially all from regulated operations. Earnings from exploration and production, construction materials and contracting, construction services and other are all from nonregulated operations.

24

Note 19 - Employee benefit plans

The Company has noncontributory defined benefit pension plans and other postretirement benefit plans for certain eligible employees. Components of net periodic benefit cost for the Company's pension and other postretirement benefit plans were as follows:

							Other
							Postretirement
	Pension Benefits						Benefits
Three Months Ended June 30,	2014			2013			2014			2013
	(In thousands)
Components of net periodic benefit cost:
Service cost	$	31		$	37		$	380		$	334
Interest cost	4,405			4,106			924			667
Expected return on assets	(5,484		)	(4,875		)	(1,242		)	(1,065		)
Amortization of prior service cost (credit)	18			18			(348		)	(364		)
Amortization of net actuarial loss	1,121			1,716			6			407
Net periodic benefit cost, including amount capitalized	91			1,002			(280		)	(21		)
Less amount capitalized	73			158			(19		)	61
Net periodic benefit cost (credit)	$	18		$	844		$	(261	)	$	(82	)

							Other
							Postretirement
	Pension Benefits						Benefits
Six Months Ended June 30,	2014			2013			2014			2013
	(In thousands)
Components of net periodic benefit cost:
Service cost	$	64		$	77		$	759		$	838
Interest cost	8,845			8,124			1,782			1,607
Expected return on assets	(10,609		)	(9,958		)	(2,309		)	(2,172		)
Amortization of prior service cost (credit)	36			36			(696		)	(728		)
Amortization of net actuarial loss	2,434			3,580			324			1,078
Net periodic benefit cost, including amount capitalized	770			1,859			(140		)	623
Less amount capitalized	168			268			10			90
Net periodic benefit cost (credit)	$	602		$	1,591		$	(150	)	$	533

In addition to the qualified plan defined pension benefits reflected in the table, the Company has unfunded, nonqualified benefit plans for executive officers and certain key management employees that generally provide for defined benefit payments at age 65 following the employee's retirement or to their beneficiaries upon death for a 15-year period. The Company's net periodic benefit cost for this plan for the three and six months ended June 30, 2014, was $1.6 million and $3.3 million, respectively. The Company's net periodic benefit cost for this plan for the three and six months ended June 30, 2013, was $1.8 million and $3.6 million, respectively.

Note 20 - Regulatory matters and revenues subject to refund

On April 8, 2014, Montana-Dakota submitted a request to the NDPSC to update the environmental cost recovery rider to reflect actual costs incurred through February 2014 and projected costs through June 2015 related to the recovery of Montana-Dakota's share of the costs resulting from the environmental retrofit required to be installed at the Big Stone Station. The NDPSC approved the proposed rider on July 10, 2014, reflecting an annual amount of $8.6 million to be recovered under the rider. The rider was effective with service rendered on and after July 15, 2014.

On September 18, 2013, Montana-Dakota filed an application with the NDPSC for a natural gas rate increase. Montana-Dakota requested a total increase of $6.8 million annually or approximately 6.4 percent above current rates. The requested increase includes the costs associated with the increased investment in facilities, including ongoing investment in new and replacement distribution facilities, an operations building, automated meter reading and a new customer billing system. An interim increase of $4.3 million annually or approximately 4.0 percent went into effect for service rendered on or after November 17, 2013. On

25

December 30, 2013, the NDPSC approved a settlement agreement for an increase in the same amount as the interim increase. A hearing on the rate design portion of the case was held February 5, 2014. The NDPSC voted to approve an order approving the allocation of the revenue increase to each rate class and the rate design on April 9, 2014. Final rates were implemented May 1, 2014.

On February 27, 2014, Montana-Dakota filed an application with the NDPSC for approval of an electric generation resource recovery rider for recovery of Montana-Dakota's investment in the 88-MW simple-cycle natural gas turbine and associated facilities currently under construction near Mandan, ND. Montana-Dakota requested recovery of $7.4 million annually or approximately 4.6 percent above current rates. Advance determination of prudence and a certificate of public convenience and necessity were received from the NDPSC on April 11, 2012. On March 12, 2014, the NDPSC suspended the filing pending further review. The NDPSC held a hearing regarding this matter on May 28, 2014. The matter is pending before the NDPSC.

On October 31, 2013, WBI Energy Transmission filed a general natural gas rate change application with the FERC based on an increase in investments of $312 million, increased operating costs, and the effect of lower storage and off system volumes. On April 30, 2014, WBI Energy Transmission reached a settlement in principle with FERC Trial Staff and all active parties to resolve the rate case. WBI Energy Transmission filed settlement rates to take effect on an interim basis, effective May 1, 2014, pending final approval of the settlement. On June 4, 2014, WBI Energy Transmission submitted to the FERC an Uncontested Offer of Settlement. On June 11, 2014, the Presiding Administrative Law Judge issued a Certification of Uncontested Settlement recommending FERC approval of the settlement without modification. The matter is pending before the FERC. Based on the adjusted base period volumes filed in the case, the annual increase in revenues is approximately $11.5 million.

Note 21 - Contingencies

The Company is party to claims and lawsuits arising out of its business and that of its consolidated subsidiaries. The Company accrues a liability for those contingencies when the incurrence of a loss is probable and the amount can be reasonably estimated. If a range of amounts can be reasonably estimated and no amount within the range is a better estimate than any other amount, then the minimum of the range is accrued. The Company does not accrue liabilities when the likelihood that the liability has been incurred is probable but the amount cannot be reasonably estimated or when the liability is believed to be only reasonably possible or remote. For contingencies where an unfavorable outcome is probable or reasonably possible and which are material, the Company discloses the nature of the contingency and, in some circumstances, an estimate of the possible loss. The Company had accrued liabilities of $32.1 million, $32.9 million and $29.5 million for contingencies, including litigation, production taxes, royalty claims and environmental matters, at June 30, 2014 and 2013, and December 31, 2013, respectively, which include amounts that may have been accrued for matters discussed in Litigation and Environmental matters within this note.

Litigation

Guarantee Obligation Under a Construction Contract Centennial guaranteed CEM's obligations under a construction contract with LPP for a 550-MW combined-cycle electric generating facility near Hobbs, New Mexico. Centennial Resources sold CEM in July 2007 to Bicent. In February 2009, Centennial received a Notice and Demand from LPP under the guarantee agreement alleging that CEM did not meet certain of its obligations under the construction contract and demanding that Centennial indemnify LPP against all losses, damages, claims, costs, charges and expenses arising from CEM's alleged failures. In December 2009, LPP submitted a demand for arbitration of its dispute with CEM to the American Arbitration Association seeking compensatory damages of $149.7 million. An arbitration award was issued January 13, 2012, awarding LPP $22.0 million. Centennial subsequently received a demand from LPP for payment of the arbitration award plus interest and attorneys' fees. An accrual related to the guarantee as a result of the arbitration award was recorded in discontinued operations on the Consolidated Statement of Income in the fourth quarter of 2011. CEM filed a petition with the New York Supreme Court to vacate the arbitration award in favor of LPP. The New York Supreme Court granted CEM's petition to vacate the arbitration award on November 20, 2012, and entered an order and judgment to that effect on June 5, 2013. LPP appealed the order and judgment and on February 20, 2014, the New York Supreme Court Appellate Division ruled the arbitration award was properly vacated. LPP filed a motion with the New York Court of Appeals for leave to appeal the decision of the New York Supreme Court Appellate Division. The motion was denied on June 10, 2014. Due to the vacation of the arbitration award, the accrual that was previously recorded in 2011 was reversed in the fourth quarter of 2012. The effect of this was recorded in discontinued operations on the Consolidated Statement of Income. For more information regarding discontinued operations, see Note 11.

Construction MaterialsUntil the fall of 2011 when it discontinued active mining operations at the pit, JTL operated the Target Range Gravel Pit in Missoula County, Montana under a 1975 reclamation contract pursuant to the Montana Opencut Mining Act. In September 2009, the Montana DEQ sent a letter asserting JTL was in violation of the Montana Opencut Mining Act by conducting mining operations outside a permitted area. JTL filed a complaint in Montana First Judicial District Court in June 2010, seeking a declaratory order that the reclamation contract is a valid permit under the Montana Opencut Mining Act. The Montana DEQ filed an answer and counterclaim to the complaint in August 2011, alleging JTL was in violation of the Montana

26

Opencut Mining Act and requesting imposition of penalties of not more than $3.7 million plus not more than $5,000 per day from the date of the counterclaim. The Company believes the operation of the Target Range Gravel Pit was conducted under a valid permit; however, the imposition of civil penalties is reasonably possible. The Company filed an application for amendment of its opencut mining permit and intends to resolve this matter through settlement or continuation of the Montana First Judicial District Court litigation.

Former Employee Litigation On August 6, 2012, a former employee and his spouse filed actions against Connolly-Pacific and others in California Superior Court alleging the former employee contracted acute myelogenous leukemia from exposure to substances while employed as a seaman by the defendants. The plaintiffs request compensatory damages of approximately $23.8 million plus punitive damages, costs and interest. Connolly-Pacific is contesting the claims and believes it has meritorious defenses to them. Connolly-Pacific will seek insurance coverage for defense costs and any liability incurred in the litigation.

Natural Gas Gathering Operations In January 2010, SourceGas filed an application with the Colorado State District Court to compel WBI Energy Midstream to arbitrate a dispute regarding operating pressures under a natural gas gathering contract on one of WBI Energy Midstream's pipeline gathering systems in Montana. WBI Energy Midstream resisted the application and sought a declaratory order interpreting the gathering contract. In May 2010, the Colorado State District Court granted the application and ordered WBI Energy Midstream into arbitration. In October 2010, the arbitration panel issued an award in favor of SourceGas for approximately $26.6 million. The Colorado Court of Appeals issued a decision on May 24, 2012, reversing the Colorado State District Court order compelling arbitration, vacating the final award and remanding the case to the Colorado State District Court to determine SourceGas's claims and WBI Energy Midstream's counterclaims. On remand of the matter to the Colorado State District Court, SourceGas may assert claims similar to those asserted in the arbitration proceeding.

In a related matter, Omimex filed a complaint against WBI Energy Midstream in Montana Seventeenth Judicial District Court in July 2010 alleging WBI Energy Midstream breached a separate gathering contract with Omimex as a result of the increased operating pressures demanded by SourceGas on the same natural gas gathering system. In December 2011, Omimex filed an amended complaint alleging WBI Energy Midstream breached obligations to operate its gathering system as a common carrier under United States and Montana law. WBI Energy Midstream removed the action to the United States District Court for the District of Montana. The parties subsequently settled the breach of contract claim and, subject to final determination on liability, stipulated to the damages on the common carrier claim, for amounts that are not material. A trial on the common carrier claim was held during July 2013, but a decision has not been issued.

Exploration and Production During the ordinary course of its business, Fidelity is subject to audit for various production related taxes by certain state and federal tax authorities for varying periods as well as claims for royalty obligations under lease agreements for oil and gas production. Disputes may exist regarding facts and questions of law relating to the tax and royalty obligations.

On May 15, 2013, Austin Holdings, LLC filed an action against Fidelity in Wyoming State District Court alleging Fidelity violated the Wyoming Royalty Payment Act and implied lease covenants by deducting production costs from and by failing to properly report and pay royalties for coalbed methane gas production in Wyoming. The plaintiff, in addition to declaratory and injunctive relief, seeks class certification for similarly situated persons and an unspecified amount of monetary damages on behalf of the class for unpaid royalties, interest, reporting violations and attorney fees. Fidelity believes it has meritorious defenses against class certification and the claims.

The Company also is subject to other litigation, and actual and potential claims in the ordinary course of its business which may include, but are not limited to, matters involving property damage, personal injury, and environmental, contractual, statutory and regulatory obligations. Accruals are based on the best information available but actual losses in future periods are affected by various factors making them uncertain. After taking into account liabilities accrued for the foregoing matters, management believes that the outcomes with respect to the above issues and other probable and reasonably possible losses in excess of the amounts accrued, while uncertain, will not have a material effect upon the Company's financial position, results of operations or cash flows.

Environmental matters

Portland Harbor Site In December 2000, Knife River - Northwest was named by the EPA as a PRP in connection with the cleanup of a riverbed site adjacent to a commercial property site acquired by Knife River - Northwest from Georgia-Pacific West, Inc. in 1999. The riverbed site is part of the Portland, Oregon, Harbor Superfund Site. The EPA wants responsible parties to share in the cleanup of sediment contamination in the Willamette River. To date, costs of the overall remedial investigation and feasibility study of the harbor site are being recorded, and initially paid, through an administrative consent order by the LWG, a group of several entities, which does not include Knife River - Northwest or Georgia-Pacific West, Inc. Investigative

27

costs are indicated to be in excess of $70 million. It is not possible to estimate the cost of a corrective action plan until the remedial investigation and feasibility study have been completed, the EPA has decided on a strategy and a ROD has been published. Corrective action will be taken after the development of a proposed plan and ROD on the harbor site is issued. Knife River - Northwest also received notice in January 2008 that the Portland Harbor Natural Resource Trustee Council intends to perform an injury assessment to natural resources resulting from the release of hazardous substances at the Harbor Superfund Site. The Portland Harbor Natural Resource Trustee Council indicates the injury determination is appropriate to facilitate early settlement of damages and restoration for natural resource injuries. It is not possible to estimate the costs of natural resource damages until an assessment is completed and allocations are undertaken.

Based upon a review of the Portland Harbor sediment contamination evaluation by the Oregon DEQ and other information available, Knife River - Northwest does not believe it is a Responsible Party. In addition, Knife River - Northwest has notified Georgia-Pacific West, Inc., that it intends to seek indemnity for liabilities incurred in relation to the above matters pursuant to the terms of their sale agreement. Knife River - Northwest has entered into an agreement tolling the statute of limitations in connection with the LWG's potential claim for contribution to the costs of the remedial investigation and feasibility study. By letter in March 2009, LWG stated its intent to file suit against Knife River - Northwest and others to recover LWG's investigation costs to the extent Knife River - Northwest cannot demonstrate its non-liability for the contamination or is unwilling to participate in an alternative dispute resolution process that has been established to address the matter. At this time, Knife River - Northwest has agreed to participate in the alternative dispute resolution process.

The Company believes it is not probable that it will incur any material environmental remediation costs or damages in relation to the above referenced administrative action.

Manufactured Gas Plant Sites There are three claims against Cascade for cleanup of environmental contamination at manufactured gas plant sites operated by Cascade's predecessors.

The first claim is for contamination at a site in Eugene, Oregon which was received in 1995. There are PRPs in addition to Cascade that may be liable for cleanup of the contamination. Some of these PRPs have shared in the investigation costs. It is expected that these and other PRPs will share in the cleanup costs. Several alternatives for cleanup have been identified, with preliminary cost estimates ranging from approximately $500,000 to $11.0 million. The Oregon DEQ is preparing a staff report which will recommend a cleanup alternative for the site. It is not known at this time what share of the cleanup costs will actually be borne by Cascade; however, Cascade anticipates its proportional share could be approximately 50 percent. Cascade has accrued $1.7 million for remediation of this site. In January 2013, the OPUC approved Cascade's application to defer environmental remediation costs at the Eugene site for a period of 12 months starting November 30, 2012. Cascade received an order reauthorizing the deferred accounting for the 12 months starting November 30, 2013.

The second claim is for contamination at a site in Bremerton, Washington which was received in 1997. A preliminary investigation has found soil and groundwater at the site contain contaminants requiring further investigation and cleanup. EPA conducted a Targeted Brownfields Assessment of the site and released a report summarizing the results of that assessment in August 2009. The assessment confirms that contaminants have affected soil and groundwater at the site, as well as sediments in the adjacent Port Washington Narrows. Alternative remediation options have been identified with preliminary cost estimates ranging from $340,000 to $6.4 million. Data developed through the assessment and previous investigations indicates the contamination likely derived from multiple, different sources and multiple current and former owners of properties and businesses in the vicinity of the site may be responsible for the contamination. In April 2010, the Washington Department of Ecology issued notice it considered Cascade a PRP for hazardous substances at the site. In May 2012, the EPA added the site to the National Priorities List of Superfund sites. Cascade has entered into an administrative settlement agreement and consent order with the EPA regarding the scope and schedule for a remedial investigation and feasibility study for the site. Cascade has accrued $12.6 million for the remedial investigation, feasibility study and remediation of this site. In April 2010, Cascade filed a petition with the WUTC for authority to defer the costs, which are included in other noncurrent assets, incurred in relation to the environmental remediation of this site until the next general rate case. The WUTC approved the petition in September 2010, subject to conditions set forth in the order.

The third claim is for contamination at a site in Bellingham, Washington. Cascade received notice from a party in May 2008 that Cascade may be a PRP, along with other parties, for contamination from a manufactured gas plant owned by Cascade and its predecessor from about 1946 to 1962. The notice indicates that current estimates to complete investigation and cleanup of the site exceed $8.0 million. Other PRPs have reached an agreed order and work plan with the Washington Department of Ecology for completion of a remedial investigation and feasibility study for the site. A report documenting the initial phase of the remedial investigation was completed in June 2011. There is currently not enough information available to estimate the potential liability to Cascade associated with this claim although Cascade believes its proportional share of any liability will be relatively small in comparison to other PRPs. The plant manufactured gas from coal between approximately 1890 and 1946. In

28

1946, shortly after Cascade's predecessor acquired the plant, it converted the plant to a propane-air gas facility. There are no documented wastes or by-products resulting from the mixing or distribution of propane-air gas.

Cascade has received notices from and entered into agreement with certain of its insurance carriers that they will participate in defense of Cascade for these contamination claims subject to full and complete reservations of rights and defenses to insurance coverage. To the extent these claims are not covered by insurance, Cascade will seek recovery through the OPUC and WUTC of remediation costs in its natural gas rates charged to customers. The accruals related to these matters are reflected in regulatory assets.

Guarantees

Centennial guaranteed CEM's obligations under a construction contract. For more information, see Litigation in this note.

In connection with the sale of the Brazilian Transmission Lines, as discussed in Note 12, Centennial has agreed to guarantee payment of any indemnity obligations of certain of the Company's indirect wholly owned subsidiaries who are the sellers in three purchase and sale agreements for periods ranging up to 10 years from the date of sale. The guarantees were required by the buyers as a condition to the sale of the Brazilian Transmission Lines.

WBI Holdings has guaranteed certain of Fidelity's oil and natural gas swap agreement obligations. There is no fixed maximum amount guaranteed in relation to the oil and natural gas swap agreements as the amount of the obligation is dependent upon oil and natural gas commodity prices. The amount of derivative activity entered into by the subsidiary is limited by corporate policy. The guarantees of the oil and natural gas swap agreements at June 30, 2014, expire in the years ranging from 2014 to 2015; however, Fidelity continues to enter into additional derivative instruments and, as a result, WBI Holdings from time to time may issue additional guarantees on these derivative instruments. The amount outstanding by Fidelity was $14.5 million and was reflected on the Consolidated Balance Sheet at June 30, 2014. In the event Fidelity defaults under its obligations, WBI Holdings would be required to make payments under its guarantees.

Certain subsidiaries of the Company have outstanding guarantees to third parties that guarantee the performance of other subsidiaries of the Company. These guarantees are related to construction contracts, natural gas transportation and sales agreements, gathering contracts and certain other guarantees. At June 30, 2014, the fixed maximum amounts guaranteed under these agreements aggregated $76.7 million. The amounts of scheduled expiration of the maximum amounts guaranteed under these agreements aggregate $21.2 million in 2014; $35.7 million in 2015; $700,000 in 2016; $600,000 in 2017; $500,000 in 2018; $500,000 in 2019; $13.5 million, which is subject to expiration on a specified number of days after the receipt of written notice; and $4.0 million, which has no scheduled maturity date. The amount outstanding by subsidiaries of the Company under the above guarantees was $200,000 and was reflected on the Consolidated Balance Sheet at June 30, 2014. In the event of default under these guarantee obligations, the subsidiary issuing the guarantee for that particular obligation would be required to make payments under its guarantee.

Certain subsidiaries have outstanding letters of credit to third parties related to insurance policies and other agreements, some of which are guaranteed by other subsidiaries of the Company. At June 30, 2014, the fixed maximum amounts guaranteed under these letters of credit, aggregated $36.3 million. In 2014 and 2015, $7.0 million and $29.3 million, respectively, of letters of credit are scheduled to expire. There were no amounts outstanding under the above letters of credit at June 30, 2014.

WBI Holdings has an outstanding guarantee to WBI Energy Transmission. This guarantee is related to a natural gas transportation and storage agreement that guarantees the performance of Prairielands. At June 30, 2014, the fixed maximum amount guaranteed under this agreement was $4.0 million and is scheduled to expire in 2016. In the event of Prairielands' default in its payment obligations, WBI Holdings would be required to make payment under its guarantee. The amount outstanding by Prairielands under the above guarantee was $1.1 million. The amount outstanding under this guarantee was not reflected on the Consolidated Balance Sheet at June 30, 2014, because this intercompany transaction was eliminated in consolidation.

In addition, Centennial, Knife River and MDU Construction Services have issued guarantees to third parties related to the routine purchase of maintenance items, materials and lease obligations for which no fixed maximum amounts have been specified. These guarantees have no scheduled maturity date. In the event a subsidiary of the Company defaults under these obligations, Centennial, Knife River and MDU Construction Services would be required to make payments under these guarantees. Any amounts outstanding by subsidiaries of the Company for these guarantees were reflected on the Consolidated Balance Sheet at June 30, 2014.

In the normal course of business, Centennial has surety bonds related to construction contracts and reclamation obligations of its subsidiaries. In the event a subsidiary of Centennial does not fulfill a bonded obligation, Centennial would be responsible to

29

the surety bond company for completion of the bonded contract or obligation. A large portion of the surety bonds is expected to expire within the next 12 months; however, Centennial will likely continue to enter into surety bonds for its subsidiaries in the future. At June 30, 2014, approximately $666.9 million of surety bonds were outstanding, which were not reflected on the Consolidated Balance Sheet.

Variable interest entities

The Company evaluates its arrangements and contracts with other entities to determine if they are VIEs and if so, if the Company is the primary beneficiary.

Dakota Prairie Refining, LLCOn February 7, 2013, WBI Energy and Calumet formed a limited liability company, Dakota Prairie Refining, and entered into an operating agreement to develop, build and operate Dakota Prairie Refinery in southwestern North Dakota. WBI Energy and Calumet each have a 50 percent ownership interest in Dakota Prairie Refining. WBI Energy's and Calumet's capital commitments, based on a total project cost of $300.0 million, under the agreement are $150.0 million and $75.0 million, respectively. Capital commitments in excess of $300.0 million are expected to be shared equally between WBI Energy and Calumet. The total project cost is currently estimated at $350 million. Dakota Prairie Refining entered into a term loan for project debt financing of $75.0 million on April 22, 2013. The operating agreement provides for allocation of profits and losses consistent with ownership interests; however, deductions attributable to project financing debt will be allocated to Calumet. Calumet's future cash distributions from Dakota Prairie Refining will be decreased by the principal and interest to be paid on the project debt, while the cash distributions to WBI Energy will not be decreased. Pursuant to the operating agreement, Centennial agreed to guarantee Dakota Prairie Refining's obligation under the term loan.

Dakota Prairie Refining has been determined to be a VIE, and the Company has determined that it is the primary beneficiary as it has an obligation to absorb losses that could be potentially significant to the VIE through WBI Energy's equity investment and Centennial's guarantee of the third-party term loan. Accordingly, the Company consolidates Dakota Prairie Refining in its financial statements and records a noncontrolling interest for Calumet's ownership interest.

Construction of Dakota Prairie Refinery began in early 2013 and the plant is not yet operational. Therefore, the results of operations of Dakota Prairie Refining did not have a material effect on the Company's Consolidated Statements of Income. The assets of Dakota Prairie Refining shall be used solely for the benefit of Dakota Prairie Refining. The total assets and liabilities of Dakota Prairie Refining reflected on the Company's Consolidated Balance Sheets were as follows:

	June 30, 2014		June 30, 2013		December 31, 2013
	(In thousands)
ASSETS
Current assets:
Cash and cash equivalents	$	32,283	$	63,089	$	4,774
Accounts receivable	—		5		—
Other current assets	2,136		—		26
Total current assets	34,419		63,094		4,800
Net property, plant and equipment	254,079		75,216		172,073
Total assets	$	288,498	$	138,310	$	176,873
LIABILITIES
Current liabilities:
Long-term debt due within one year	$	3,000	$	3,000	$	3,000
Accounts payable	28,150		21,057		8,904
Taxes payable	225		—		5
Accrued compensation	256		—		26
Other accrued liabilities	494		300		461
Total current liabilities	32,125		24,357		12,396
Long-term debt	69,000		72,000		72,000
Total liabilities	$	101,125	$	96,357	$	84,396

Fuel Contract On October 10, 2012, the Coyote Station entered into a new coal supply agreement with Coyote Creek that will replace a coal supply agreement expiring in May 2016. The new agreement provides for the purchase of coal necessary to supply the coal requirements of the Coyote Station for the period May 2016 through December 2040.

30

The new coal supply agreement creates a variable interest in Coyote Creek due to the transfer of all operating and economic risk to the Coyote Station owners, as the agreement is structured so the price of the coal will cover all costs of operations as well as future reclamation costs. The Coyote Station owners are also providing a guarantee of the value of the assets of Coyote Creek as they would be required to buy the assets at book value should they terminate the contract prior to the end of the contract term and are providing a guarantee of the value of the equity of Coyote Creek in that they are required to buy the entity at the end of the contract term at equity value. Although the Company has determined that Coyote Creek is a VIE, the Company has concluded that it is not the primary beneficiary of Coyote Creek because the authority to direct the activities of the entity is shared by the four unrelated owners of the Coyote Station, with no primary beneficiary existing. As a result, Coyote Creek is not required to be consolidated in the Company's financial statements.

At June 30, 2014, Coyote Creek was not yet operational. The assets and liabilities of Coyote Creek and exposure to loss as a result of the Company's involvement with the VIE, based on the Company's ownership percentage, at June 30, 2014, was $9.7 million.

Note 22 - Subsequent Events

The Company entered into a $150.0 million note purchase agreement on January 28, 2014. On April 15, 2014, the Company issued $50.0 million of Senior Notes with a due date of April 15, 2044, at an interest rate of 5.2 percent. The remaining $100.0 million of Senior Notes was issued on July 15, 2014, with due dates ranging from July 15, 2024 to July 15, 2026, at a weighted average interest rate of 4.3 percent.

Fidelity entered into a purchase and sale agreement on July 17, 2014, to sell certain oil and natural gas properties in Mountrail County, North Dakota for a sale price of approximately $200.0 million, subject to accounting and purchase price adjustments customary with dispositions of this type. The effective date of the disposition is May 1, 2014, with the expected closing date to occur on or before September 30, 2014, conditioned upon the buyer completing a due diligence process, including environmental reviews, and both parties satisfying other standard closing conditions.

31

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIALCONDITION AND RESULTS OF OPERATIONS

Overview

The Company's strategy is to apply its expertise in energy and transportation infrastructure industries to increase market share, increase profitability and enhance shareholder value through:

• 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

The Company has capabilities to fund its growth and operations through various sources, including internally generated funds, commercial paper facilities, revolving credit facilities and the issuance from time to time of debt and equity securities. For more information on the Company's net capital expenditures, see Liquidity and Capital Commitments.

The key strategies for each of the Company's business segments and certain related business challenges are summarized below. For a summary of the Company's business segments, see Note 18.

Key Strategies and Challenges

Electric and Natural Gas Distribution

Strategy Provide safe and reliable competitively priced energy and related services to customers. The electric and natural gas distribution segments continually seek opportunities to retain, grow and expand their customer base through extensions of existing operations, including building and upgrading electric generation and transmission and natural gas systems, and through selected acquisitions of companies and properties at prices that will provide stable cash flows and an opportunity for the Company to earn a competitive return on investment.

Challenges Both segments are subject to extensive regulation in the state jurisdictions where they conduct operations with respect to costs and permitted returns on investment as well as subject to certain operational, system integrity and environmental regulations. These regulations can require substantial investment to upgrade facilities. The ability of these segments to grow through acquisitions is subject to significant competition. In addition, the ability of both segments to grow service territory and customer base is affected by the economic environment of the markets served and competition from other energy providers and fuels. The construction of any new electric generating facilities, transmission lines and other service facilities are subject to increasing cost and lead time, extensive permitting procedures, and federal and state legislative and regulatory initiatives, which will necessitate increases in electric energy prices. Legislative and regulatory initiatives to increase renewable energy resources and reduce GHG emissions could impact the price and demand for electricity and natural gas.

Pipeline and Energy Services

Strategy Utilize the segment's existing expertise in energy infrastructure and related services to increase market share and profitability through optimization of existing operations, internal growth, investments in and acquisitions of energy-related assets and companies. Incremental and new growth opportunities include: access to new energy sources for storage, gathering and transportation services; expansion of existing gathering, transmission and storage facilities; incremental expansion of pipeline capacity; expansion of midstream business to include liquid pipelines and processing/refining activities; and expansion of related energy services.

ChallengesChallenges for this segment include: energy price volatility; tight natural gas basis differentials; environmental and regulatory requirements; recruitment and retention of a skilled workforce; and competition from other pipeline and energy services companies.

Exploration and Production

Strategy Apply technology and utilize existing exploration and production expertise, with a focus on operated properties, to increase production and reserves from existing leaseholds, and to seek additional reserves and production opportunities both in new and existing areas to further expand the segment's asset base. By optimizing existing operations and taking advantage of new and incremental growth opportunities, this segment is focused on balancing the oil and natural gas commodity mix to maximize profitability with its goal to add value by increasing both reserves and production over the long term so as to generate competitive returns on investment.

32

Challenges Volatility in natural gas and oil prices; timely receipt of necessary permits and approvals; environmental and regulatory requirements; recruitment and retention of a skilled workforce; availability of drilling rigs, materials, auxiliary equipment and industry-related field services; inflationary pressure on development and operating costs; and competition from other exploration and production companies are ongoing challenges for this segment.

Construction Materials and Contracting

Strategy Focus on high-growth strategic markets located near major transportation corridors and desirable mid-sized metropolitan areas; strengthen long-term, strategic aggregate reserve position through purchase and/or lease opportunities; enhance profitability through cost containment, margin discipline and vertical integration of the segment's operations; develop and recruit talented employees; and continue growth through organic and acquisition opportunities. Vertical integration allows the segment to manage operations from aggregate mining to final lay-down of concrete and asphalt, with control of and access to permitted aggregate reserves being significant. A key element of the Company's long-term strategy for this business is to further expand its market presence in the higher-margin materials business (rock, sand, gravel, liquid asphalt, asphalt concrete, ready-mixed concrete and related products), complementing and expanding on the Company's expertise.

Challenges Recruitment and retention of key personnel and volatility in the cost of raw materials such as diesel, gasoline, liquid asphalt, cement and steel, continue to be a concern. This business unit expects to continue cost containment efforts, positioning its operations for the resurgence in the private market, while continuing the emphasis on industrial, energy and public works projects.

Construction Services

Strategy Provide a superior return on investment by: building new and strengthening existing customer relationships; effectively controlling costs; retaining, developing and recruiting talented employees; and focusing our efforts on projects that will permit higher margins while properly managing risk.

Challenges This segment operates in highly competitive markets with many jobs subject to competitive bidding. Maintenance of effective operational and cost controls, retention of key personnel, managing through downturns in the economy and effective management of working capital are ongoing challenges.

For more information on the risks and challenges the Company faces as it pursues its growth strategies and other factors that should be considered for a better understanding of the Company's financial condition, see Item 1A - Risk Factors, as well as Part I, Item 1A - Risk Factors in the 2013 Annual Report. For more information on each segment's key growth strategies, projections and certain assumptions, see Prospective Information. For information pertinent to various commitments and contingencies, see Notes to Consolidated Financial Statements.

33

Earnings Overview

The following table summarizes the contribution to consolidated earnings by each of the Company's businesses.

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2014			2013			2014			2013
	(Dollars in millions, where applicable)
Electric	$	7.8		$	4.4		$	18.9		$	14.2
Natural gas distribution	(4.5		)	(5.9		)	22.8			26.6
Pipeline and energy services	5.8			(6.4		)	10.1			(4.1		)
Exploration and production	19.2			33.0			40.1			53.3
Construction materials and contracting	10.6			10.0			(13.0		)	(10.5		)
Construction services	14.3			12.9			30.9			24.6
Other	1.1			.5			1.3			.9
Intersegment eliminations	(.9		)	(2.1		)	(1.2		)	(2.1		)
Earnings before discontinued operations	53.4			46.4			109.9			102.9
Income (loss) from discontinued operations, net of tax	.5			(.1		)	.5			(.2		)
Earnings on common stock	$	53.9		$	46.3		$	110.4		$	102.7
Earnings per common share – basic:
Earnings before discontinued operations	$	.28		$	.25		$	.58		$	.54
Discontinued operations, net of tax	—			—			—			—
Earnings per common share – basic	$	.28		$	.25		$	.58		$	.54
Earnings per common share – diluted:
Earnings before discontinued operations	$	.28		$	.24		$	.58		$	.54
Discontinued operations, net of tax	—			—			—			—
Earnings per common share – diluted	$	.28		$	.24		$	.58		$	.54

Three Months Ended June 30, 2014 and 2013 Consolidated earnings for the quarter ended June 30, 2014, increased$7.6 million (16 percent) from the comparable prior period largely due to:

• The absence of the 2013 natural gas gathering asset impairment of $9.0 million (after tax) and higher earnings from the Company's interest in the Pronghorn oil and natural gas gathering and processing assets at the pipeline and energy services business

• Higher retail sales margins at the electric business

Partially offsetting these increases were an unrealized loss on commodity derivatives of $3.3 million (after tax) in 2014 compared to an unrealized gain on commodity derivatives of $8.2 million (after tax) in 2013, a loss of $7.3 million (after tax) resulting from a realized commodity derivative loss in 2014 compared to a realized commodity derivative gain in 2013 and higher depreciation, depletion and amortization expense; partially offset by increased oil production of 14 percent and increased average realized oil prices of 6 percent, excluding gain/loss on commodity derivatives, at the exploration and production business.

Six Months EndedJune 30, 2014 and 2013 Consolidated earnings for the six months ended June 30, 2014, increased$7.7 million (8 percent) from the comparable prior period largely due to:

• The absence of the 2013 natural gas gathering asset impairment of $9.0 million (after tax), as well as higher earnings from the Company's interest in the Pronghorn oil and natural gas gathering and processing assets at the pipeline and energy services business

• Higher workloads and margins in the Western region at the construction services business

Partially offsetting these increases were a loss of $14.3 million (after tax) resulting from a realized commodity derivative loss in 2014 compared to a realized commodity derivative gain in 2013, an unrealized loss on commodity derivatives of $7.5 million (after tax) in 2014 compared to an unrealized gain on commodity derivatives of $4.6 million (after tax) in 2013, higher depreciation, depletion and amortization expense, as well as decreased natural gas production of 19 percent; partially offset by higher oil production of 14 percent and higher average realized natural gas prices of 52 percent, excluding gain/loss on commodity derivatives, at the exploration and production business.

34

FINANCIAL AND OPERATING DATA

Below are key financial and operating data for each of the Company's businesses.

Electric

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2014		2013		2014		2013
	(Dollars in millions, where applicable)
Operating revenues	$	65.1	$	57.0	$	138.8	$	121.6
Operating expenses:
Fuel and purchased power	21.1		18.2		47.6		39.8
Operation and maintenance	20.5		20.5		38.9		36.8
Depreciation, depletion and amortization	8.5		7.9		17.1		16.5
Taxes, other than income	2.8		2.8		5.7		5.7
	52.9		49.4		109.3		98.8
Operating income	12.2		7.6		29.5		22.8
Earnings	$	7.8	$	4.4	$	18.9	$	14.2
Retail sales (million kWh)	721.5		691.5		1,650.4		1,534.1
Average cost of fuel and purchased power per kWh	$	.027	$	.024	$	.027	$	.024

Three Months Ended June 30, 2014 and 2013 Electric earnings increased$3.4 million (77 percent) due to:

• Higher retail sales margins, the result of higher rates, primarily due to the recovery of costs of environmental upgrades; as well as increased sales volumes of 4 percent, primarily to commercial and industrial customers

• Higher other income, which includes $800,000 (after tax) largely related to allowance for funds used during construction

Partially offsetting these increases were higher depreciation, depletion and amortization expense of $400,000 (after tax), primarily related to increased property, plant and equipment balances.

Six Months EndedJune 30, 2014 and 2013 Electric earnings increased$4.7 million (32 percent) due to:

• Higher retail sales margins, the result of higher rates, primarily due to the recovery of costs of environmental upgrades; and increased sales volumes of 8 percent to all customer classes

• Higher other income, which includes $1.2 million (after tax) largely related to allowance for funds used during construction

Partially offsetting these increases were higher operation and maintenance expense, which includes $1.4 million (after tax) primarily related to higher benefit-related costs and contract services, along with higher depreciation, depletion and amortization expense of $400,000 (after tax), as previously discussed.

35

Natural Gas Distribution

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2014			2013			2014			2013
	(Dollars in millions, where applicable)
Operating revenues	$	146.1		$	127.6		$	520.3		$	459.3
Operating expenses:
Purchased natural gas sold	89.1			73.5			346.4			286.9
Operation and maintenance	35.9			35.7			73.8			69.9
Depreciation, depletion and amortization	13.5			12.4			26.8			24.5
Taxes, other than income	9.9			9.5			27.8			25.7
	148.4			131.1			474.8			407.0
Operating income (loss)	(2.3		)	(3.5		)	45.5			52.3
Earnings (loss)	$	(4.5	)	$	(5.9	)	$	22.8		$	26.6
Volumes (MMdk):
Sales	14.7			15.3			60.0			60.2
Transportation	29.9			30.3			69.2			68.5
Total throughput	44.6			45.6			129.2			128.7
Degree days (% of normal)*
Montana-Dakota/Great Plains	109		%	130		%	107		%	104		%
Cascade	78		%	82		%	93		%	93		%
Intermountain	95		%	99		%	96		%	110		%
Average cost of natural gas, including transportation, per dk	$	6.05		$	4.82		$	5.77		$	4.77
* Degree days are a measure of the daily temperature-related demand for energy for heating.

Three Months Ended June 30, 2014 and 2013 The natural gas distribution business experienced a seasonal loss of $4.5 million compared to a seasonal loss of $5.9 million a year ago (a 24 percent improvement). The improvement was largely due to:

• Higher sales margins, including approved rate increases effective in late 2013, offset in part by lower volumes, primarily due to warmer weather

• Lower regulated operation and maintenance expense, which includes $500,000 (after tax) largely related to decreased benefit-related costs and other expenses, offset in part by increased contract services

• Higher other income, which includes $500,000 (after tax) largely related to allowance for funds used during construction

Partially offsetting these increases were higher depreciation, depletion and amortization expense of $700,000 (after tax), primarily resulting from higher property, plant and equipment balances.

The previous table also reflects higher revenue and higher operation and maintenance expense related to nonregulated activity.

Six Months EndedJune 30, 2014 and 2013Natural gas distribution earnings decreased$3.8 million (14 percent) due to:

• The absence in 2014 of the $2.8 million (after tax) gain on the sale of Montana-Dakota's nonregulated appliance service and repair business in March 2013

• Higher operation and maintenance expense, which includes $2.7 million (after tax) largely related to higher payroll and benefit-related costs and higher contract services

• Higher depreciation, depletion and amortization expense of $1.4 million (after tax), as previously discussed

Partially offsetting these decreases were higher retail sales margins, largely resulting from approved rate increases effective in late 2013; as well as higher other income, which includes $800,000 (after tax) largely related to allowance for funds used during construction.

36

Pipeline and Energy Services

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2014		2013				2014			2013
	(Dollars in millions)
Operating revenues	$	51.4	$	50.9			$	113.3		$	97.3
Operating expenses:
Purchased natural gas sold	13.0		15.8				39.2			28.6
Operation and maintenance	16.9		32.1			*	33.6			49.3			*
Depreciation, depletion and amortization	7.2		7.7				14.3			14.9
Taxes, other than income	3.4		3.5				6.6			6.9
	40.5		59.1				93.7			99.7
Operating income (loss)	10.9		(8.2		)		19.6			(2.4		)
Earnings (loss)	$	5.8	$	(6.4	)	*	$	10.1		$	(4.1	)	*
Transportation volumes (MMdk)	53.3		40.3				105.8			77.1
Natural gas gathering volumes (MMdk)	9.7		10.0				19.1			19.9
Customer natural gas storage balance (MMdk):
Beginning of period	10.4		24.7				26.7			43.7
Net injection (withdrawal)	1.0		.5				(15.3		)	(18.5		)
End of period	11.4		25.2				11.4			25.2
* Reflects an impairment of coalbed natural gas gathering assets of $14.5 million ($9.0 million after tax).

Three Months Ended June 30, 2014 and 2013 Pipeline and energy services recognized earnings of $5.8 million compared to a loss of $6.4 million for the comparable prior period due to:

• Absence of the 2013 natural gas gathering asset impairment of $9.0 million (after tax)

• Higher earnings from the Company's interest in the Pronghorn oil and natural gas gathering and processing assets, primarily due to higher volumes

• Higher earnings of $1.2 million (after tax) due to increased transportation rates

• Lower operation and maintenance expense (excluding the asset impairment and Pronghorn-related expense), which includes $800,000 (after tax) largely related to lower legal-related costs

These increases were partially offset by lower storage services revenue of $700,000 (after tax), largely due to lower average storage balances and lower rates.

Six Months EndedJune 30, 2014 and 2013Pipeline and energy services recognized earnings of $10.1 million compared to a loss of $4.1 million for the comparable prior period due to:

• Absence of the 2013 natural gas gathering asset impairment of $9.0 million (after tax)

• Higher earnings from the Company's interest in the Pronghorn oil and natural gas gathering and processing assets, primarily due to higher volumes and prices

• Higher earnings of $2.0 million (after tax) due to increased transportation rates and volumes

• Lower operation and maintenance expense (excluding the asset impairment and Pronghorn-related expense), which includes $1.1 million (after tax) largely related to lower legal-related costs

These increases were partially offset by lower storage services revenue of $1.3 million (after tax), largely due to lower average storage balances.

Results also reflect higher operating revenues and higher purchased natural gas sold, both related to higher natural gas prices.

37

Exploration and Production

	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2014			2013		2014			2013
	(Dollars in millions, where applicable)
Operating revenues:
Oil	$	127.2		$	105.9	$	240.8		$	205.9
NGL	6.3			6.2		13.2			13.7
Natural gas	21.6			23.2		52.1			42.4
Realized gain (loss) on commodity derivatives	(10.3		)	1.3		(17.1		)	5.6
Unrealized gain (loss) on commodity derivatives	(5.2		)	13.0		(11.9		)	7.2
	139.6			149.6		277.1			274.8
Operating expenses:
Operation and maintenance:
Lease operating costs	23.9			22.0		48.0			42.8
Gathering and transportation	3.1			4.2		5.4			8.5
Other	11.8			10.3		23.7			20.4
Depreciation, depletion and amortization	52.9			45.1		102.4			88.3
Taxes, other than income:
Production and property taxes	14.2			12.3		27.1			23.9
Other	.2			.3		.6			.6
	106.1			94.2		207.2			184.5
Operating income	33.5			55.4		69.9			90.3
Earnings	$	19.2		$	33.0	$	40.1		$	53.3
Production:
Oil (MBbls)	1,366			1,201		2,646			2,319
NGL (MBbls)	167			191		331			392
Natural gas (MMcf)	5,756			6,987		11,034			13,700
Total production (MBOE)	2,492			2,557		4,816			4,995
Average realized prices (excluding realized and unrealized gain/loss on commodity derivatives):
Oil (per Bbl)	$	93.06		$	88.12	$	90.99		$	88.75
NGL (per Bbl)	$	37.67		$	32.26	$	39.94		$	34.86
Natural gas (per Mcf)	$	3.76		$	3.33	$	4.72		$	3.10
Average realized prices (including realized gain/loss on commodity derivatives):
Oil (per Bbl)	$	87.03		$	90.55	$	86.43		$	91.18
NGL (per Bbl)	$	37.67		$	32.26	$	39.94		$	34.86
Natural gas (per Mcf)	$	3.40		$	3.09	$	4.27		$	3.09
Average depreciation, depletion and amortization rate, per BOE	$	20.45		$	16.90	$	20.45		$	16.90
Production costs, including taxes, per BOE:
Lease operating costs	$	9.57		$	8.59	$	9.97		$	8.57
Gathering and transportation	1.24			1.66		1.13			1.71
Production and property taxes	5.68			4.81		5.63			4.78
	$	16.49		$	15.06	$	16.73		$	15.06

38

Three Months Ended June 30, 2014 and 2013 Exploration and production earnings decreased$13.8 million (42 percent) due to:

• Unrealized loss on commodity derivatives of $3.3 million (after tax) in 2014 compared to an unrealized gain on commodity derivatives of $8.2 million (after tax) in 2013

• A loss of $7.3 million (after tax) resulting from a realized commodity derivative loss in 2014 compared to a realized commodity derivative gain in 2013

• Higher depreciation, depletion and amortization expense of $4.9 million (after tax), largely related to higher depletion rates

• Decreased natural gas production of 18 percent, largely due to the sale of non-strategic assets

Partially offsetting these decreases were:

• Increased oil production of 14 percent, primarily related to the Powder River Basin acquisition

• Increased average realized oil prices of 6 percent, excluding gain/loss on commodity derivatives

Six Months EndedJune 30, 2014 and 2013Exploration and production earnings decreased$13.2 million (25 percent) due to:

• A loss of $14.3 million (after tax) resulting from a realized commodity derivative loss in 2014 compared to a realized commodity derivative gain in 2013

• Unrealized loss on commodity derivatives of $7.5 million (after tax) in 2014 compared to an unrealized gain on commodity derivatives of $4.6 million (after tax) in 2013

• Higher depreciation, depletion and amortization expense of $8.9 million (after tax), primarily related to higher depletion rates

• Decreased natural gas production of 19 percent, largely due to the sale of non-strategic assets

• Higher lease operating expenses of $3.3 million (after tax), primarily in the Paradox Basin and Bakken areas

• Higher general and administrative expenses of $2.0 million (after tax), primarily related to higher professional services and higher payroll-related costs

Partially offsetting these decreases were:

• Increased oil production of 14 percent, primarily related to drilling activity in the Paradox Basin and the Powder River Basin acquisition

• Higher average realized natural gas prices of 52 percent, excluding gain/loss on commodity derivatives

• Higher average realized oil prices of 3 percent, excluding gain/loss on commodity derivatives

Construction Materials and Contracting

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2014		2013		2014			2013
	(Dollars in millions)
Operating revenues	$	442.6	$	431.3	$	611.0		$	597.6
Operating expenses:
Operation and maintenance	393.4		381.2		569.1			547.9
Depreciation, depletion and amortization	17.4		18.7		35.0			37.7
Taxes, other than income	10.6		10.6		18.9			19.1
	421.4		410.5		623.0			604.7
Operating income (loss)	21.2		20.8		(12.0		)	(7.1		)
Earnings (loss)	$	10.6	$	10.0	$	(13.0	)	$	(10.5	)
Sales (000's):
Aggregates (tons)	6,971		6,152		9,800			9,110
Asphalt (tons)	1,474		1,518		1,658			1,667
Ready-mixed concrete (cubic yards)	907		846		1,404			1,326

Three Months Ended June 30, 2014 and 2013 Construction materials and contracting earnings increased$600,000 (5 percent) due to higher earnings of $2.0 million (after tax) resulting from higher aggregate margins and volumes, partially offset by lower earnings resulting from lower construction margins.

39

Six Months EndedJune 30, 2014 and 2013Construction materials and contracting experienced a loss of $13.0 million compared to a loss of $10.5 million a year ago (a 23 percentdecline). The decline was the result of:

• Lower earnings of $4.7 million (after tax) resulting from lower construction revenues and margins

• Higher selling, general and administrative expenses of $1.8 million (after tax), including higher labor and insurance costs

Partially offsetting the decline were:

• Higher earnings of $2.3 million (after tax) resulting from higher aggregate margins

• Higher earnings resulting from higher other product line margins

• Higher earnings of $600,000 (after tax) resulting from higher asphalt margins

Construction Services

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2014		2013		2014		2013
	(In millions)
Operating revenues	$	282.3	$	279.6	$	556.0	$	511.0
Operating expenses:
Operation and maintenance	246.5		245.9		480.6		444.3
Depreciation, depletion and amortization	3.2		3.0		6.4		6.0
Taxes, other than income	8.3		8.4		18.5		18.0
	258.0		257.3		505.5		468.3
Operating income	24.3		22.3		50.5		42.7
Earnings	$	14.3	$	12.9	$	30.9	$	24.6

Three Months Ended June 30, 2014 and 2013 Construction services earnings increased$1.4 million (11 percent) due to higher margins in the Central region, primarily related to outside work.

Six Months EndedJune 30, 2014 and 2013Construction services earnings increased$6.3 million (26 percent) due to:

• Higher workloads and margins in the Western region and higher margins in the Central region, both primarily related to outside work

• Higher electrical supply sales and margins

Partially offsetting these increases were higher selling, general and administrative expense of $1.4 million (after tax), primarily related to higher payroll-related costs.

40

Other

	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2014		2013			2014		2013
	(In millions)
Operating revenues	$	2.2	$	2.3		$	4.3	$	4.5
Operating expenses:
Operation and maintenance	1.1		1.4			2.5		2.7
Depreciation, depletion and amortization	.6		.5			1.1		1.0
Taxes, other than income	—		—			—		.1
	1.7		1.9			3.6		3.8
Operating income	.5		.4			.7		.7
Income from continuing operations	1.1		.5			1.3		.9
Income (loss) from discontinued operations, net of tax	.5		(.1		)	.5		(.2		)
Earnings	$	1.6	$	.4		$	1.8	$	.7

Three Months Ended June 30, 2014 and 2013 Other earnings increased$1.2 million, including the effects of the vacation of an arbitration award which is included in discontinued operations as discussed in Note 21.

Six Months EndedJune 30, 2014 and 2013Other earnings increased$1.1 million, as previously discussed.

Intersegment Transactions

Amounts presented in the preceding tables will not agree with the Consolidated Statements of Income due to the Company's elimination of intersegment transactions. The amounts relating to these items are as follows:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2014		2013		2014		2013
	(In millions)
Intersegment transactions:
Operating revenues	$	35.3	$	37.7	$	83.9	$	73.9
Purchased natural gas sold	17.7		19.1		56.3		46.1
Operation and maintenance	16.0		15.2		25.3		24.4
Depreciation, depletion and amortization	.2		—		.4		—
Earnings on common stock	.9		2.1		1.2		2.1

For more information on intersegment eliminations, see Note 18.

PROSPECTIVE INFORMATION

The following information highlights the key growth strategies, projections and certain assumptions for the Company and its subsidiaries and other matters for certain of the Company's businesses. Many of these highlighted points are "forward-looking statements." There is no assurance that the Company's projections, including estimates for growth and changes in earnings, will in fact be achieved. Please refer to assumptions contained in this section, as well as the various important factors listed in Part II, Item 1A - Risk Factors, as well as Part I, Item 1A - Risk Factors in the 2013 Annual Report. Changes in such assumptions and factors could cause actual future results to differ materially from the Company's growth and earnings projections.

MDU Resources Group, Inc.

• Adjusted earnings per common share for 2014, diluted, are projected in the range of $1.50 to $1.65, excluding discontinued operations and the unrealized loss of $7.5 million (after tax) on commodity derivatives. Including these adjustments, GAAP earnings guidance for 2014 is in the same range. Unrealized commodity derivatives fair values can fluctuate causing actual GAAP earnings to vary accordingly.

The Company believes that these non-GAAP financial measures are useful because the items excluded are not indicative of the Company's continuing operating results. Also, the Company's management uses these non-GAAP financial measures as

41

indicators for planning and forecasting future periods. The presentation of this additional information is not meant to be considered a substitute for financial measures prepared in accordance with GAAP.

• The Company's long-term compound annual growth goals on earnings per share from operations are in the range of 7 to 10 percent.

• The Company continually seeks opportunities to expand through organic growth opportunities and strategic acquisitions.

• The Company focuses on creating value through vertical integration between its business units.

• Estimated gross capital expenditures for 2014 are approximately $1.1 billion. The estimate excludes noncontrolling interest capital expenditures related to Dakota Prairie Refining.

Electric and natural gas distribution

• Rate base growth is projected to be approximately 9 percent compounded annually over the next five years, including plans for an approximate $1.3 billion capital investment program.

• Regulatory actions

◦ The Company filed an application February 27, 2014, with the NDPSC requesting approval for a generation resource recovery rider for $7.4 million to recover costs associated with the 88-MW simple-cycle natural gas turbine and associated facilities currently under construction. The estimated project cost is $77 million and the projected in-service date is third quarter 2014. It is located adjacent to the Company's Heskett Generating Station near Mandan, North Dakota. The capacity is necessary to meet the requirements of the Company's integrated electric system customers and will be a partial replacement for third-party contract capacity expiring in 2015. On March 12, 2014, the NDPSC suspended the filing pending further review and a hearing was held May 28, 2014. A work session was held July 18, 2014, to discuss the request. Advance determination of prudence and a Certificate of Public Convenience and Necessity have been received from the NDPSC. For more information, see Note 20.

◦ The Company filed an application September 18, 2013, with the NDPSC for a natural gas rate increase, as discussed in Note 20.

◦ The Company submitted a request April 8, 2014, to the NDPSC to update an environmental cost recovery rider related to costs resulting from the environmental retrofit required to be installed at the Big Stone Station to reflect actual costs incurred through February 2014 and projected costs through June 2015. The NDPSC approved the rider July 10, 2014, for recovery of $8.6 million annually. The Company's share of the cost for the installation is approximately $90 million and is expected to be complete in 2015. The NDPSC had earlier approved advance determination of prudence for recovery of costs on the system. For more information, see Note 20.

• Investments are being made in 2014 totaling approximately $80 million to serve the growing electric and natural gas customer base associated with the Bakken oil development where customer growth is substantially higher than the national average.

• The Company is engaged in a 30-mile, approximately $60 million natural gas line project into the Hanford Nuclear Site in Washington.

• The Company, along with a partner, expects to build a 345-kilovolt transmission line from Ellendale, North Dakota, to Big Stone City, South Dakota, about 160 miles. The Company’s share of the cost is estimated at approximately $170 million. The project is a MISO multi-value project. A route application was filed in August 2013 with the state of South Dakota, and in October 2013 with the state of North Dakota. A route permit was approved in North Dakota on July 10, 2014. A route permit hearing was held June 10, 2014, in South Dakota. The project is expected to be complete in 2019.

• The Company is analyzing potential projects for accommodating load growth in its industrial and agricultural sectors, with company- and customer-owned pipeline facilities designed to serve existing facilities served by fuel oil or propane, and to serve new customers.

• The Company is involved with a number of pipeline projects to enhance the reliability and deliverability of its system in the Pacific Northwest and Idaho.

42

Pipeline and energy services

• The Company, in conjunction with Calumet, formed Dakota Prairie Refining, to develop, build and operate Dakota Prairie Refinery. Construction began on the facility in late March 2013 and it is approximately 75 percent complete. When complete, it will process Bakken crude into diesel, which will be marketed within the Bakken region. Other by-products, naphtha and atmospheric tower bottoms, will be railed to other areas. The total project cost estimate is approximately $350 million, with a projected in-service date in late 2014. EBITDA for the first year of operation is projected to be in the range of $70 million to $90 million, to be shared equally with Calumet.

• In January 2014, the Company launched an open season to obtain capacity commitments on a proposed 375-mile natural gas pipeline from western North Dakota to northwestern Minnesota to transport natural gas to markets in eastern North Dakota, Minnesota, Wisconsin, Michigan and other Midwest markets. The pipeline is expected to provide access to additional markets via interconnections with pipelines owned by Great Lakes Gas Transmission, Viking Gas Transmission and potentially TransCanada, in northwestern Minnesota. An interconnection with the Alliance Pipeline system in eastern North Dakota also is possible. Initially the pipeline would transport approximately 400 MMcf per day of natural gas and could be expanded to more than 500 MMcf per day. The project investment is estimated to be approximately $650 million. The open season ended May 30, 2014, and the Company is evaluating the responses received and working with those parties as well as other interested parties. The Company expects to provide a status update on its efforts by this fall. If the project moves forward, following the receipt of necessary permits and regulatory approvals, construction on the new pipeline could begin in 2016 with completion expected in 2017.

• On October 31, 2013, WBI Energy Transmission filed a Section 4 rate case with the FERC, as discussed in Note 20.

• The Company is engaged in various natural gas pipeline projects to be constructed in 2014, including connections for the planned Garden Creek II natural gas processing plant in the Bakken, an expansion of its transmission system to increase capacity to the Black Hills, and a 24-mile pipeline and related processing facilities to transport Fidelity's Paradox basin natural gas production. The total cost for these projects is approximately $50 million.

• The Company continues to pursue expansion of facilities and services offered to customers. Energy development within its geographic region is expanding, most notably in the Bakken area, where the Company owns an extensive natural gas pipeline system. Ongoing energy development is expected to continue to provide growth opportunities for this business.

Exploration and production

• The Company expects to spend approximately $620 million in gross capital expenditures in 2014, which is likely to be partially offset by the expected sale of certain Mountrail County, North Dakota assets and other planned asset sales this year.

• For 2014, the Company now expects a 10 to 15 percent increase in oil production, lower than its earlier estimate primarily the result of the expected sale of certain Mountrail County assets. NGL production is expected to decline 20 to 25 percent and natural gas production is expected to be 20 to 25 percent lower compared to a year ago. The declines are primarily the result of the divestment of certain non-strategic natural gas-based properties in 2013 and the expected divestment of the Company's South Texas assets this year. The vast majority of the capital program is focused on growing oil production.

• The Company has a total of three operated drilling rigs deployed on its acreage with two deployed in the Bakken area and one in the Paradox area. There are two non-operated rigs deployed on the Company's Powder River Basin acreage.

• Bakken areas

◦ The Company owns a total of approximately 108,500 net acres of leaseholds in Mountrail and Stark counties, North Dakota and Richland County, Montana, assuming the divestment of 4,363 net acres in Mountrail County. The Middle Bakken and Three Forks formations are targeted in North Dakota and the Red River formation is targeted in Montana.

◦ Capital expenditures are expected to total approximately $125 million in 2014, excluding the proceeds from the pending sale of Mountrail County acreage.

◦ Net oil production for the second quarter was approximately 7,600 BOPD.

◦ The Company has been testing two alternative completion techniques; plug and perforation and coil tubing with cemented liners. The coil tubing with cemented liner technique is encouraging and focus is on optimizing this approach.

43

• Paradox Basin, Utah

◦ The Company owns approximately 140,000 net acres of leaseholds, including its acquisitions of 35,000 net acres of leaseholds in February 2014, and 11,000 net acres of leaseholds in April 2014 and has an option to earn another 20,000 acres.

◦ Capital expenditures are expected to total approximately $150 million in 2014.

◦ Well costs range from $8 million to $11 million per well depending upon lateral lengths. Estimated ultimate recoveries are increasing with the upper range now at 1.7 MMBbls of oil per well.

◦ The Cane Creek Unit 12-1 well has cumulative production of 740 MBbls of oil since it began producing in September 2012. Artificial lift facilities have recently been installed.

◦ Net oil production for second quarter was approximately 3,290 BOPD, up 42 percent from second quarter 2013 and down 8 percent from first quarter 2014. Operational issues/downtime on several high-rate wells occurred during the quarter, which have now been broadly resolved with the installation of artificial lift. Drilling on multi-well pads, which defers completion, and two low-rate fringe acreage tests have delayed production growth. Higher growth is expected in third quarter 2014. The second drilling rig will return when sufficient permits are in place to sustain two rigs.

◦ The Company's understanding of this play continues to improve. It is anticipated that this field will play a key role in the Company's oil growth strategy.

• Powder River Basin, Wyoming

◦ In March 2014, the Company acquired 24,500 net acres of leaseholds in Converse County, Wyoming.

◦ Capital expenditures are expected to total approximately $260 million in 2014, including the acquisition costs, related closing adjustments and drilling capital.

◦ Net production for the second quarter 2014 was 2,000 BOE per day (75 percent oil), up 23 percent from late March 2014 average net production of 1,630 BOE per day.

• Earnings guidance reflects estimated average NYMEX index prices for August through December 2014 in the range of $96 to $102 per Bbl of crude oil, and $4.00 to $5.00 per Mcf of natural gas. Estimated prices for NGL are in the range of $37 to $40 per Bbl.

• Derivatives:

◦ For July through December 2014, 12,000 BOPD at a weighted average price of $96.47.

◦ For July through December 2014, 40,000 MMBtu of natural gas per day at a weighted average price of $4.10.

◦ For January through March 2015, 3,000 BOPD at a weighted average price of $98.00.

◦ For 2015, 10,000 MMBtu of natural gas per day at a weighted average price of $4.28.

◦ The commodity derivative instruments that are in place as of August 1, 2014, are summarized in the following chart:

44

Commodity	Type	Index	Period Outstanding	Forward Notional Volume (Bbl/MMBtu)	Price (Per Bbl/MMBtu)
Crude Oil	Swap	NYMEX	7/14 - 12/14	184,000	$94.05
Crude Oil	Swap	NYMEX	7/14 - 12/14	184,000	$95.00
Crude Oil	Swap	NYMEX	7/14 - 9/14	184,000	$95.75
Crude Oil	Swap	NYMEX	7/14 - 9/14	184,000	$96.00
Crude Oil	Swap	NYMEX	7/14 - 9/14	92,000	$96.25
Crude Oil	Swap	NYMEX	7/14 - 12/14	184,000	$94.25
Crude Oil	Swap	NYMEX	7/14 - 12/14	184,000	$95.00
Crude Oil	Swap	NYMEX	7/14 - 12/14	184,000	$95.25
Crude Oil	Swap	NYMEX	7/14 - 12/14	368,000	$96.00
Crude Oil	Swap	NYMEX	10/14 - 12/14	276,000	$100.50
Crude Oil	Swap	NYMEX	10/14 - 12/14	184,000	$101.50
Crude Oil	Swap	NYMEX	1/15 - 3/15	270,000	$98.00
Natural Gas	Swap	NYMEX	7/14 - 12/14	3,680,000	$4.13
Natural Gas	Swap	NYMEX	7/14 - 12/14	1,840,000	$4.05
Natural Gas	Swap	NYMEX	7/14 - 12/14	1,840,000	$4.10
Natural Gas	Swap	NYMEX	1/15 - 12/15	3,650,000	$4.28

Construction materials and contracting

• Approximate work backlog as of June 30, 2014, was $764 million, compared to $730 million a year ago. Private work represents 11 percent of construction backlog and public work represents 89 percent of backlog. The backlog includes a variety of projects such as highway grading, paving and underground projects, airports, bridge work and subdivisions.

• The Company's approximate backlog in North Dakota as of June 30, 2014, was $158 million. North Dakota backlog was $165 million a year ago.

• Projected revenues included in the Company's 2014 earnings guidance are in the range of $1.6 billion to $1.8 billion.

• The Company anticipates margins in 2014 to be in line with 2013 margins.

• The Company continues to pursue opportunities for expansion in energy projects such as refineries, transmission, wind towers and geothermal. Initiatives are aimed at capturing additional market share and expanding into new markets.

• As the country's fifth-largest sand and gravel producer, the Company will continue to strategically manage its 1.1 billion tons of aggregate reserves in all its markets, as well as take further advantage of being vertically integrated.

• Of the seven labor contracts that Knife River was negotiating, as reported in Items 1 and 2 - Business and Properties - General in the 2013 Annual Report, six have been ratified. The one remaining contract is still in negotiation.

Construction services

• Approximate work backlog as of June 30, 2014, was $386 million, compared to $447 million a year ago. The backlog includes a variety of projects such as substation and line construction, solar and other commercial, institutional and industrial projects including refinery work.

• The Company's approximate backlog in North Dakota as of June 30, 2014, was $11 million. The construction services business did not have any backlog in North Dakota a year ago.

• Projected revenues included in the Company's 2014 earnings guidance are in the range of $1.1 billion to $1.2 billion.

• The Company anticipates margins in 2014 to be in line with 2013 margins.

45

• The Company continues to pursue opportunities for expansion in energy projects such as refineries, transmission, substations, utility services, as well as solar. Initiatives are aimed at capturing additional market share and expanding into new markets.

NEW ACCOUNTING STANDARDS

For information regarding new accounting standards, see Note 8, which is incorporated by reference.

CRITICAL ACCOUNTING POLICIES INVOLVING SIGNIFICANT ESTIMATES

The Company's critical accounting policies involving significant estimates include impairment testing of oil and natural gas properties, impairment testing of long-lived assets and intangibles, revenue recognition, pension and other postretirement benefits, and income taxes. There were no material changes in the Company's critical accounting policies involving significant estimates from those reported in the 2013 Annual Report. For more information on critical accounting policies involving significant estimates, see Part II, Item 7 in the 2013 Annual Report.

LIQUIDITY AND CAPITAL COMMITMENTS

At June 30, 2014, the Company had cash and cash equivalents of $90.3 million and available capacity of $669.8 million under the outstanding credit facilities of the Company and its subsidiaries. The Company expects to meet its obligations for debt maturing within one year from various sources, including internally generated funds; the Company's credit facilities, as described later; and through the issuance of long-term debt and the Company's equity securities.

Cash flows

Operating activitiesThe changes in cash flows from operating activities generally follow the results of operations as discussed in Financial and Operating Data and also are affected by changes in working capital.

Cash flows provided by operating activities in the first six months of 2014 decreased$23.4 million from the comparable period in 2013 primarily due to higher income taxes paid.

Investing activities Cash flows used in investing activities in the first six months of 2014increased$175.2 million from the comparable period in 2013. The increase in cash flows used in investing activities was primarily due to higher acquisition-related capital expenditures at the exploration and production business; offset in part by lower ongoing capital expenditures at the exploration and production business.

Financing activities Cash flows provided by financing activities in the first six months of 2014increased$177.5 million from the comparable period in 2013. The increase in cash flows provided by financing activities was primarily due to the issuance of $132.3 million of common stock; as well as lower repayment of long-term debt of $102.9 million. Partially offsetting this increase were higher dividends paid in 2014 compared to 2013 due to the acceleration of the first quarter 2013 quarterly common stock dividend to 2012.

Defined benefit pension plans

There were no material changes to the Company's qualified noncontributory defined benefit pension plans from those reported in the 2013 Annual Report. For more information, see Note 19 and Part II, Item 7 in the 2013 Annual Report.

Capital expenditures

Net capital expenditures for the first six months of 2014 were $579.2 million and are estimated to be approximately $863 million for 2014. Estimated capital expenditures include:

• System upgrades

• Routine replacements

• Service extensions

• Routine equipment maintenance and replacements

• Buildings, land and building improvements

• Pipeline, gathering and other midstream projects

• Further development of existing properties, acquisition of additional leasehold acreage, exploratory drilling and proceeds from the sale of certain assets at the exploration and production segment

• Power generation and transmission opportunities, including certain costs for additional electric generating capacity

• Environmental upgrades

• The Company's proportionate share of Dakota Prairie Refinery at the pipeline and energy services segment

• Other growth opportunities

46

The Company continues to evaluate potential future acquisitions and other growth opportunities; however, they are dependent upon the availability of economic opportunities and, as a result, capital expenditures may vary significantly from the estimated 2014 capital expenditures referred to previously. The Company expects the 2014 estimated capital expenditures to be funded by various sources, including internally generated funds; the Company's credit facilities, as described later; and through the issuance of long-term debt and the Company's equity securities.

Capital resources

Certain debt instruments of the Company and its subsidiaries, including those discussed later, contain restrictive covenants and cross-default provisions. In order to borrow under the respective credit agreements, the Company and its subsidiaries must be in compliance with the applicable covenants and certain other conditions, all of which the Company and its subsidiaries, as applicable, were in compliance with at June 30, 2014. In the event the Company and its subsidiaries do not comply with the applicable covenants and other conditions, alternative sources of funding may need to be pursued. For more information on the covenants, certain other conditions and cross-default provisions, see Note 16 and Part II, Item 8 - Note 9, in the 2013 Annual Report.

The following table summarizes the outstanding revolving credit facilities of the Company and its subsidiaries at June 30, 2014:

Company	Facility		Facility Limit			Amount Outstanding			Letters of Credit			Expiration Date
			(In millions)
MDU Resources Group, Inc.	Commercial paper/ Revolving credit agreement	(a)	$	175.0		$	79.0	(b)	$	—		5/8/19
Cascade Natural Gas Corporation	Revolving credit agreement		$	50.0	(c)	$	—		$	2.2	(d)	7/9/18
Intermountain Gas Company	Revolving credit agreement		$	65.0	(e)	$	—		$	—		7/13/18
Centennial Energy Holdings, Inc.	Commercial paper/ Revolving credit agreement	(f)	$	650.0		$	189.0	(b)	$	—		5/8/19

(a) The commercial paper program is supported by a revolving credit agreement with various banks (provisions allow for increased borrowings, at the option of the Company on stated conditions, up to a maximum of $225.0 million). There were no amounts outstanding under the credit agreement.

(b) Amount outstanding under commercial paper program.

(c) Certain provisions allow for increased borrowings, up to a maximum of $75.0 million.

(d) The outstanding letter of credit, as discussed in Note 21, reduces the amount available under the credit agreement.

(e) Certain provisions allow for increased borrowings, up to a maximum of $90.0 million.

(f) The commercial paper program is supported by a revolving credit agreement with various banks (provisions allow for increased borrowings, at the option of Centennial on stated conditions, up to a maximum of $800.0 million). There were no amounts outstanding under the credit agreement.

The Company's and Centennial's respective commercial paper programs are supported by revolving credit agreements. While the amount of commercial paper outstanding does not reduce available capacity under the respective revolving credit agreements, the Company and Centennial do not issue commercial paper in an aggregate amount exceeding the available capacity under their credit agreements. The commercial paper borrowings may vary during the period, largely the result of fluctuations in working capital requirements due to the seasonality of the construction businesses.

The following includes information related to the preceding table.

MDU Resources Group, Inc. On May 8, 2014, the Company amended the revolving credit agreement to increase the borrowing limit to $175.0 million and extend the termination date to May 8, 2019. The Company's revolving credit agreement supports its commercial paper program. Commercial paper borrowings under this agreement are classified as long-term debt as they are intended to be refinanced on a long-term basis through continued commercial paper borrowings. The Company's objective is to maintain acceptable credit ratings in order to access the capital markets through the issuance of commercial paper. Downgrades in the Company's credit ratings have not limited, nor are currently expected to limit, the Company's ability

47

to access the capital markets. If the Company were to experience a downgrade of its credit ratings, it may need to borrow under its credit agreement and may experience an increase in overall interest rates with respect to its cost of borrowings.

Prior to the maturity of the credit agreement, the Company expects that it will negotiate the extension or replacement of this agreement. If the Company is unable to successfully negotiate an extension of, or replacement for, the credit agreement, or if the fees on this facility become too expensive, which the Company does not currently anticipate, the Company would seek alternative funding.

The Company's coverage of fixed charges including preferred stock dividends was 4.8 times for the 12 months ended June 30, 2014 and December 31, 2013. Due to the $246.8 million after-tax noncash write-downs of oil and natural gas properties in 2012, earnings were insufficient by $19.8 million to cover fixed charges for the 12 months ended June 30, 2013. If the $246.8 million after-tax noncash write-downs were excluded, the coverage of fixed charges including preferred stock dividends would have been 4.5 times for the 12 months ended June 30, 2013.

The coverage of fixed charges including preferred stock dividends, that excludes the effect of the after-tax noncash write-downs of oil and natural gas properties is a non-GAAP financial measure. The Company believes that this non-GAAP financial measure is useful because the write-downs excluded are not indicative of the Company's cash flows available to meets its fixed charges obligations. The presentation of this additional information is not meant to be considered a substitute for the financial measure prepared in accordance with GAAP.

Total equity as a percent of total capitalization was 58 percent, 57 percent and 60 percent at June 30, 2014 and 2013 and December 31, 2013, respectively. This ratio is calculated as the Company's total equity, divided by the Company's total capital. Total capital is the Company's total debt, including short-term borrowings and long-term debt due within one year, plus total equity. This ratio indicates how a company is financing its operations, as well as its financial strength.

On May 20, 2013, the Company entered into an Equity Distribution Agreement with Wells Fargo Securities, LLC with respect to the issuance and sale of up to 7.5 million shares of the Company's common stock. The common stock may be offered for sale, from time to time, in accordance with the terms and conditions of the agreement. Sales of such common stock may not be made after February 28, 2016. Proceeds from the shares of common stock under the agreement have been and are expected to be used for corporate development purposes and other general corporate purposes. Under the Equity Distribution Agreement, the Company issued 2.2 million shares of stock between April 1, 2014 and June 30, 2014, receiving net proceeds of $72.3 million, 3.7 million shares of stock between January 1, 2014 and June 30, 2014, receiving net proceeds of $122.4 million and a total of 4.2 million shares of stock as of June 30, 2014, receiving net proceeds of $137.0 million.

The Company currently has a shelf registration statement on file with the SEC, under which the Company may issue and sell any combination of common stock and debt securities. The Company may sell all or a portion of such securities if warranted by market conditions and the Company's capital requirements. Any public offer and sale of such securities will be made only by means of a prospectus meeting the requirements of the Securities Act and the rules and regulations thereunder. The Company's board of directors currently has authorized the issuance and sale of up to an aggregate of $1.0 billion worth of such securities. The Company's board of directors reviews this authorization on a periodic basis and the aggregate amount of securities authorized may be increased in the future.

The Company entered into a $150.0 million note purchase agreement on January 28, 2014. On April 15, 2014, the Company issued $50.0 million of Senior Notes with a due date of April 15, 2044, at an interest rate of 5.2 percent. The remaining $100.0 million of Senior Notes was issued on July 15, 2014, with due dates ranging from July 15, 2024 to July 15, 2026, at a weighted average interest rate of 4.3 percent.

Centennial Energy Holdings, Inc. On May 8, 2014, Centennial entered into an amended and restated revolving credit agreement which increased the borrowing limit to $650.0 million and extended the termination date to May 8, 2019. The credit agreement contains customary covenants and provisions, including a covenant of Centennial not to permit, as of the end of any fiscal quarter, the ratio of total consolidated debt to total consolidated capitalization to be greater than 65 percent. Other covenants include restrictions on the sale of certain assets, limitations on subsidiary indebtedness and the making of certain loans and investments.

Centennial's revolving credit agreement contains cross-default provisions. These provisions state that if Centennial or any subsidiary of Centennial fails to make any payment with respect to any indebtedness or contingent obligation, in excess of a specified amount, under any agreement that causes such indebtedness to be due prior to its stated maturity or the contingent obligation to become payable, the agreement will be in default.

48

Centennial's revolving credit agreement supports its commercial paper program. Commercial paper borrowings under this agreement are classified as long-term debt as they are intended to be refinanced on a long-term basis through continued commercial paper borrowings. Centennial's objective is to maintain acceptable credit ratings in order to access the capital markets through the issuance of commercial paper. Downgrades in Centennial's credit ratings have not limited, nor are currently expected to limit, Centennial's ability to access the capital markets. If Centennial were to experience a downgrade of its credit ratings, it may need to borrow under its credit agreement and may experience an increase in overall interest rates with respect to its cost of borrowings.

Prior to the maturity of the Centennial credit agreement, Centennial expects that it will negotiate the extension or replacement of this agreement, which provides credit support to access the capital markets. In the event Centennial is unable to successfully negotiate this agreement, or in the event the fees on this facility become too expensive, which Centennial does not currently anticipate, it would seek alternative funding.

Centennial entered into two separate two year $125.0 million term loan agreements with variable interest rates on March 31, 2014 and April 2, 2014, respectively. These agreements contain customary covenants and default provisions, including covenants not to permit, as of the end of any fiscal quarter, the ratio of Centennial's total debt to total capitalization to be greater than 65 percent. The covenants also include certain limitations on subsidiary indebtedness and restrictions on the sale of certain assets and on the making of certain loans and investments.

WBI Energy Transmission, Inc. WBI Energy Transmission has a $175.0 million amended and restated uncommitted long-term private shelf agreement with an expiration date of September 12, 2016. WBI Energy Transmission had $100.0 million of notes outstanding at June 30, 2014, which reduced capacity under this uncommitted private shelf agreement.

Off balance sheet arrangements

In connection with the sale of the Brazilian Transmission Lines, Centennial has agreed to guarantee payment of any indemnity obligations of certain of the Company's indirect wholly owned subsidiaries who are the sellers in three purchase and sale agreements for periods ranging up to 10 years from the date of sale. The guarantees were required by the buyers as a condition to the sale of the Brazilian Transmission Lines. For more information, see Note 12.

Centennial continues to guarantee CEM's obligations under a construction contract for an electric generating facility near Hobbs, New Mexico. For more information, see Note 21.

Contractual obligations and commercial commitments

There are no material changes in the Company's contractual obligations relating to estimated interest payments, operating leases, purchase commitments, derivatives, asset retirement obligations, uncertain tax positions and minimum funding requirements for its defined benefit plans for 2014 from those reported in the 2013 Annual Report.

The Company's contractual obligations relating to long-term debt at June 30, 2014, increased $332.5 million or 18 percent from December 31, 2013. As of June 30, 2014, the Company's contractual obligations related to long-term debt aggregated $2,187.1 million. The scheduled amounts of redemption (for the twelve months ended June 30, of each year listed) aggregate $42.2 million in 2015; $669.2 million in 2016; $116.0 million in 2017; $63.0 million in 2018; $382.4 million in 2019; and $914.3 million thereafter.

For more information on contractual obligations and commercial commitments, see Part II, Item 7 in the 2013 Annual Report.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

The Company is exposed to the impact of market fluctuations associated with commodity prices, interest rates and foreign currency. The Company has policies and procedures to assist in controlling these market risks and utilizes derivatives to manage a portion of its risk.

For more information on derivative instruments and commodity price risk, see Part II, Item 7A in the 2013 Annual Report, the Consolidated Statements of Comprehensive Income and Notes 9 and 14.

Commodity price risk

Fidelity utilizes derivative instruments to manage a portion of the market risk associated with fluctuations in the price of oil and natural gas on forecasted sales of oil and natural gas production.

49

The following table summarizes derivative agreements entered into by Fidelity as of June 30, 2014. These agreements call for Fidelity to receive fixed prices and pay variable prices.

	(Forward notional volume and fair value in thousands)
		Weighted Average Fixed Price (Per Bbl/MMBtu)		Forward Notional Volume (Bbl/MMBtu)	Fair Value
Oil swap agreements maturing in 2014		$	96.43	2,208	$	(14,793	)
Oil swap agreements maturing in 2015		$	98.00	270	$	(374	)
Natural gas swap agreements maturing in 2014		$	4.10	7,360	$	(2,282	)
Natural gas swap agreement maturing in 2015		$	4.28	3,650	$	260

Interest rate risk

There were no material changes to interest rate risk faced by the Company from those reported in the 2013 Annual Report.

At June 30, 2014, the Company had no outstanding interest rate hedges.

Foreign currency risk

The Company's investment in ECTE is exposed to market risks from changes in foreign currency exchange rates between the U.S. dollar and the Brazilian Real. For more information, see Part II, Item 8 - Note 4 in the 2013 Annual Report.

At June 30, 2014, the Company had no outstanding foreign currency hedges.

ITEM 4. CONTROLS AND PROCEDURES

The following information includes the evaluation of disclosure controls and procedures by the Company's chief executive officer and the chief financial officer, along with any significant changes in internal controls of the Company.

Evaluation of disclosure controls and procedures

The term "disclosure controls and procedures" is defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act. The Company's disclosure controls and other procedures are designed to provide reasonable assurance that information required to be disclosed in the reports that the Company files or submits under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC's rules and forms. The Company's disclosure controls and procedures include controls and procedures designed to provide reasonable assurance that information required to be disclosed is accumulated and communicated to management, including the Company's chief executive officer and chief financial officer, to allow timely decisions regarding required disclosure. The Company's management, with the participation of the Company's chief executive officer and chief financial officer, has evaluated the effectiveness of the Company's disclosure controls and procedures. Based upon that evaluation, the chief executive officer and the chief financial officer have concluded that, as of the end of the period covered by this report, such controls and procedures were effective at a reasonable assurance level.

Changes in internal controls

No change in the Company's internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) occurred during the quarter ended June 30, 2014, that has materially affected, or is reasonably likely to materially affect, the Company's internal control over financial reporting.

PART II -- OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

For information regarding legal proceedings, see Note 21, which is incorporated herein by reference.

50

ITEM 1A. RISK FACTORS

This Form 10-Q contains forward-looking statements within the meaning of Section 21E of the Exchange Act. Forward-looking statements are all statements other than statements of historical fact, including without limitation those statements that are identified by the words "anticipates," "estimates," "expects," "intends," "plans," "predicts" and similar expressions.

The Company is including the following factors and cautionary statements in this Form 10-Q to make applicable and to take advantage of the safe harbor provisions of the Private Securities Litigation Reform Act of 1995 for any forward-looking statements made by, or on behalf of, the Company. Forward-looking statements include statements concerning plans, objectives, goals, strategies, future events or performance, and underlying assumptions (many of which are based, in turn, upon further assumptions) and other statements that are other than statements of historical facts. From time to time, the Company may publish or otherwise make available forward-looking statements of this nature, including statements contained within Prospective Information. All these subsequent forward-looking statements, whether written or oral and whether made by or on behalf of the Company, also are expressly qualified by these factors and cautionary statements.

Forward-looking statements involve risks and uncertainties, which could cause actual results or outcomes to differ materially from those expressed. The Company's expectations, beliefs and projections are expressed in good faith and are believed by the Company to have a reasonable basis, including without limitation, management's examination of historical operating trends, data contained in the Company's records and other data available from third parties. Nonetheless, the Company's expectations, beliefs or projections may not be achieved or accomplished.

Any forward-looking statement contained in this document speaks only as of the date on which the statement is made, and the Company undertakes no obligation to update any forward-looking statement or statements to reflect events or circumstances that occur after the date on which the statement is made or to reflect the occurrence of unanticipated events. New factors emerge from time to time, and it is not possible for management to predict all of the factors, nor can it assess the effect of each factor on the Company's business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained in any forward-looking statement.

There are no material changes in the Company's risk factors from those reported in Part I, Item 1A - Risk Factors in the 2013 Annual Report other than the risk related to environmental laws and regulations and the risk that the Company's operations could be adversely impacted by initiatives to reduce GHG emissions. These factors and the other matters discussed herein are important factors that could cause actual results or outcomes for the Company to differ materially from those discussed in the forward-looking statements included elsewhere in this document.

Environmental and Regulatory Risks

The Company's operations are subject to environmental laws and regulations that may increase costs of operations, impact or limit business plans, or expose the Company to environmental liabilities.

The Company is subject to environmental laws and regulations affecting many aspects of its operations, including air quality, water quality, waste management and other environmental considerations. These laws and regulations can increase capital, operating and other costs, cause delays as a result of litigation and administrative proceedings, and create compliance, remediation, containment, monitoring and reporting obligations, particularly relating to electric generation operations and oil and natural gas development and processing. These laws and regulations generally require the Company to obtain and comply with a wide variety of environmental licenses, permits, inspections and other approvals. Although the Company strives to comply with all applicable environmental laws and regulations, public and private entities and private individuals may interpret the Company's legal or regulatory requirements differently and seek injunctive relief or other remedies against the Company. The Company cannot predict the outcome (financial or operational) of any such litigation or administrative proceedings.

Existing environmental laws and regulations may be revised and new laws and regulations seeking to protect the environment may be adopted or become applicable to the Company. These laws and regulations could require the Company to limit the use or output of certain facilities, restrict the use of certain fuels, install pollution controls, remediate environmental contamination, remove or reduce environmental hazards, or prevent or limit the development of resources. Revised or additional laws and regulations that increase compliance costs or restrict operations, particularly if costs are not fully recoverable from customers, could have a material adverse effect on the Company's results of operations and cash flows.

The EPA issued draft regulations that outline several possible approaches for coal combustion residuals management under the RCRA. One approach, designating coal ash as a hazardous waste, if adopted would significantly change the manner and increase the costs of managing coal ash at five plants that supply electricity to customers of Montana-Dakota. This designation

51

also could significantly increase costs for Knife River, which beneficially uses fly ash as a cement replacement in ready-mixed concrete and road base applications.

In December 2011, the EPA finalized the Mercury and Air Toxics Standards rules that will require reductions in mercury and other air emissions from coal- and oil-fired electric utility steam generating units. Montana-Dakota evaluated the pollution control technologies needed at its electric generation resources to comply with this rule and determined that the Lewis & Clark Station near Sidney, Montana, would require additional particulate matter control for non-mercury metal emissions. Montana-Dakota initially determined that the additional controls could be accomplished by installing a baghouse but later determined the baghouse is not currently an economically effective means of compliance. Montana-Dakota intends to comply with the rule by co-firing the plant with natural gas and lignite. Controls must be in place by April 16, 2015, or April 16, 2016, if a one-year extension is granted for completion of the pollution control project.

Hydraulic fracturing is an important common practice used by Fidelity that involves injecting water, sand, a water-thickening agent called guar, and trace amounts of chemicals, under pressure, into rock formations to stimulate oil, NGL and natural gas production. Fidelity follows state regulations for well drilling and completion, including regulations for hydraulic fracturing and recovered fluids disposal. Fracturing fluid constituents are reported on state or national websites. The EPA is developing a study to review potential effects of hydraulic fracturing on underground sources of drinking water; the results of that study could impact future legislation or regulation. The BLM has released draft well stimulation regulations for hydraulic fracturing operations. If implemented, the BLM regulations would affect only Fidelity's operations on BLM-administered lands. If adopted as proposed, the BLM regulations, along with other legislative initiatives and regulatory studies, proceedings or initiatives at federal or state agencies that focus on the hydraulic fracturing process, could result in additional compliance, reporting and disclosure requirements. Future legislation or regulation could increase compliance and operating costs, as well as delay or inhibit the Company's ability to develop its oil, NGL and natural gas reserves.

On August 16, 2012, the EPA published a final NSPS rule for the oil and natural gas industry. The NSPS rule phases in over two years. The first phase was effective October 15, 2012, and primarily covers natural gas wells that are hydraulically fractured. Under the new rule, gas vapors or emissions from the natural gas wells must be captured or combusted utilizing a high-efficiency device. Additional reporting requirements and control devices covering oil and natural gas production equipment will be phased in for certain new oil and gas facilities with a final effective date of January 1, 2015. This new rule's impacts on Fidelity, WBI Energy Transmission and WBI Energy Midstream are not expected to be material and are likely to include implementing recordkeeping, reporting and testing requirements and purchasing and installing required equipment.

Initiatives to reduce GHG emissions could adversely impact the Company's operations.

Concern that GHG emissions are contributing to global climate change has led to international, federal and state legislative and regulatory proposals to reduce or mitigate the effects of GHG emissions. On June 25, 2013, President Obama released his Climate Action Plan for the U.S. in which he stated his goal to reduce GHG emissions "in the range of 17 percent" below 2005 levels by 2020. The president issued a memorandum to the EPA on the same day, instructing the EPA to re-propose the GHG NSPS rule for new electric generation units. The EPA released the re-proposed rule on January 8, 2014, in the Federal Register, which takes the place of the rule proposed in 2012 for new electric generation units that the EPA did not finalize. This rule applies to new fossil fuel-fired electric generation units, including coal-fired units, natural gas-fired combined-cycle units and natural gas-fired simple-cycle peaking units. The EPA's 1,100 pounds of carbon dioxide per MW hour emissions standard for coal-fired units does not allow any new coal-fired electric generation to be constructed unless carbon dioxide is captured and sequestered.

President Obama also directed the EPA to develop a GHG NSPS standard for existing fossil fuel-fired electric generation units by June 1, 2014, with finalization by June 1, 2015. On June 18, 2014, the EPA published in the Federal Register a proposed rule limiting carbon dioxide emissions from existing fossil fuel-fired electric generating units and a separate proposed rule limiting carbon dioxide emissions from existing units that are modified or reconstructed.

In the existing source rule, the EPA requires carbon dioxide emission reductions from each state and instructs each state, or group of states that work together, to submit a plan to the EPA by June 30, 2016, that demonstrates how the state will achieve the targeted emission reductions by 2030. The state plans could include performance standards, emissions reductions or limits on generation for each existing fossil fuel-fired generating unit. It is unknown at this time what each state will require for emissions reductions from each Montana-Dakota owned and jointly owned fossil fuel-fired electric generating unit. In the EPA’s proposed GHG rule for modified or reconstructed fossil fuel-fired sources, the EPA proposes emissions limits that could potentially be unachievable. Montana-Dakota does not plan to modify or reconstruct any fossil fuel-fired units at this time, but may modify or reconstruct units in the future which must comply with the rule limitations.

52

The Company’s primary GHG emission is carbon dioxide from fossil fuels combustion at Montana-Dakota's electric generating facilities, particularly its coal-fired facilities. Approximately 70 percent of Montana-Dakota's owned generating capacity and more than 90 percent of the electricity it generates is from coal-fired facilities.

There may also be new treaties, legislation or regulations to reduce GHG emissions that could affect Montana-Dakota's electric utility operations by requiring additional energy conservation efforts or renewable energy sources, as well as other mandates that could significantly increase capital expenditures and operating costs. If Montana-Dakota does not receive timely and full recovery of GHG emission compliance costs from its customers, then such costs could adversely impact the results of its operations.

In addition to Montana-Dakota's electric generation operations, the GHG emissions from the Company's other operations are monitored, analyzed and reported as required by applicable laws and regulations. The Company monitors GHG regulations and the potential for GHG regulations to impact operations.

Due to the uncertain availability of technologies to control GHG emissions and the unknown obligations that potential GHG emission legislation or regulations may create, the Company cannot determine the potential financial impact on its operations.

ITEM 4. MINE SAFETY DISCLOSURES

For information regarding mine safety violations or other regulatory matters required by Section 1503(a) of the Dodd-Frank Act and Item 104 of Regulation S-K, see Exhibit 95 to this Form 10-Q, which is incorporated herein by reference.

ITEM 6. EXHIBITS

See the index to exhibits immediately preceding the exhibits filed with this report.

53

SIGNATURES

Pursuant to the requirements of the Exchange Act, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

		MDU RESOURCES GROUP, INC.
DATE:	August 8, 2014	BY:	/s/ Doran N. Schwartz
			Doran N. Schwartz
			Vice President and Chief Financial Officer
		BY:	/s/ Nathan W. Ring
			Nathan W. Ring
			Vice President, Controller and Chief Accounting Officer

54

EXHIBIT INDEX

Exhibit No.
4(a)	Second Amendment to Credit Agreement, dated May 8, 2014, among MDU Resources Group, Inc., Various Lenders, and Wells Fargo Bank, National Association, as Administrative Agent
4(b)	Third Amended and Restated Credit Agreement, dated May 8, 2014, among Centennial Energy Holdings, Inc., U.S. Bank National Association, as Administrative Agent, and The Several Financial Institutions party thereto
+10(a)	Instrument of Amendment to the MDU Resources Group, Inc. 401(k) Retirement Plan, dated June 5, 2014
+10(b)	Director Compensation Policy, as amended May 15, 2014
+10(c)	MDU Resources Group, Inc. Section 16 Officers and Directors with Indemnification Agreements Chart, as of July 15, 2014
12	Computation of Ratio of Earnings to Fixed Charges and Combined Fixed Charges and Preferred Stock Dividends
31(a)	Certification of Chief Executive Officer filed pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31(b)	Certification of Chief Financial Officer filed pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
32	Certification of Chief Executive Officer and Chief Financial Officer furnished pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
95	Mine Safety Disclosures
101	The following materials from MDU Resources Group, Inc.'s Quarterly Report on Form 10-Q for the quarter ended June 30, 2014, formatted in XBRL (eXtensible Business Reporting Language): (i) the Consolidated Statements of Income, (ii) the Consolidated Statements of Comprehensive Income, (iii) the Consolidated Balance Sheets, (iv) the Consolidated Statements of Cash Flows and (v) the Notes to Consolidated Financial Statements, tagged in summary and detail

+ Management contract, compensatory plan or arrangement.

MDU Resources Group, Inc. agrees to furnish to the SEC upon request any instrument with respect to long-term debt that MDU Resources Group, Inc. has not filed as an exhibit pursuant to the exemption provided by Item 601(b)(4)(iii)(A) of Regulation S-K.

55

EX-4.(A)

SECOND AMENDMENT

TO CREDIT AGREEMENT

This Amendment is entered into as of May 8, 2014 by and among MDU Resources Group, Inc., a Delaware corporation (the “Borrower”); Wells Fargo Bank, National Association, a national banking association, as administrative agent under the Credit Agreement described below (in such capacity, the “Administrative Agent”); and the undersigned Lenders (as defined in the Credit Agreement described below).

The Borrower, the Administrative Agent and the Lenders are parties to a Credit Agreement dated as of May 26, 2011 (as amended, supplemented, restated or otherwise modified from time to time, the “Credit Agreement”).

The Borrower has asked the Lenders to increase the amount available for borrowing under the Credit Agreement, to extend the term of the Credit Agreement and to modify certain other provisions thereof, and the Lenders are willing to do so on the terms and conditions set forth herein.

ACCORDINGLY, in consideration of the premises and of the mutual covenants and agreements herein contained, it is agreed as follows:

1.Definitions. All terms defined in the Credit Agreement that are not otherwise defined herein shall have the meanings given them in the Credit Agreement.

2.Amendments to Credit Agreement. The Credit Agreement is hereby amended as follows:

(a)The phrase, “$125,000,000 Revolving Credit Facility”, on the cover page of the Credit Agreement is hereby deleted, and the phrase, “$175,000,000 Revolving Credit Facility”, is substituted therefor.

(b)The definitions of the following terms in Section 1.1 of the Credit Agreement are hereby amended in their entirety to read, respectively, as follows:

“Aggregate Revolving Commitment Amount” means $175,000,000, as such amount may be reduced pursuant to Section 2.13 or increased pursuant to Section 2.14.

“Applicable Rating” means (i) with respect to S&P, the rating designated by S&P as its long-term corporate credit rating of the Borrower, and (ii) with respect to Fitch, the rating designated by Fitch as its rating of the Borrower’s senior unsecured debt.

“Fee Letters” means (i) the Fee Letter dated April 4, 2011 between the Administrative Agent, Wells Fargo Securities, LLC and the Borrower, (ii) the Fee Letter dated April 4, 2011 between Union Bank, N.A. and the Borrower, (iii) the Fee Letter dated September14, 2012 among the Administrative Agent, Wells Fargo Securities, LLC and the Borrower, (iv) the Fee Letter dated May 2, 2014 among the Administrative Agent, Wells Fargo Securities, LLC and the Borrower, (v) the Fee Letter dated May 2, 2014 between The Bank of Tokyo-Mitsubishi UFJ, Ltd. and the Borrower, and (vi) any separate agreements between the Borrower and the Administrative Agent after the date hereof that set forth the terms of fees to be paid by the Borrower to the Administrative Agent for the

US.53897791.05

Administrative Agent’s own behalf or for the benefit of the Lenders, as more fully set forth therein.

“LIBO Rate” means, with respect to an Interest Period, (a) the rate per annum determined by the Administrative Agent as of approximately 11:00 a.m. London time on the date 2 Business Days before the commencement of such Interest Period by reference to the London interbank offered rate administered by ICE Benchmark Administration Limited (or any other Person that takes over the administration of such rate and designated by the Administrative Agent) for deposits in dollars offered on the London interbank dollar market for a period corresponding to the term of such Interest Period and in an amount comparable to the aggregate amount of the relevant Loan (as displayed in the Bloomberg Financial Market System or any successor thereto or any other service selected by the Administrative Agent that has been nominated by ICE Benchmark Administration Limited as an authorized information vendor for the purpose of displaying such rates), or (b) if such rate cannot be determined, the rate per annum equal to the rate determined by the Administrative Agent in accordance with Section 2.4 to be a rate at which U.S. dollar deposits are offered to major banks in the London interbank eurodollar market for funds to be made available on the first day of such Interest Period and maturing at the end of such Interest Period.

“Maturity Date” means May 8, 2019.

“Maximum Aggregate Revolving Facility Amount” means $225,000,000, unless said amount is reduced pursuant to Section 2.13, in which event it means the amount to which said amount is reduced.

“S&P” means Standard & Poor’s Financial Services LLC, a subsidiary of The McGraw-Hill Companies, Inc., and any successor thereto.

(c)The table in Section 2.5(c) of the Credit Agreement is hereby amended in its entirety to read as follows:

	Level I	Level II	Level III	Level IV	Level V
ABR Loan Margin	0%	0%	0.075%	0.275%	0.475%
LIBOR Loan Margin	0.900%	1.000%	1.075%	1.275%	1.475%
Facility Fee Rate	0.100%	0.125%	0.175%	0.225%	0.275%

(d)    Section 4.2 of the Credit Agreement is hereby amended in its entirety to read as follows:

Section 4.2Authorization of Credit Extensions; No Conflict as to Law or Agreements.

- 2 -

US.53897791.05

The execution, delivery and performance by the Borrower of the Loan Documents, and the borrowings from time to time hereunder, have been duly authorized by all necessary corporate action and by all necessary public utilities commissions and any other regulatory bodies having jurisdiction over the Borrower (except as noted in Schedule 4.2 to the Agreement with respect to Borrowings made after September 12, 2015), and do not and will not (i) require any consent or approval of the stockholders of the Borrower, or any authorization, consent or approval by any governmental department, commission, board, bureau, agency or instrumentality, domestic or foreign, other than Authorizing Orders set forth in Schedule 4.2 that (except as noted therein with respect to Borrowings made after September 12, 2015) have been obtained and copies of which have been delivered to the Administrative Agent pursuant to Section 3.1, (ii) violate any provision of any law, rule or regulation (including, without limitation, Regulation T, U or X of the Board of Governors of the Federal Reserve System) or of any order, writ, injunction or decree presently in effect having applicability to the Borrower or of the articles of incorporation or bylaws of the Borrower, (iii) result in a breach of or constitute a default under any indenture or loan or credit agreement or any other agreement, lease or instrument to which the Borrower is a party or by which it or its properties may be bound or affected, or (iv) result in, or require, the creation or imposition of any Lien or other charge or encumbrance of any nature (other than those in favor of the Administrative Agent to secure one or more of the Obligations) upon or with respect to any of the properties now owned or hereafter acquired by the Borrower.

(e)Sections 4.5 through 4.8 of the Credit Agreement are hereby amended in their entirety to read as follows:

Section 4.5Financial Condition.

The Borrower has furnished to the Lenders its audited consolidated financial statement as of December 31, 2013, and its unaudited interim financial statement as of March 31, 2014. Those financial statements fairly present the financial condition of the Borrower and its Subsidiaries on the dates thereof and the results of their operations and cash flows for the periods then ended, and were prepared in accordance with GAAP, except as expressly noted therein.

Section 4.6Adverse Change.

There has been no material adverse change in the business, properties or condition (financial or otherwise) of the Borrower since December 31, 2013.

Section 4.7Litigation.

Except as set forth in the Borrower’s Annual Report on Form 10-K for the year ended December 31, 2013, or in any document subsequently filed pursuant to Section 13, 14 or 15(d) of the Exchange Act, there are no actions, suits or proceedings pending or, to the knowledge of the Borrower, threatened against or affecting the Borrower or the properties of the Borrower, before any court or governmental department, commission, board, bureau, agency or instrumentality, domestic or foreign, which, if determined adversely to the Borrower, would have a Material Adverse Effect.

- 3 -

US.53897791.05

Section 4.8Environmental Matters.

The Borrower conducts in the ordinary course of business a review of the effect of existing Environmental Laws and existing Environmental Claims on its business, operations and properties and, as a result thereof, the Borrower has reasonably concluded that such Environmental Laws and Environmental Claims could not, individually or in the aggregate, reasonably be expected to have a Material Adverse Effect, exclusive of Environmental Claims as set forth in the Borrower’s Annual Report on Form 10-K for the year ended December 31, 2013, or in any document subsequently filed pursuant to Section 13, 14 or 15(d) of the Exchange Act.

(f)Exhibit A to the Credit Agreement is hereby replaced in its entirety with Exhibit A to this Amendment.

(g)Schedule 4.2 to the Credit Agreement is hereby amended and restated as set forth in Schedule 4.2 to this Amendment.

(h)Schedule 4.4 to the Credit Agreement is hereby amended and restated as set forth in Schedule 4.4 to this Amendment.

3.New Lender. From and after the effective date of the amendments set forth in Section 2, KeyBank National Association (the “New Lender”) shall be a Lender under the Credit Agreement, as amended hereby, with a Commitment as set forth therein. The New Lender (a) represents and warrants that (i) it has full power and authority, and has taken all action necessary, to execute and deliver this Amendment and to consummate the transactions contemplated hereby and to become a Lender having its Commitment set forth the Credit Agreement as amended hereby, (ii) from and after the Effective Date, it shall be bound by the provisions of the Credit Agreement as a Lender thereunder and, to the extent of its Commitment and related interests, shall have the obligations of a Lender thereunder, (iii) it is sophisticated with respect to decisions to acquire assets of the type represented by its Commitment acquired hereby and it is experienced in acquiring assets of such type, (iv) it has received a copy of the Credit Agreement, and has received or has been accorded the opportunity to receive copies of the most recent financial statements delivered pursuant to Section 5.1 thereof, as applicable, and such other documents and information as it deems appropriate to make its own credit analysis and decision to enter into this Amendment and to become a Lender having the Commitment set forth in the Credit Agreement as amended hereby, and (iv) it has, independently and without reliance upon the Administrative Agent or any other Lender and based on such documents and information as it has deemed appropriate, made its own credit analysis and decision to enter into this Amendment and to become a Lender having the Commitment set forth in the Credit Agreement as amended hereby; and (b) agrees that (i) it will, independently and without reliance on the Administrative Agent or any other Lender, and based on such documents and information as it shall deem appropriate at the time, continue to make its own credit decisions in taking or not taking action under the Loan Documents, and (ii) it will perform in accordance with their terms all of the obligations which by the terms of the Loan Documents are required to be performed by it as a Lender. Without limiting the generality of the foregoing, the New Lender confirms that it has thereby appointed (and does hereby appoint) Wells Fargo to act on its behalf as the Administrative Agent and has thereby authorized (and does hereby authorize) the Administrative Agent to take such actions on its behalf and to exercise such powers as are delegated to the Administrative Agent by the terms of the Loan Documents, together with such actions and powers as are reasonably incidental thereto.

4.Replacement Notes. Concurrent with the execution of this Amendment, the Borrower shall execute and deliver to the Administrative Agent its promissory notes (the “Replacement Notes”) in

- 4 -

US.53897791.05

the form of Exhibit B to the Credit Agreement, dated the date hereof, payable to the order of each Lender in an amount equal to that Lender’s Revolving Commitment, after giving effect to the amendments set forth in Section 2 above. The Lenders shall accept the Replacement Notes in substitution for, but not in payment of, the corresponding Notes dated October 4, 2012 delivered in connection with the closing of the First Amendment to Credit Agreement dated October 4, 2012 among the Borrower, the Administrative Agent and the Lenders party thereto. Each reference in the Credit Agreement to the “Notes” shall hereafter be deemed to be a reference to the Replacement Notes.

5.Representations and Warranties. The Borrower hereby represents and warrants to the Administrative Agent and the Lenders as follows:

(a)The Borrower has all requisite power and authority, corporate or otherwise, to execute and deliver this Amendment, and to perform this Amendment and (except as noted in Schedule 4.2 to the Credit Agreement with respect to Borrowings made after September 12, 2015) the Credit Agreement as amended hereby. This Amendment has been duly and validly executed and delivered to the Administrative Agent and the Lenders by the Borrower, and this Amendment, and the Credit Agreement as amended hereby, constitute the Borrower’s legal, valid and binding obligations enforceable in accordance with their terms, except to the extent that such enforcement may be limited by bankruptcy, insolvency or similar laws affecting the enforcement of creditors’ rights generally or by general equitable principles.

(b)The execution, delivery and performance by the Borrower of this Amendment, and the performance of the Credit Agreement as amended hereby, have been duly authorized by all necessary corporate action and do not and will not (i) require any authorization, consent or approval by any governmental department, commission, board, bureau, agency or instrumentality, domestic or foreign, except as noted in Schedule 4.2 to the Credit Agreement with respect to Borrowings made after September 12, 2015, (ii) violate the Borrower’s articles of incorporation or bylaws or any provision of any law, rule, regulation or order presently in effect having applicability to the Borrower, or (iii) result in a breach of or constitute a default under any indenture or agreement to which the Borrower is a party or by which the Borrower is bound.

(c)Except as set forth in Schedules 4.2 and 4.4 attached hereto, all of the representations and warranties contained in Article IV of the Credit Agreement, as amended hereby, are correct on and as of the date hereof as though made on and as of such date.

6.Conditions. The amendments set forth in paragraph 2 shall be effective only if the Administrative Agent has received (or waived the receipt of) each of the following, in form and substance satisfactory to the Administrative Agent, on or before the date hereof (or such later date as the Administrative Agent may agree to in writing):

(a)This Amendment, duly executed by the Borrower and each of the Lenders below.

(b)The Replacement Notes, duly executed by the Borrower.

(c)A certificate of an officer of the Borrower (i) certifying that the execution, delivery and performance of this Amendment, and the performance of the Credit Agreement as amended hereby, have been duly approved by all necessary action of the board of directors of the Borrower, and attaching true and correct copies of the applicable resolutions granting such approval, (ii) certifying that there have been no amendments to or restatements of the articles of incorporation or bylaws of the Borrower as furnished to the Administrative Agent in connection with the execution and delivery of the Credit Agreement, other than those that may be attached to

- 5 -

US.53897791.05

the certificate, and (iii) certifying the names of the officers of the Borrower that are authorized to sign this Amendment, together with the true signatures of such officers.

(d)A signed copy of the opinion of Paul K. Sandness, general counsel for the Borrower, in substantially the form of Exhibit B-1 hereto, and a signed copy of the opinion of Cohen Tauber Spievack & Wagner P.C., special counsel to the Borrower, in substantially the form of Exhibit B-2.

(e)All fees required to be paid with respect to this Amendment as of the date hereof as specified in the Fee Letter.

7.Miscellaneous. The Borrower shall pay all costs and expenses of the Administrative Agent, including attorneys’ fees, incurred in connection with the drafting and preparation of this Amendment and any related documents. Except as amended by this Amendment, all of the terms and conditions of the Credit Agreement shall remain in full force and effect. This Amendment may be executed in any number of counterparts, each of which when so executed and delivered shall be deemed to be an original and all of which counterparts of this Amendment, taken together, shall constitute but one and the same instrument. Delivery of an executed counterpart of a signature page to this Amendment by facsimile or by e-mail transmission of a PDF or similar copy shall be equally as effective as delivery of an original executed counterpart of this Amendment. Any party delivering an executed counterpart signature page to this Amendment by facsimile or by e-mail transmission shall also deliver an original executed counterpart of this Amendment but the failure to deliver an original executed counterpart shall not affect the validity, enforceability or binding effect of this Amendment. This Amendment shall be governed by the substantive law of the State of New York.

[Signature pages follow]

- 6 -

US.53897791.05

IN WITNESS WHEREOF, the undersigned have executed this Amendment as of the day and year first above written.

MDU RESOURCES GROUP, INC.
	/s/ Doran N. Schwartz
By
Name:	Doran N. Schwartz
Title:	Vice President and
	Chief Financial Officer

Signature page to Second Amendment to MDU Resources Group, Inc. Credit Agreement

WELLS FARGO BANK, NATIONAL
ASSOCIATION, as Administrative Agent
and as a Lender
By	/s/ Nick Brokke
Name:	Nick Brokke
Title:	Vice President

Signature page to Second Amendment to MDU Resources Group, Inc. Credit Agreement

THE BANK OF TOKYO-MITSUBISHI UFJ,
LTD., NEW YORK BRANCH
By	/s/ Paul V. Farrell
Name:	Paul V. Farrell
Title:	Director

Signature page to Second Amendment to MDU Resources Group, Inc. Credit Agreement

PNC BANK, NATIONAL ASSOCIATION
By	/s/ Jon R Hinard
Name:	Jon R Hinard
Title:	Senior Vice President

Signature page to Second Amendment to MDU Resources Group, Inc. Credit Agreement

U.S. BANK NATIONAL ASSOCIATION
By	/s/ John Prigge
Name:	John Prigge
Title:	Vice President

Signature page to Second Amendment to MDU Resources Group, Inc. Credit Agreement

KEYBANK NATIONAL ASSOCIATION
By	/s/ Keven D. Smith
Name:	Keven D. Smith
Title:	Senior Vice President

Signature page to Second Amendment to MDU Resources Group, Inc. Credit Agreement

Exhibit A

REVOLVING COMMITMENTS AND ADDRESSES

Name	Revolving Commitment	Notice Address
MDU Resources Group, Inc.	N/A	1200 West Century Avenue Bismarck, ND 58503 Attention: Doug Mahowald, Treasurer Telecopier: 701-530-1734 E-Mail: Doug.Mahowald@MDUResources.com
Wells Fargo Bank, National        Association, as        Administrative Agent	N/A	1525 W WT Harris Boulevard Mail Code: D1109-019 Attention: Syndication Agency Services Charlotte, NC 28262 Telecopier: 704-590-2790 E-Mail:        agencyservices.requests@wellsfargo.com with a copy to: MAC N9305-070 90 South Seventh Street Minneapolis, MN 55402 Attention: Nick Brokke Telecopier: 612-667-4747 E-Mail: nick.brokke@wellsfargo.com
Wells Fargo Bank, National        Association, as a Lender	$42,500,000	MAC N9305-070 90 South Seventh Street Minneapolis, MN 55402 Attention: Nick Brokke Telecopier: 612-667-4747 E-Mail: nick.brokke@wellsfargo.com
The Bank of Tokyo-Mitsubishi       UFJ, Ltd.	$42,500,000	1251 Avenue of the Americas New York, NY 10020-1104 Attention: Paul Farrell Telecopier: 201-521-2304 Email: pfarrell@us.mufg.jp
PNC Bank, National Association	$30,000,000	One North Franklin, 28th Floor Chicago, IL 60606 Attention: Michael Cortese Telecopier: 312-338-8128 E-Mail: Michael.Cortese@pnc.com
U.S. Bank National Association	$30,000,000	800 Nicollet Mall Minneapolis, MN 55402 Attention: John Prigge Telecopier: 612-303-2205 E-Mail: John.prigge@usbank.com
KeyBank National Association	$30,000,000	127 Public Square Cleveland, OH 44114 Attention: Jacob Micsak Telecopier: N/A E-Mail: jacob.micsak@key.com

Exhibit B-1

Opinion of Paul K. Sandness

May 8, 2014

Wells Fargo Bank, National Association

as Administrative Agent and as a Lender,

and the Other Financial Institutions Listed on

Schedule A Hereto

Ladies and Gentlemen:

I am the General Counsel of MDU Resources Group, Inc., a Delaware corporation (the “Company”), and in such capacity, I am familiar with the negotiation, preparation, execution and delivery of (i) a Second Amendment to Credit Agreement (the “Amendment”) dated May 8, 2014 among the Company, Wells Fargo Bank, National Association, as Administrative Agent and as a Lender, and The Bank of Tokyo-Mitsubishi UFJ, Ltd., PNC Bank, National Association, U.S. Bank National Association and KeyBank National Association, as Lenders, (ii) a Fee Letter (the “Wells Fargo Fee Letter”) dated May 2, 2014 among Wells Fargo Securities, LLC, Wells Fargo Bank, National Association, as Administrative Agent, and the Company, setting forth certain fees to be paid in connection with the Amendment, and (iii) a Fee Letter (together with the Amendment and the Wells Fargo Fee Letter, the “Amendment Documents”) dated May 2, 2014 between The Bank of Tokyo-Mitsubishi UFJ, Ltd. and the Company, setting forth certain fees to be paid in connection with the Amendment. This opinion is furnished to you pursuant to Section 6(d) of the Amendment and at the instruction of the Company. All capitalized terms used but not otherwise defined herein have the meanings ascribed thereto in or pursuant to the Amendment.

For the purpose of rendering the opinions contained herein, I have examined and reviewed the Amendment Documents and the Loan Documents. I have also examined the originals, or copies certified to my satisfaction, of the Restated Certificate of Incorporation and By-Laws of the Company, resolutions adopted by the Board of Directors of the Company authorizing the execution, delivery and performance by the Company of the Amendment Documents and the Loan Documents, and such other corporate records of the Company and agreements, instruments and other documents as I have deemed necessary as a basis for the opinions expressed below. In my examination, I have assumed the genuineness of all signatures, other than the signatures of the Company on the Amendment Documents and the Loan Documents, the legal capacity of natural persons, the authenticity of all documents submitted to me as originals and the conformity with original documents of all documents submitted to me as certified or photostatic copies. I have also assumed, with your consent, the due execution and delivery, pursuant to due authorization, of the Amendment Documents and the Loan Documents by all parties thereto other than the Company and the validity and binding effect of the Amendment Documents and the Loan Documents upon such parties.

As to any facts that I did not independently establish or verify, I have relied without independent investigation upon statements, representations and certificates of officers of the Company and as to the matters addressed therein, upon certificates or communications from public officials. As used herein, the phrase “to my knowledge” with respect to the existence or absence of facts is intended to signify that, while I have made no specific inquiry or other independent examination to determine the existence or absence of such facts, no factual information has come to my attention which causes me to believe that such facts are not accurate.

Based on and subject to the foregoing and upon such investigation as I have deemed necessary, and subject to the qualifications set forth below, it is my opinion that:

1.The Company is a corporation duly incorporated, validly existing and in good standing under the laws of Delaware.

2.The Company is duly qualified as a foreign corporation to transact business and is in good standing in Minnesota, Montana, North Dakota and South Dakota, and is not required, whether by reason of ownership or leasing of property or the conduct of its business, to be qualified in any other jurisdiction, except where the failure so to qualify or to be in good standing would not result in a Material Adverse Effect.

3.The Company has the corporate power and authority to execute and deliver the Amendment Documents and to perform its obligations under the Amendment Documents and under the Loan Documents as amended thereby, and has all requisite corporate power and authority, licenses and permits to own its assets and to carry on its business as currently conducted and as contemplated to be conducted by the Amendment and by the Credit Agreement as amended thereby.

4.The execution and delivery of the Amendment Documents, and the performance by the Company of the Amendment Documents and the Loan Documents as amended thereby, have been duly authorized by all necessary corporate action and by all necessary public utility commissions and other regulatory bodies having jurisdiction over the Company (except as noted in Schedule 4.2 of the Credit Agreement with respect to Borrowings made after September 12, 2015), and each of the Amendment Documents has been duly executed and delivered by the Company.

5.The execution and delivery of the Amendment Documents, and the performance by the Company of the Amendment Documents and the Loan Documents as amended thereby, do not and will not (a) require any consent or approval of the stockholders of the Company or any authorization, consent or approval by any governmental department, commission, board, bureau, agency or instrumentality, other than Authorizing Orders set forth in Schedule 4.2 to the Credit Agreement that (except as noted therein with respect to Borrowings made after September 12, 2015) have been obtained and are in full force and effect, (b) violate any provision of any law, rule or regulation or any order, writ, injunction or decree presently in effect having applicability to the Company or the Restated Certificate of Incorporation or By-Laws of the Company, (c) result in a breach of or constitute a default under any indenture or loan or credit agreement or any other agreement, lease or instrument to which the Company is a party or by which its properties may be bound or affected, or (d) except as provided therein, result in, or require, the creation or imposition of any Lien or other charge or encumbrance of any nature upon or with respect to any of its properties.

6.Except as set forth in the Company’s Annual Report on Form 10-K for the year ended December 31, 2013, or in any document subsequently filed by the Company pursuant to Section 13, 14 or 15(d) of the Exchange Act, there are no actions, suits or proceedings pending or, to my knowledge, threatened against or affecting the Company or the properties of the Company before any court or governmental department, commission, board, bureau, agency or instrumentality, which, if determined adversely to the Company, would have a Material Adverse Effect.

The opinions expressed herein are limited to the laws of the State of North Dakota and the General Corporation Law of the State of Delaware. I am a member of the Minnesota and North Dakota Bars and do not hold myself out as an expert on the laws of the States of Delaware, Montana or South Dakota. Insofar as the opinions expressed herein relate to the General Corporation Law of the State of Delaware, or the federal laws of the United States of America, I have relied with your consent on the opinion, of even date herewith, of Cohen Tauber Spievack & Wagner P.C.

This opinion is intended solely for your use and is rendered solely in connection with the Amendment Documents and the Loan Documents, and without my written consent may not be (a) relied

upon by you for any other purpose, or (b) relied upon by any other person or entity for any purpose, except that Cohen Tauber Spievack & Wagner P.C., special counsel to the Company, may rely on the opinions expressed herein in rendering to you their opinion of even date herewith. The opinions expressed above are limited to the law and facts in effect on the date hereof. I disclaim any obligation to advise you of facts, circumstances, events or developments which hereafter may be brought to my attention and which might alter, affect or modify the opinions expressed herein.

I hereby consent to reliance by the Administrative Agent and the Lenders now or hereafter parties to the Credit Agreement on the opinions expressed herein.

Very truly yours,

Paul K. Sandness

General Counsel and Secretary

SCHEDULE A

Lenders

Wells Fargo Bank, National Association

The Bank of Tokyo-Mitsubishi UFJ, Ltd.

PNC Bank, National Association

U.S. Bank National Association

KeyBank National Association

Exhibit B-2

Opinion of Cohen Tauber Spievack & Wagner P.C.

May 8, 2014

Wells Fargo Bank, National Association, as

Administrative Agent and as a Lender,

and the Other Financial Institutions Listed on

Schedule A Hereto

Ladies and Gentlemen:

We have acted as special counsel for MDU Resources Group, Inc., a Delaware corporation (the “Company”), in connection with (i) a Second Amendment to Credit Agreement (the “Amendment”) dated May 8, 2014 among the Company, Wells Fargo Bank, National Association, as Administrative Agent and as a Lender, and The Bank of Tokyo-Mitsubishi UFJ, Ltd., PNC Bank, National Association, U.S. Bank National Association and KeyBank National Association, as Lenders, (ii) a Fee Letter (the “Wells Fargo Fee Letter”) dated May 2, 2014 among Wells Fargo Securities, LLC, Wells Fargo Bank, National Association, as Administrative Agent, and the Company, setting forth certain fees to be paid in connection with the Amendment, and (iii) a Fee Letter (together with the Amendment and the Wells Fargo Fee Letter, the “Amendment Documents”) dated May 2, 2014 between The Bank of Tokyo-Mitsubishi UFJ, Ltd. and the Company, setting forth certain fees to be paid in connection with the Amendment. This opinion is furnished to you pursuant to Section 6(d) of the Amendment and at the instruction of the Company. All capitalized terms used but not otherwise defined herein have the meanings ascribed thereto in or pursuant to the Amendment.

For the purpose of rendering the opinions contained herein, we have examined and reviewed the Amendment Documents and the Loan Documents. We have also examined the originals, or copies certified to our satisfaction, of the Restated Certificate of Incorporation and By-Laws of the Company, resolutions adopted by the Board of Directors of the Company authorizing the execution, delivery and performance by the Company of the Amendment Documents and the Loan Documents, and such other corporate records of the Company and agreements, instruments and other documents as we have deemed necessary as a basis for the opinions expressed below. In our examination, we have assumed the genuineness of all signatures, the legal capacity of natural persons, the authenticity of all documents submitted to us as originals and the conformity with original documents of all documents submitted to us as certified or photostatic copies. We have also assumed, with your consent, the due execution and delivery, pursuant to due authorization, of the Amendment Documents and the Loan Documents by all parties thereto other than the Company and the validity and binding effect of the Amendment Documents and the Loan Documents upon such parties. As to any facts that we did not independently establish or verify, we have relied without independent investigation upon statements, representations and certificates of officers of the Company and as to the matters addressed therein, upon certificates or communications from public officials.

Based on and subject to the foregoing and upon such investigation as we have deemed necessary, and subject to the qualifications set forth below, it is our opinion that:

1.The Company is a corporation duly incorporated, validly existing and in good standing under the laws of Delaware.

2.The Company has the corporate power and authority to execute and deliver the Amendment Documents and to perform its obligations under the Amendment Documents and under the Loan Documents as amended thereby.

3.The execution and delivery of the Amendment Documents, and the performance by the Company of the Amendment Documents and the Loan Documents as amended thereby, have been duly authorized by all necessary corporate action, and each of the Amendment Documents has been duly executed and delivered by the Company.

4.The execution and delivery of the Amendment Documents, and the performance by the Company of the Amendment Documents and the Loan Documents as amended thereby, do not and will not (a) require any consent or approval of the stockholders of the Company or any authorization, consent or approval by any governmental department, commission, board, bureau, agency or instrumentality, other than Authorizing Orders set forth in Schedule 4.2 to the Credit Agreement that (except as noted therein with respect to Borrowings made after September 12, 2015) have been obtained and are in full force and effect, or (b) violate any provision of any law, rule or regulation or any order, writ, injunction or decree presently in effect having applicability to the Company or the Restated Certificate of Incorporation or By-Laws of the Company.

5.Each of the Amendment Documents and each of the Loan Documents as amended thereby constitutes a legal, valid and binding obligation of the Company enforceable in accordance with its respective terms, subject to the effect of any applicable bankruptcy, insolvency, moratorium or other similar laws affecting creditors’ rights generally and of general principles of equity (regardless of whether applied in a proceeding in equity or at law), except that we express no opinion as to (a) Section 7.3 of the Credit Agreement, (b) the enforceability of rights to indemnify under federal or state securities laws, or (c) the enforceability of waivers of the parties of their respective rights and remedies under law.

This opinion is limited to the laws of the State of New York, the General Corporation Law of the State of Delaware, and the federal laws of the United States of America. We express no opinion as to the laws of any other jurisdiction.

In rendering this opinion, we have relied as to all matters of North Dakota law, as to matters addressed therein, with your consent, upon the opinion of Paul K. Sandness, Bismarck, North Dakota, the General Counsel of the Company.

This opinion is intended solely for your use and is rendered solely in connection with the Amendment Documents and the Loan Documents, and without our written consent may not be (a) relied upon by you for any other purpose, or (b) relied upon by any other person or entity for any purpose, except that Paul K. Sandness may rely on the opinions expressed herein in rendering to you his opinion of even date herewith.

The opinions expressed above are limited to the law and facts in effect on the date hereof. We disclaim any obligation to advise you of facts, circumstances, events or developments which hereafter may be brought to our attention and which might alter, affect or modify the opinions expressed herein.

We hereby consent to reliance by the Administrative Agent and the Lenders now or hereafter parties to the Agreement on the opinions expressed herein.

Very truly yours,

COHEN TAUBER SPIEVACK & WAGNER P.C.

SCHEDULE A

Lenders

Wells Fargo Bank, National Association

The Bank of Tokyo-Mitsubishi UFJ, Ltd.

PNC Bank, National Association

U.S. Bank National Association

KeyBank National Association

Schedule 4.2

Authorizing Orders

MDU Resources Group, Inc. MDU Resources Group, Inc. (“MDU”) received authorization to issue up to $250,000,000 of short-term promissory notes representing bank borrowings and/or in the form of commercial paper from the following regulatory commissions:

a.    By an order dated September 12, 2013 and an Errata Notice dated October 18, 2013, MDU received

authorization from the Federal Energy Regulatory Commission (FERC) in Docket No. ES13-38-000. This FERC authorization is effective from September 12, 2013 through September 12, 2015.

b.    By an order dated August 21, 2013, MDU received authorization from the Montana Public Service

Commission in Docket No. D2013.7.58, Order No. 7301. This Montana authorization is effective from August 21, 2013 to December 31, 2015.

No further consent, approval, waiver, order or authorization of, or registration, qualification, declaration, or filings with, or notice to, any governmental department, commission, board, bureau, agency or instrumentality is required.

Schedule 4.4

SUBSIDIARIES

1. Alaska Basic Industries, Inc., an Alaska corporation, 100%

2. Ames Sand & Gravel, Inc., a North Dakota corporation, 100%

3. Anchorage Sand and Gravel Company, Inc., an Alaska corporation , 100%

4. Baldwin Contracting Company, Inc., a California corporation, 100%

5. BEH Electric Holdings, LLC, a Nevada limited liability company, 100%

6. Bell Electrical Contractors, Inc., a Missouri corporation, 100%

7. BMH Mechanical Holdings, LLC, a Nevada limited liability company, 100%

8. Bombard Electric, LLC, a Nevada limited liability company, 100%

9. Bombard Mechanical, LLC, a Nevada limited liability company, 100%

10. Capital Electric Construction Company, Inc., a Kansas corporation, 100%

11. Capital Electric Line Builders, Inc., a Kansas corporation, 100%

12. Cascade Natural Gas Corporation, a Washington corporation, 100%

13. Centennial Energy Holdings, Inc., a Delaware corporation, 100%

14. Centennial Energy Resources International, Inc., a Delaware corporation, 100%

15. Centennial Energy Resources LLC, a Delaware limited liability company, 100%

16. Centennial Holdings Capital LLC, a Delaware limited liability company, 100%

17. Central Oregon Redi-Mix, L.L.C., an Oregon limited liability company, 78%

18. CGC Resources, Inc., a Washington corporation, 100%

19. Concrete, Inc., a California corporation, 100%

20. Connolly-Pacific Co., a California corporation, 100%

21. Continental Line Builders, Inc., a Delaware corporation, 100%

22. Coordinating and Planning Services, Inc., a Delaware corporation, 100%

23. Desert Fire Holdings, Inc., a Nevada corporation, 100%

24. Desert Fire Protection, a Nevada Limited Partnership, 100%

25. Desert Fire Protection, Inc., a Nevada corporation, 100%

26. Desert Fire Protection, LLC, a Nevada limited liability company, 100%

27. D S S Company, a California corporation, 100%

28. E.S.I., Inc., an Ohio corporation, 100%

29. Fairbanks Materials, Inc., an Alaska corporation, 100%

30. Fidelity Exploration & Production Company, a Delaware corporation, 100%

31. Fidelity Oil Co., a Delaware corporation, 100%

32. Frebco, Inc., an Ohio corporation, 100%

33. FutureSource Capital Corp., a Delaware corporation, 100%

34. Granite City Ready Mix, Inc., a Minnesota corporation, 100%

35. Hamlin Electric Company, a Colorado corporation, 100%

36. Harp Engineering, Inc., a Montana corporation, 100%

37. Hawaiian Cement, a Hawaii partnership, 100%

38. ILB Hawaii, Inc., a Hawaii corporation, 100%

39. Independent Fire Fabricators, LLC, a Nevada limited liability company, 100%

40. Intermountain Gas Company, an Idaho corporation, 100%

41. International Line Builders, Inc., a Delaware corporation, 100%

42. InterSource Insurance Company, a Vermont corporation, 100%

43. Jebro Incorporated, an Iowa corporation, 100%

44. JTL Group, Inc., a Montana corporation, 100%

45. JTL Group, Inc., a Wyoming corporation, 100%

46. Kent’s Oil Service, a California corporation, 100%

47. Knife River Corporation, a Delaware corporation, 100%

48. Knife River Corporation - North Central, a Minnesota corporation, 100%

49. Knife River Corporation - Northwest, an Oregon corporation, 100%

50. Knife River Corporation - South, a Texas corporation, 100%

51. Knife River Dakota, Inc., a Delaware corporation, 100%

52. Knife River Hawaii, Inc., a Delaware corporation, 100%

53. Knife River Marine, Inc., a Delaware corporation, 100%

54. Knife River Midwest, LLC, a Delaware limited liability company, 100%

55. KRC Holdings, Inc., a Delaware corporation, 100%

56. LME&U Holdings, LLC, a Nevada limited liability company, 100%

57. Lone Mountain Excavation & Utilities, LLC, a Nevada limited liability company, 100%

58. Loy Clark Pipeline Co., an Oregon corporation, 100%

59. LTM, Incorporated, an Oregon corporation, 100%

60. MDU Brasil Ltda., a Brazil limited liability company, 100%

61. MDU Construction Services Group, Inc., a Delaware corporation, 100%

62. MDU Energy Capital, LLC, a Delaware limited liability company, 100%

63. MDU Industrial Services, Inc., a Delaware corporation, 100%

64. MDU Resources International LLC, a Delaware limited liability company, 100%

65. MDU Resources Luxembourg I LLC S.a.r.l., a Luxembourg limited liability company, 100%

66. MDU Resources Luxembourg II LLC S.a.r.l., a Luxembourg limited liability company, 100%

67. MDU United Construction Solutions, Inc., a Delaware corporation, 100%

68. Midland Technical Crafts, Inc., a Delaware corporation, 100%

69. Nevada Solar Solutions, LLC, a Delaware limited liability company, 100%

70. Northstar Materials, Inc., a Minnesota corporation, 100%

71. Oregon Electric Construction, Inc., an Oregon corporation, 100%

72. Pouk & Steinle, Inc., a California corporation, 100%

73. Prairie Cascade Energy Holdings, LLC, a Delaware limited liability company, 100%

74. Prairie Intermountain Energy Holdings, LLC, a Delaware limited liability company, 100%

75. Prairielands Energy Marketing, Inc., a Delaware corporation, 100%

76. Rocky Mountain Contractors, Inc., a Montana corporation, 100%

77. USI Industrial Services, Inc., a Delaware corporation, 100%

78. The Wagner Group, Inc., a Delaware corporation, 100%

79. Wagner Industrial Electric, Inc., a Delaware corporation, 100%

80. The Wagner-Smith Company, an Ohio corporation, 100%

81. Wagner-Smith Equipment Co., a Delaware corporation, 100%

82. Wagner-Smith Pumps & Systems, Inc., an Ohio corporation, 100%

83. Warner Enterprises, Inc., a Nevada corporation, 100%

84. WBI Canadian Pipeline, Ltd., a Canadian corporation, 100%

85. WBI Energy, Inc., a Delaware corporation, 100%

86. WBI Energy Midstream, LLC, a Colorado limited liability company, 100%

87. WBI Energy Services, Inc., a Delaware corporation, 100%

88. WBI Energy Transmission, Inc., a Delaware corporation, 100%

89. WBI Holdings, Inc., a Delaware corporation, 100%

90. WHC, Ltd., a Hawaii corporation, 100%

EX-4.(B)

THIRD AMENDED AND RESTATED CREDIT AGREEMENT

Dated as of May 8, 2014

among

CENTENNIAL ENERGY HOLDINGS, INC.,

THE SEVERAL FINANCIAL INSTITUTIONS

FROM TIME TO TIME PARTY TO THIS AGREEMENT,

U.S. BANK NATIONAL ASSOCIATION,

as Administrative Agent,

THE BANK OF TOKYO-MITSUBISHI UFJ, LTD.,

as Syndication Agent,

and

JPMORGAN CHASE BANK, N.A.,

WELLS FARGO BANK, NATIONAL ASSOCIATION

and

ROYAL BANK OF CANADA,

as Co-Documentation Agents

Arranged By

U.S. BANK NATIONAL ASSOCIATION,

THE BANK OF TOKYO-MITSUBISHI UFJ, LTD.,

J.P. MORGAN SECURITIES LLC,

WELLS FARGO SECURITIES, LLC

and

ROYAL BANK OF CANADA

709152408 03173762

CONTENTS
Clause		Page
ARTICLE I	DEFINITIONS	1
1.01	Certain Defined Terms	1
1.02	Other Interpretive Provisions	19
1.03	Accounting Principles	19
1.04	Amendment and Restatement	20
ARTICLE II	THE FACILITY	20
2.01	The Facility	20
2.02	Advances	20
2.03	Method of Borrowing	22
2.04	Fees; Changes in Aggregate Commitment	22
2.05	Minimum Amount of Each Advance	23
2.06	Optional Principal Payments	23
2.07	Changes in Interest Rate, etc	23
2.08	Rates Applicable After Default	23
2.09	Method of Payment	24
2.10	Evidence of Debt; Telephonic Notices	24
2.11	Interest Payment Dates; Interest and Fee Basis	24
2.12	Notification of Advances, Interest Rates, Prepayments and Commitment Changes	25
2.13	Lending Installations	25
2.14	Non-Receipt of Funds by the Administrative Agent	25
2.15	Replacement of Bank	25
2.16	Letters of Credit	26
2.17	Additional Cash Collateral	30
2.18	Defaulting Banks	31
ARTICLE III	YIELD PROTECTION; TAXES	34
3.01	Increased Costs Generally	34
3.02	Changes in Capital Adequacy Regulations	35
3.03	Certificates for Reimbursement; Delay in Requests	35
3.04	Availability of Types of Advances	35
3.05	Funding Indemnification	35
3.06	Taxes	36
3.07	Mitigation Obligations; Replacement of Banks	39
ARTICLE IV	CONDITIONS PRECEDENT	41
4.01	Initial Credit Extension	41
4.02	Each Credit Extension	42

709152408 03173762

CONTENTS
Clause		Page
ARTICLE V	REPRESENTATIONS AND WARRANTIES	43
5.01	Existence and Power; Standing; Compliance With Laws	43
5.02	Corporate Authorization; No Contravention or Conflict	43
5.03	Governmental Authorization	43
5.04	Validity and Binding Effect	43
5.05	Litigation; Environmental Claims	44
5.06	No Default	44
5.07	ERISA Compliance	44
5.08	Use of Proceeds; Margin Regulations	44
5.09	Title to Properties	44
5.10	Taxes	44
5.11	Financial Condition	45
5.12	Environmental Matters	45
5.13	Regulated Entities	45
5.14	Copyrights, Patents, Trademarks and Licenses, etc	45
5.15	Subsidiaries	46
5.16	Insurance	46
5.17	Solvency	46
5.18	Full Disclosure	46
5.19	Senior Debt	46
5.20	OFAC; Anti-Terrorism Laws	46
ARTICLE VI	AFFIRMATIVE COVENANTS	46
6.01	Financial Statements	47
6.02	Certificates; Other Information	47
6.03	Notices	48
6.04	Preservation of Existence	48
6.05	Maintenance of Property	48
6.06	Insurance	49
6.07	Payment of Obligations	49
6.08	Compliance with Laws	49
6.09	Inspection of Property and Books and Records	49
6.10	Environmental Laws	50
6.11	Use of Proceeds	50
6.12	OFAC, PATRIOT Act Compliance	50
ARTICLE VII	NEGATIVE COVENANTS	50
7.01	Limitation on Liens	50

709152408 03173762

CONTENTS
Clause		Page
7.02	Disposition of Assets	52
7.03	Consolidations and Mergers	53
7.04	Loans and Investments	54
7.05	Transactions with Affiliates	55
7.06	Use of Proceeds	55
7.07	Joint Ventures	56
7.08	Restricted Payments	56
7.09	Change in Business	56
7.10	Accounting Changes	56
7.11	Maximum Company Capitalization Ratio	56
7.12	Limitation on Subsidiary Indebtedness	56
7.13	Agreements Restricting Subsidiary Dividends	57
7.14	Activities of International Subsidiaries	58
ARTICLE VIII	EVENTS OF DEFAULT	58
8.01	Event of Default	58
8.02	Remedies	60
ARTICLE IX	THE ADMINISTRATIVE AGENT	61
9.01	Appointment; Nature of Relationship	61
9.02	Powers	61
9.03	General Immunity	61
9.04	No Responsibility for Loans, Recitals, etc	62
9.05	Action on Instructions of Banks	62
9.06	Employment of Agents and Counsel	62
9.07	Reliance on Documents; Counsel	62
9.08	Administrative Agent’s Reimbursement and Indemnification	63
9.09	Notice of Default	63
9.10	Rights as a Bank	63
9.11	Bank Credit Decision	63
9.12	Successor Administrative Agent	64
9.13	Administrative Agent’s and Co-Lead Arrangers’ Fees	64
9.14	Delegation to Affiliates	65
9.15	Other Agents	65
ARTICLE X	MISCELLANEOUS	65
10.01	Amendments and Waivers	65
10.02	Notices	66
10.03	No Waiver; Cumulative Remedies	67

709152408 03173762

CONTENTS
Clause		Page
10.04	Several Obligations; Benefits of this Agreement	67
10.05	Expenses; Indemnification	67
10.06	Marshalling; Payments Set Aside	68
10.07	Successors and Assigns	68
10.08	Participations; Assignments, etc	68
10.09	Confidentiality	70
10.10	Set-off; Ratable Payments	71
10.11	Automatic Debits of Fees	71
10.12	Notification of Addresses, Lending Installations, Etc	72
10.13	Counterparts	72
10.14	Severability	72
10.15	GOVERNING LAW AND JURISDICTION	72
10.16	WAIVER OF JURY TRIAL	73
10.17	Entire Agreement	73
10.18	Survival of Representations	73
10.19	Governmental Regulation	73
10.20	Numbers of Documents	73
10.21	Nonliability of Banks	74
10.22	No Advisory or Fiduciary Responsibility	74
10.23	USA Patriot Act Notice	74

709152408 03173762

CONTENTS
Clause			Page
EXHIBITS
A		Form of Compliance Certificate
B-1		Form of Opinion of Paul K. Sandness
B-2		Form of Opinion of Cohen Tauber Spievack & Wagner P.C.
C		Form of Note
D		Form of Money Transfer Instructions
E-1 TO E-4		Forms of Tax Compliance Certificates
F		Form of Assignment Agreement
G		Form of Increase Request
H		Form of Borrowing Notice
SCHEDULES
2.01	-	Commitments and Pro Rata Shares
2.16	-	Existing Letters of Credit
5.15	-	Subsidiaries and Minority Interests
7.01	-	Certain Permitted Liens
7.12	-	Certain Permitted Indebtedness
7.13	-	Agreements Restricting Subsidiary Dividends
10.02	-	Lending Installations; Addresses for Notices

709152408 03173762

THIRD AMENDED AND RESTATED CREDIT AGREEMENT

This THIRD AMENDED AND RESTATED CREDIT AGREEMENT (this “Agreement”) is entered into as of May 8, 2014 among CENTENNIAL ENERGY HOLDINGS, INC., a Delaware corporation (the “Company”), the several financial institutions from time to time party to this Agreement, JPMORGAN CHASE BANK, N.A., WELLS FARGO BANK, NATIONAL ASSOCIATION and ROYAL BANK OF CANADA, as Co-Documentation Agents, THE BANK OF TOKYO-MITSUBISHI UFJ, LTD.,as Syndication Agent, and U.S. BANK NATIONAL ASSOCIATION, as administrative agent for the Banks.

WHEREAS, the Company, various financial institutions and U.S. Bank National Association, as administrative agent, have entered into a second amended and restated credit agreement dated as of June 8, 2012, as amended (the “Existing Credit Agreement”);

WHEREAS, the parties hereto have agreed to amend and restate the Existing Credit Agreement pursuant to this Agreement; and

WHEREAS, the parties hereto intend that this Agreement and the documents executed in connection herewith not effect a novation of the obligations of the Company under the Existing Credit Agreement, but merely a restatement of and, where applicable, an amendment to the terms governing such obligations;

NOW, THEREFORE, for good and valuable consideration, the receipt and sufficiency of which are acknowledged hereby, the parties hereto agree as follows:

ARTICLE I

DEFINITIONS

1.01    Certain Defined Terms. The following terms have the following meanings:

“Acquisition” means any transaction or series of related transactions for the purpose of or resulting, directly or indirectly, in (a) the acquisition of all or substantially all of the assets of a Person, or of any business or division of a Person, (b) the acquisition of more than 50% of the capital stock, partnership interests, membership interests or equity of any Person, or otherwise causing any Person to become a Subsidiary, or (c) a merger or consolidation or any other combination with another Person (other than a Person that is a Subsidiary) provided that the Company or the Subsidiary is the surviving entity.

“Administrative Agent” means U.S. Bank in its capacity as administrative agent for the Banks pursuant to Article IX, and not in its individual capacity as a Bank, and any successor administrative agent appointed pursuant to Article IX.

“Advance” means a borrowing hereunder (or conversion or continuation thereof) consisting of the aggregate amount of the several Loans made on the same Borrowing Date (or date of conversion or continuation) by the Banks to the Company at the same Rate Option and, in the case of Eurodollar Advances, for the same Interest Period.

“Affected Bank” has the meaning specified in Section 2.15.

1

709152408 03173762

“Affiliate” of any Person means any other Person directly or indirectly controlling, controlled by or under common control with such Person. A Person shall be deemed to control another Person if the controlling Person owns 10% or more of any class of voting securities (or other ownership interests) of the controlled Person or possesses, directly or indirectly, the power to direct or cause the direction of the management or policies of the controlled Person, whether through ownership of stock or other equity interests, by contract or otherwise.

“Agent-Related Persons” means U.S. Bank and any successor Administrative Agent arising under Section 9.12, together with their respective Affiliates and the officers, directors, employees, agents and attorneys-in-fact of such Persons and Affiliates.

“Aggregate Commitment” means the aggregate of the Commitments of all the Banks, as modified from time to time pursuant to the terms hereof.

“Aggregate Outstanding Credit Exposure” means, at any time, the aggregate of the Outstanding Credit Exposures of all Banks.

“Agreement” - see the preamble.

“Alternate Base Rate” means, for any day, a rate of interest per annum equal to the highest of (i) the Prime Rate for such day, (ii) the sum of the Federal Funds Effective Rate for such day plus 1/2% per annum and (iii) the Eurodollar Rate (without giving effect to the Applicable Amount) for a one month Interest Period on such day (or if such day is not a Business Day, the immediately preceding Business Day) plus 1.0%, provided that the Eurodollar Rate for any day shall be based on the rate reported by the applicable financial information service at approximately 11:00 a.m. (London time) on such day.

“Applicable Amount” means, for any Pricing Period, with respect to the fees referred to below and outstanding Advances of the Types referred to below, the per annum amount set forth below in the corresponding column under Applicable Amount opposite the applicable Pricing Level:

Pricing Level	Applicable Amount (in basis points per annum)
	Facility Fee	Eurodollar Advances/ Letter of Credit Fee	Base Rate Advances
1	10.0	77.5	0.0
2	12.5	87.5	0.0
3	15.0	97.5	0.0
4	20.0	105.0	5.0
5	25.0	125.0	25.0
6	30.0	145.0	45.0

2

709152408 03173762

“Approved Fund” means any Fund that is administered or managed by (a) a Bank, (b) an Affiliate of a Bank or (c) an entity or an Affiliate of an entity that administers or manages a Bank.

“Assignment Agreement” means an assignment agreement, in substantially the form of Exhibit F hereto.

“Attorney Costs” means and includes all fees and disbursements of any law firm or other external counsel, the allocated cost of internal legal services and all disbursements of internal counsel.

“Bankruptcy Code” means the United States Bankruptcy Code (11 U.S.C. §101, et seq.).

“Banks” means the lending institutions listed on the signature pages of this Agreement and their respective successors and assigns.

“Base Rate” means, for any day, a rate per annum equal to (i) the Alternate Base Rate for such day plus (ii) the Applicable Amount.

“Base Rate Advance” means an Advance which bears interest at the Base Rate.

“Borrowing Date” means a date on which an Advance is made hereunder.

“Borrowing Notice” has the meaning specified in Section 2.02(c).

“Business Day” means a day (other than a Saturday or Sunday) on which banks generally are open in Minneapolis and New York for the conduct of substantially all of their commercial lending activities, interbank wire transfers can be made on the Fedwire system and, with respect to any borrowing, payment or rate selection of Eurodollar Advances or Eurodollar Loans, a day on which dealings in United States dollars are carried on in the London interbank market.

“Capital Adequacy Regulation” means any guideline, request or directive of any central bank or other Governmental Authority, or any other law, rule or regulation, whether or not having the force of law, in each case, regarding capital adequacy of any bank or of any corporation controlling a bank.

“Capitalization Ratio” means, with respect to any Person, the ratio of such Person’s Total Debt to such Person’s Total Capitalization.

“Cash Collateralize” means to pledge and deposit with or deliver to the Administrative Agent, for the benefit of one or more of the Issuers or the Banks, as collateral for Letter of Credit Obligations or obligations of the Banks to fund participations in respect of Letter of Credit Obligations, cash or deposit account balances or, if the Administrative Agent and each applicable Issuer shall agree in their sole discretion, other credit support, in each case pursuant to documentation in form and substance satisfactory to the Administrative Agent and each applicable Issuer. “Cash Collateral” shall have a meaning correlative to the foregoing and shall include the proceeds of such cash collateral and other credit support.

“Centennial International” means Centennial Energy Resources International Inc., a Delaware corporation.

3

709152408 03173762

“Change in Law” has the meaning specified in Section 3.01.

“Change of Control” means the occurrence of any event whereby MDU Resources Group, Inc. ceases to own direct or indirect sole beneficial ownership (as defined under Rule 13d-3 under the Exchange Act as in effect on the date of this Agreement) of at least 66-2/3% of the combined voting power of the Company’s securities which are entitled to vote generally in the election of directors of the Company.

“Code” means the Internal Revenue Code of 1986, and regulations promulgated thereunder.

“Co-Lead Arrangers” means U.S. Bank, The Bank of Tokyo-Mitsubishi UFJ, Ltd., J.P. Morgan Securities LLC, Wells Fargo Securities, LLC and Royal Bank of Canada in their capacity as co-lead arrangers for the credit facilities evidenced hereby.

“Commitment” means, for each Bank, the obligation of such Bank to make Loans and to participate in Letters of Credit in an aggregate amount not exceeding the amount set forth in Schedule 2.01, as it may be modified as a result of any assignment that has become effective pursuant to Section 10.08, or as otherwise modified from time to time pursuant to the terms hereof.

“Commodity Contract” means any agreement, device or arrangement providing for payments which are related to fluctuations in commodity prices, including commodity swap or forward sale or purchase agreements.

“Company” - see the preamble.

“Compliance Certificate” means a certificate substantially in the form of Exhibit A properly completed and signed by a Responsible Officer.

“Connection Income Taxes” means Other Connection Taxes that are imposed on or measured by net income (however denominated) or that are franchise Taxes or branch profits Taxes.

“Consolidated Net Worth” means, at any time, the excess of total assets of the Company and its Subsidiaries over total liabilities of the Company and its Subsidiaries as of the last day of the fiscal quarter most recently then ended, determined on a consolidated basis in accordance with GAAP.

“Contingent Obligation” means, as to any Person, any direct or indirect liability of that Person, whether or not contingent, with or without recourse, (a) with respect to any Indebtedness, lease, dividend, letter of credit or other obligation (the “primary obligations”) of another Person (the “primary obligor”), including any obligation of that Person (i) to purchase, repurchase or otherwise acquire such primary obligations or any security therefor, (ii) to advance or provide funds for the payment or discharge of any such primary obligation, or to maintain working capital or equity capital of the primary obligor or otherwise to maintain the net worth or solvency or any balance sheet item, level of income or financial condition of the primary obligor, (iii) to purchase property, securities or services primarily for the purpose of assuring the owner of any such primary obligation of the ability of the primary obligor to make payment of such primary obligation, or (iv) otherwise to assure or hold harmless the holder of any such primary obligation

4

709152408 03173762

against loss in respect thereof (each, a “Guaranty Obligation”); (b) to purchase any materials, supplies or other property from, or to obtain the services of, another Person if the relevant contract or other related document or obligation requires that payment for such materials, supplies or other property, or for such services, shall be made regardless of whether delivery of such materials, supplies or other property is ever made or tendered, or such services are ever performed or tendered, or (c) in respect of any Swap Contract. The amount of any Contingent Obligation shall, in the case of Guaranty Obligations, be deemed equal to the stated or determinable amount of the primary obligation in respect of which such Guaranty Obligation is made or, if not stated or if indeterminable, the maximum reasonably anticipated liability in respect thereof, and in the case of other Contingent Obligations other than in respect of Swap Contracts, shall be equal to the maximum reasonably anticipated liability in respect thereof and, in the case of Contingent Obligations in respect of Swap Contracts, shall be equal to the Swap Termination Value thereof.

“Contractual Obligation” means, as to any Person, any provision of any security issued by such Person or of any agreement, undertaking, contract, indenture, mortgage, deed of trust or other instrument, document or agreement to which such Person is a party or by which it or any of its property is bound.

“Covered Contracts” means all obligations (contingent or otherwise) of the Company or any Subsidiary existing or arising under Swap Contracts, provided that such obligations are (or were) entered into by such Person in the ordinary course of business for the purpose of directly mitigating interest rate, exchange rate or price risks associated with liabilities, commitments or assets held or reasonably anticipated by such Person and not for the purposes of financing, speculation or taking a “market view”.

“Credit Extension” means the making of an Advance or the issuance or increase in the stated amount of a Letter of Credit.

“Default” means any event or circumstance which, with the giving of notice, the lapse of time, or both, would (if not cured or otherwise remedied during such time) constitute an Event of Default.

“Defaulting Bank” means, subject to Section 2.18(b), any Bank that (a) has failed to (i) fund all or any portion of its Loans within two Business Days of the date such Loans were required to be funded hereunder unless such Bank notifies the Administrative Agent and the Company in writing that such failure is the result of such Bank’s determination that one or more conditions precedent to funding (each of which conditions precedent, together with any applicable default, shall be specifically identified in such writing) has not been satisfied, or (ii) pay to the Administrative Agent, any Issuer or any other Bank any other amount required to be paid by it hereunder (including in respect of its participation in Letters of Credit) within two Business Days of the date when due, (b) has notified the Company, the Administrative Agent or any Issuer in writing that it does not intend to comply with its funding obligations hereunder, or has made a public statement to that effect (unless such writing or public statement relates to such Bank’s obligation to fund a Loan hereunder and states that such position is based on such Bank’s determination that a condition precedent to funding (which condition precedent, together with any applicable default, shall be specifically identified in such writing or public statement) cannot be satisfied), (c) has failed, within three Business Days after written request by the Administrative Agent or the Company, to confirm in writing to the Administrative Agent and the

5

709152408 03173762

Company that it will comply with its prospective funding obligations hereunder (provided that such Bank shall cease to be a Defaulting Bank pursuant to this clause (c) upon receipt of such written confirmation by the Administrative Agent and the Company), or (d) has, or has a direct or indirect parent company that has, (i) become the subject of an Insolvency Proceeding, or (ii) had appointed for it a receiver, custodian, conservator, trustee, administrator, assignee for the benefit of creditors or similar Person charged with reorganization or liquidation of its business or assets, including the Federal Deposit Insurance Corporation or any other state or federal regulatory authority acting in such a capacity; provided that a Bank shall not be a Defaulting Bank solely by virtue of the ownership or acquisition of any equity interest in that Bank or any direct or indirect parent company thereof by a Governmental Authority so long as such ownership interest does not result in or provide such Bank with immunity from the jurisdiction of courts within the United States or from the enforcement of judgments or writs of attachment on its assets or permit such Bank (or such Governmental Authority) to reject, repudiate, disavow or disaffirm any contracts or agreements made with such Bank. Any determination by the Administrative Agent that a Bank is a Defaulting Bank under any one or more of clauses (a) through (d) above shall be conclusive and binding absent manifest error, and such Bank shall be deemed to be a Defaulting Bank (subject to Section 2.18(b)) upon delivery of written notice of such determination to the Company, each Issuer and each Bank.

“Dollars”, “dollars” and “$” each mean lawful money of the United States.

“DPR” means Dakota Prairie Refining, LLC, a Delaware limited liability company.

“Eligible Assignee” means (a) a Bank, (b) an Affiliate of a Bank, (c) an Approved Fund and (d) any other Person (other than a natural person) approved by (i) the Administrative Agent, (ii) each Issuer and (iii) unless an Event of Default has occurred and is continuing, the Company (each such approval not to be unreasonably withheld or delayed); provided that, notwithstanding the foregoing, “Eligible Assignee” shall not include (x) the Company or any of the Company’s Affiliates or Subsidiaries or (y) any Defaulting Bank or any of its Subsidiaries, or any Person that, upon becoming a Bank hereunder, would constitute any of the foregoing Persons described in this clause (y).

“Environmental Claims” means all material claims, however asserted, by any Governmental Authority or other Person alleging potential liability or responsibility for violation of any Environmental Law, or for release or injury to the environment.

“Environmental Laws” means all federal, state or local laws, statutes, rules, regulations, ordinances and codes, together with all administrative orders, requests, licenses, authorizations and permits of, and agreements with, any Governmental Authorities, in each case relating to environmental, health, safety and land use matters, including the Comprehensive Environmental Response, Compensation and Liability Act of 1980, the Clean Air Act, the Federal Water Pollution Control Act of 1972, the Solid Waste Disposal Act, the Federal Resource Conservation and Recovery Act, the Toxic Substances Control Act, and the Emergency Planning and Community Right-to-Know Act.

“ERISA” means the Employee Retirement Income Security Act of 1974.

“ERISA Affiliate” means any trade or business (whether or not incorporated) under common control with the Company within the meaning of Section 414(b) or (c) of the Code (and

6

709152408 03173762

Sections 414(m) and (o) of the Code for purposes of provisions relating to Section 412 of the Code).

“ERISA Event” means (a) a Reportable Event with respect to a Pension Plan; (b) a withdrawal by the Company or any ERISA Affiliate from a Pension Plan subject to Section 4063 of ERISA during a plan year in which it was a substantial employer (as defined in Section 4001(a)(2) of ERISA) or a cessation of operations which is treated as such a withdrawal under Section 4062(e) of ERISA; (c) a complete or partial withdrawal by the Company or any ERISA Affiliate from a Multiemployer Plan or notification that a Multiemployer Plan is in reorganization (within the meaning of Section 4241 of ERISA), insolvent (within the meaning of Section 4245 of ERISA) or in “critical” status (within the meaning of Section 432 of the Code or Section 305 of ERISA); (d) the commencement of proceedings by the PBGC to terminate a Pension Plan; (e) a failure by the Company or any ERISA Affiliate to make required contributions to a Pension Plan or Multiemployer Plan, or the imposition of a lien in favor of a Pension Plan under Section 430(k) of the Code or Section 303(k) of ERISA; (f) an event or condition which might reasonably be expected to constitute grounds under Section 4042 of ERISA for the termination of, or the appointment of a trustee to administer, any Pension Plan or for the imposition of any liability under Section 4069 or 4212(c) of ERISA; (g) the imposition of any liability under Title IV of ERISA, other than PBGC premiums due but not delinquent under Section 4007 of ERISA, upon the Company or any ERISA Affiliate; (h) an application for a funding waiver pursuant to Section 412 of the Code or Section 302(c) of ERISA with respect to any Plan; or (i) a determination that a Plan is, or is reasonably expected to be, in “at risk” status (within the meaning of Section 430 of the Code or Section 303 of ERISA).

“ERISA Termination Event” means the filing of a notice of intent to terminate a Pension Plan, or the treatment of a plan amendment as the termination of a Pension Plan, under Section 4041 or 4042 of ERISA.

“Eurodollar Advance” means an Advance which bears interest based upon the Eurodollar Rate as requested by the Company pursuant to Section 2.02.

“Eurodollar Base Rate” means, with respect to any applicable Advance for the relevant Interest Period, the rate per annum equal to the rate determined by the Administrative Agent to be the offered rate that appears on the Reuters Screen LIBOR01 page (or any successor thereto) that displays the London interbank offered rate administered by ICE Benchmark Administration Limited (or any other Person that takes over the administration of such rate and designated by the Administrative Agent (the “IBA Rate”) for deposits in U.S. dollars (for delivery on the first day of such Interest Period) with a term equivalent to such Interest Period, determined as of approximately 11:00 a.m. (London time) two Business Days prior to the first day of such Interest Period, provided that (i) if such Reuters Screen LIBOR01 page is not available to the Administrative Agent for any reason, the applicable Eurodollar Base Rate for the relevant Interest Period shall instead be the applicable IBA Rate for deposits in U.S. dollars as reported by any other generally recognized financial information service as of 11:00 a.m. (London time) two Business Days prior to the first day of such Interest Period, and having a maturity equal to such Interest Period, and (ii) if no such IBA Rate is available to the Administrative Agent, the applicable Eurodollar Base Rate for the relevant Interest Period shall instead be the rate determined by the Administrative Agent to be the rate at which U.S. Bank or one of its Affiliate banks offers to place deposits in U.S. dollars with first-class banks in the London interbank market at approximately 11:00 a.m. (London time) two Business Days prior to the first day of

7

709152408 03173762

such Interest Period, in the approximate amount of U.S. Bank’s relevant Eurodollar Loan and having a maturity equal to such Interest Period.

“Eurodollar Loan” means a Loan comprising a Eurodollar Advance.

“Eurodollar Rate” means, with respect to a Eurodollar Advance for the relevant Interest Period, the sum of (i) the quotient of (a) the Eurodollar Base Rate applicable to such Interest Period, divided by (b) one minus the Reserve Requirement (expressed as a decimal) applicable to such Interest Period, plus (ii) the Applicable Amount.

“Event of Default” means any of the events or circumstances specified in Section 8.01.

“Exchange Act” means the Securities Exchange Act of 1934.

“Excluded Taxes” means any of the following Taxes imposed on or with respect to a Recipient or required to be withheld or deducted from a payment to a Recipient, (a) Taxes imposed on or measured by net income (however denominated), franchise Taxes, and branch profits Taxes, in each case, (i) imposed as a result of such Recipient being organized under the laws of, or having its principal office or, in the case of any Bank, its applicable lending office located in, the jurisdiction imposing such Tax (or any political subdivision thereof) or (ii) that are Other Connection Taxes, (b) in the case of a Bank, U.S. federal withholding Taxes imposed on amounts payable to or for the account of such Bank with respect to an applicable interest in a Loan or Commitment pursuant to a law in effect on the date on which (i) such Bank acquires such interest in such Loan or Commitment (other than pursuant to an assignment request by the Company under Section 3.07) or (ii) such Bank changes its lending office, except in each case to the extent that, pursuant to Section 3.06, amounts with respect to such Taxes were payable either to such Bank's assignor immediately before such Bank became a party hereto or to such Bank immediately before it changed its lending office, (c) Taxes attributable to such Recipient’s failure to comply with Section 3.06(g) and (d) any U.S. federal withholding Taxes imposed under FATCA.

“Execution Date” means the date set forth on the cover page of this Agreement.

“Existing Credit Agreement” - see the recitals.

“Existing Letters of Credit” means the letters of credit issued under the Existing Credit Agreement that are listed on Schedule 2.16.

“FATCA” means Sections 1471 through 1474 of the Code, as of the date of this Agreement (or any amended or successor version that is substantively comparable and not materially more onerous to comply with) and any current or future regulations or official interpretations thereof.

“Federal Funds Effective Rate” means, for any day, an interest rate per annum equal to the weighted average of the rates on overnight Federal funds transactions with members of the Federal Reserve System arranged by Federal funds brokers on such day, as published for such day (or, if such day is not a Business Day, for the immediately preceding Business Day) by the Federal Reserve Bank of New York, or, if such rate is not so published for any day which is a Business Day, the average of the quotations at approximately 11:00 a.m. (New York time) on

8

709152408 03173762

such day on such transactions received by the Administrative Agent from three Federal funds brokers of recognized standing selected by the Administrative Agent in its sole discretion.

“Fee Letter” means each letter agreement referenced in Section 9.13.

“Financial Contract” means any agreement, device or arrangement providing for payments related to fluctuations of interest rates, including interest rate swap or exchange agreements, interest rate cap or collar protection agreements and interest rate options.

“Fitch” means Fitch Ratings Inc. and any successor thereto that is a nationally recognized rating agency (or if neither Fitch Ratings Inc. nor any such successor shall be in the business of rating long-term indebtedness, a nationally recognized rating agency in the United States as mutually agreed between the Majority Banks and the Company).

“Foreign Bank” means a Bank that is not a U.S. Person.

“FRB” means the Board of Governors of the Federal Reserve System, and any Governmental Authority succeeding to any of its principal functions.

“Fronting Exposure” means with respect to any Issuer at any time there is a Defaulting Bank, such Defaulting Bank’s Pro Rata Share of the outstanding Letter of Credit Obligations with respect to Letters of Credit issued by such Issuer, other than Letter of Credit Obligations as to which such Defaulting Bank’s participation obligation has been reallocated to other Banks or Cash Collateralized in accordance with the terms hereof.

“Fund” means any Person (other than a natural person) that is (or will be) engaged in making, purchasing, holding or otherwise investing in commercial loans and similar extensions of credit in the ordinary course of its business.

“GAAP” means generally accepted accounting principles set forth from time to time in the opinions and pronouncements of the Accounting Principles Board and the American Institute of Certified Public Accountants and statements and pronouncements of the Financial Accounting Standards Board (or agencies with similar functions of comparable stature and authority within the U.S. accounting profession), which are applicable to the circumstances as of the date of determination.

“Governmental Authority” means the government of any nation, any state or other political subdivision thereof, any central bank (or similar monetary or regulatory authority) thereof, any agency, authority, instrumentality, regulatory body, court or other entity exercising executive, legislative, judicial, taxing, regulatory or administrative functions of or pertaining to government (including any supra-national bodies such as the European Union or the European Central Bank), and any corporation or other entity owned or controlled, through stock or capital ownership or otherwise, by any of the foregoing.

“Guaranty Obligation” has the meaning specified in the definition of “Contingent Obligation.”

“Honor Date” has the meaning specified in Section 2.16(f).

9

709152408 03173762

“IFRS” means the body of pronouncements issued by the International Accounting Standards Board (IASB), including International Financial Reporting Standards and interpretations approved by the IASB, International Accounting Standards and Standing Interpretations Committee interpretations approved by the predecessor International Accounting Standards Committee and adapted for use in the European Union.

“Increased Cost Bank” has the meaning specified in Section 3.07(b).

“Indebtedness” of any Person means, without duplication, (a) all indebtedness for borrowed money; (b) all redemption obligations in respect of Redeemable Preferred Stock; (c) all obligations issued, undertaken or assumed as the deferred purchase price of property or services (other than trade payables entered into in the ordinary course of business on ordinary terms); (d) all reimbursement or payment obligations (contingent or otherwise) with respect to Surety Instruments; (e) all obligations evidenced by notes, bonds, debentures or similar instruments, including obligations so evidenced incurred in connection with the acquisition of property, assets or businesses; (f) all indebtedness created or arising under any conditional sale or other title retention agreement, or incurred as financing, in either case with respect to property acquired by the Person (even though the rights and remedies of the seller or bank under such agreement in the event of default are limited to repossession or sale of such property); (g) all liabilities properly appearing on the Person’s balance sheet with respect to capital leases; (h) net liabilities under Swap Contracts; (i) all indebtedness referred to in clauses (a) through (h) above secured by (or for which the holder of such Indebtedness has an existing right, contingent or otherwise, to be secured by) any Lien upon or in property (including accounts and contracts rights) owned by such Person, even though such Person has not assumed or become liable for the payment of such Indebtedness; (j) all Securitization Obligations of such Person; and (k) all Guaranty Obligations in respect of indebtedness or obligations of others of the kinds referred to in clauses (a) through (j) above. For all purposes of this Agreement, the Indebtedness of any Person shall include all recourse Indebtedness of any partnership or joint venture or limited liability company in which such Person is a general partner or a joint venturer or a member.

“Indemnified Taxes” means (a) Taxes, other than Excluded Taxes, imposed on or with respect to any payment made by or on account of any obligation of the Company under any Loan Document and (b) to the extent not otherwise described in the foregoing clause (a), Other Taxes.

“Independent Auditor” has the meaning specified in Section 6.01(a).

“Insolvency Proceeding” means, with respect to any Person, (a) any case, action or proceeding with respect to such Person before any court or other Governmental Authority relating to bankruptcy, reorganization, insolvency, liquidation, receivership, dissolution, winding-up or relief of debtors, or (b) any general assignment for the benefit of creditors, composition, marshalling of assets for creditors, or other similar arrangement in respect of its creditors generally or any substantial portion of its creditors undertaken under U.S. Federal, state or foreign law, including the Bankruptcy Code.

“Interest Period” means, with respect to a Eurodollar Advance, a period of one, two, three or six months commencing on a Business Day selected by the Company pursuant to this Agreement. Such Interest Period shall end on the day which corresponds numerically to such date one, two, three or six months thereafter; provided that if there is no such numerically corresponding day in such next, second, third or sixth succeeding month, such Interest Period

10

709152408 03173762

shall end on the last Business Day of such next, second, third or sixth succeeding month. If an Interest Period would otherwise end on a day which is not a Business Day, such Interest Period shall end on the next succeeding Business Day; provided that if such next succeeding Business Day falls in a new calendar month, such Interest Period shall end on the immediately preceding Business Day.

“International Subsidiary” means Centennial International or any Subsidiary thereof (other than any Project Finance Subsidiary).

“IRS” means the Internal Revenue Service, and any Governmental Authority succeeding to any of its principal functions.

“Issuer” means each of U.S. Bank, The Bank of Tokyo-Mitsubishi UFJ, Ltd., JPMorgan Chase Bank, N.A., Wells Fargo Bank, National Association and Royal Bank of Canada in its capacity as issuer of Letters of Credit hereunder and any other Bank that may (with the consent of the Company and the Administrative Agent) issue Letters of Credit hereunder, in each case in its capacity as issuer of a Letter of Credit hereunder.

“Joint Venture” means a single-purpose corporation, partnership, limited liability company, joint venture or other similar legal arrangement (whether created by contract or conducted through a separate legal entity) now or hereafter formed by the Company or any of its Subsidiaries with another Person or Persons in order to conduct a common venture or enterprise with such Person or Persons. The term “Joint Venture” shall not include any Subsidiary.

“LC Collateral Account” has the meaning specified in Section 2.16(k).

“LC Disbursement” has the meaning specified in Section 2.16(d).

“Lending Installation” means, with respect to a Bank or the Administrative Agent, any office, branch, subsidiary or affiliate of such Bank or the Administrative Agent.

“Lien” means any security interest, mortgage, deed of trust, pledge, hypothecation, assignment, charge or deposit arrangement, encumbrance, lien (statutory or other) or preferential arrangement of any kind or nature whatsoever in respect of any property (including those created by, arising under or evidenced by any conditional sale or other title retention agreement, the interest of a lessor under a capital lease, any financing lease having substantially the same economic effect as any of the foregoing, or the filing of any financing statement naming the owner of the asset to which such lien relates as debtor, under the Uniform Commercial Code or any comparable law) and any contingent or other agreement to provide any of the foregoing, but not including the interest of a lessor under an operating lease.

“Letter of Credit” has the meaning specified in Section 2.16(a). The term “Letter of Credit” includes each Existing Letter of Credit.

“Letter of Credit Application” has the meaning specified in Section 2.16(c).

“Letter of Credit Fee” has the meaning specified in Section 2.16(d).

11

709152408 03173762

“Letter of Credit Obligations” means, at any time, the sum, without duplication, of (i) the aggregate undrawn stated amount of all Letters of Credit at such time plus (ii) the aggregate unpaid amount of all Reimbursement Obligations at such time.

“Loan” has the meaning specified in Section 2.01(a).

“Loan Documents” means this Agreement, the Notes, each Letter of Credit, each Letter of Credit Application, each Fee Letter and the other documents and agreements contemplated hereby.

“Majority Banks” means (a) as of any date of determination if the Commitments are then in effect, Banks having in the aggregate in excess of 50% of the Aggregate Commitments; and (b) as of any date of determination if the Commitments have then been terminated and there are Loans outstanding, Banks with Outstanding Credit Exposures aggregating in excess of 50% of the Aggregate Outstanding Credit Exposure. The Commitment of any Defaulting Bank shall be disregarded in determining Majority Banks at any time.

“Margin Stock” means “margin stock” as such term is defined in Regulation T, U or X of the FRB.

“Material Adverse Effect” means a material adverse effect on (a) the business, property, condition (financial or otherwise) or results of operations of the Company and its Subsidiaries taken as a whole, (b) the ability of the Company to perform its obligations under the Loan Documents, or (c) the validity or enforceability of any of the Loan Documents or the rights or remedies of the Administrative Agent or the Banks thereunder.

“Minimum Collateral Amount” means, at any time, (a) with respect to Cash Collateral consisting of cash or deposit account balances, an amount equal to 105% of the Fronting Exposure of all Issuers with respect to Letters of Credit issued and outstanding at such time and (b) otherwise, an amount determined by the Administrative Agent and the Issuers in their sole discretion.

“Modification” and “Modify” are defined in Section 2.16(a).

“Multiemployer Plan” means a “multiemployer plan” (within the meaning of Section 4001(a)(3) of ERISA) to which the Company or any ERISA Affiliate (a) makes, is making, or is obligated to make contributions or, (b) has made, or been obligated to make, contributions during the preceding three calendar years.

“Non-Consenting Bank” means any Bank that does not approve any consent, waiver or amendment that (i) requires the approval of all affected Banks in accordance with the terms of Section 10.01 and (ii) has been approved by the Majority Banks.

“Non-Defaulting Bank” means, at any time, each Bank that is not a Defaulting Bank at such time.

“Note” means a promissory note, in substantially the form of Exhibit C hereto, duly executed by the Company and payable to the order of the applicable Bank, including any amendment, modification, renewal or replacement of such promissory note.

12

709152408 03173762

“Notice of Assignment” has the meaning specified in Section 10.08(e).

“Obligations” means all unpaid principal of and accrued and unpaid interest on the Loans, all Reimbursement Obligations and accrued and unpaid interest thereon, all accrued and unpaid fees and all expenses, reimbursements, indemnities and other obligations of the Company to any Bank, any Issuer, the Administrative Agent or any indemnified party hereunder arising under any Loan Document.

“OFAC” means the U.S. Department of the Treasury’s Office of Foreign Assets Control, and any successor thereto.

“Opinions of Counsel” means the written legal opinion of Paul K. Sandness, general counsel to the Company and its Subsidiaries, substantially in the form of Exhibit B-1, and the written legal opinion of Cohen Tauber Spievack & Wagner, P.C.,  special counsel to the Company and its Subsidiaries, substantially in the form of Exhibit B-2, together with copies of all factual certificates and legal opinions upon which such counsel has relied.

“Organization Documents” means, for any corporation or other entity, the certificate or articles of incorporation (or similar formation document), the bylaws (or similar governing document), any certificate of determination or instrument relating to the rights of preferred equityholders of such Person, any equityholder rights agreement, and all applicable resolutions of the board of directors (or similar governing body) (or any committee thereof) of such Person.

“Other Connection Taxes” means, with respect to any Recipient, Taxes imposed as a result of a present or former connection between such Recipient and the jurisdiction imposing such Tax (other than connections arising from such Recipient having executed, delivered, become a party to, performed its obligations under, received payments under, received or perfected a security interest under, engaged in any other transaction pursuant to or enforced any Loan Document, or sold or assigned an interest in any Loan or Loan Document).

“Other Taxes” means all present or future stamp, court or documentary, intangible, recording, filing or similar Taxes that arise from any payment made under, from the execution, delivery, performance, enforcement or registration of, from the receipt or perfection of a security interest under, or otherwise with respect to, any Loan Document, except any such Taxes that are Other Connection Taxes imposed with respect to an assignment (other than an assignment made pursuant to Section 3.07).

“Outstanding Credit Exposure” means, as to any Bank at any time, the sum of (a) the aggregate principal amount of its Loans outstanding at such time, plus (b) its Pro Rata Share of the Letter of Credit Obligations at such time.

“Participant” has the meaning specified in Section 10.08(a).

“Payment Date” means the last day of each March, June, September and December.

“PBGC” means the Pension Benefit Guaranty Corporation, or any Governmental Authority succeeding to any of its principal functions under ERISA.

“Pension Plan” means a pension plan (as defined in Section 3(2) of ERISA) subject to Title IV of ERISA or the minimum funding standards under Section 412 of the Code, which the

13

709152408 03173762

Company or any ERISA Affiliate sponsors, maintains, or to which it makes, is making, or is obligated to make contributions, or in the case of a multiple employer plan (as described in Section 4064(a) of ERISA) has made contributions at any time during the immediately preceding five (5) plan years but excluding any Multiemployer Plan.

“Permitted Liens” has the meaning specified in Section 7.01.

“Person” means an individual, partnership, corporation, limited liability company, business trust, joint stock company, trust, unincorporated association, joint venture or Governmental Authority.

“Plan” means an employee benefit plan (as defined in Section 3(3) of ERISA) which the Company or any ERISA Affiliate sponsors or maintains or to which the Company or any ERISA Affiliate makes, is making, or is obligated to make contributions and includes any Pension Plan but excludes any Multiemployer Plan.

“Pricing Level” means, for each Pricing Period, the pricing level set forth below opposite the Pricing Rating achieved by the Company as of the first day of that Pricing Period (subject to the provisions of the definition of “Pricing Rating”):

Pricing Level	Pricing Rating
1	At least A
2	At least A-
3	At least BBB+
4	At least BBB
5	At least BBB-
6	Below BBB- or not rated.

“Pricing Level Change Date” means, with respect to any change in the Pricing Level which results in a change in the Applicable Amount, the date which is five Business Days after the Administrative Agent has received evidence reasonably satisfactory to it of such change.

“Pricing Period” means (a) the period commencing on the date of this Agreement and ending on the day prior to the first Pricing Level Change Date to occur thereafter and (b) each subsequent period commencing on each Pricing Level Change Date and ending the day prior to the next Pricing Level Change Date.

“Pricing Rating” means, as of any date of determination of the Applicable Amount, (a) the rating assigned by S&P or Fitch to the outstanding senior unsecured non-credit-enhanced long-term indebtedness of the Company or (b) if neither S&P nor Fitch has assigned a rating of the type described in clause (a), the corporate rating assigned to the Company by S&P or the issuer rating assigned to the Company by Fitch; provided that (i) if the Company is split-rated and the ratings differential is one Pricing Level, the higher rating will apply, (ii) if the Company is split-rated and the ratings differential is two Pricing Levels or more, the intermediate rating at the midpoint will apply (or if there is no midpoint, the higher of the two intermediate ratings will apply) and (iii) if only one of the two rating agencies has assigned such a rating, the Pricing Level corresponding to such rating shall apply. For purposes hereof, the rating by each rating agency as of any date shall be the applicable rating by such agency in effect at the close of business on such date.

14

709152408 03173762

“Prime Rate” means a rate per annum equal to the prime rate of interest announced from time to time by U.S. Bank or its parent (which is not necessarily the lowest rate charged to any customer), changing when and as such prime rate changes.

“Principal Operating Subsidiaries” means each of (i) WBI Holdings, Inc., (ii) Fidelity Exploration & Production Company and (iii) Knife River Corporation, and their respective permitted successors.

“Project Finance Subsidiary” means any Subsidiary that meets each of the following requirements: (a) it is primarily engaged, directly or indirectly, in the ownership, operation and/or financing of facilities and assets used in any line of business engaged in, or closely related to any line of business engaged in, by MDU Resources Group, Inc. and its Subsidiaries as of the date of this Agreement; (b) neither the Company nor any other Subsidiary (other than another Project Finance Subsidiary) has any liability, contingent or otherwise, for the Indebtedness or other obligations of such Subsidiary (other than (i) non-recourse liability resulting solely from the pledge of stock of such Subsidiary and (ii) to the extent permitted by Section 7.04); and (c) it has Indebtedness owing to, or commitments therefor from, Persons other than the Company and its Subsidiaries.

“Pro Rata Share” means, as to any Bank at any time, the percentage equivalent (expressed as a decimal, rounded to the ninth decimal place) at such time of such Bank’s Commitment, subject to adjustment as provided in Section 2.18, divided by the Aggregate Commitment (or, if the Commitments have terminated, of such Bank’s Outstanding Credit Exposure divided by the Aggregate Outstanding Credit Exposure).

“Purchasers” is defined in Section 10.08(d).

“Rate Option” means the Eurodollar Rate or the Base Rate.

“Rate Option Notice” is defined in Section 2.02(d).

“Recipient” means (a) the Administrative Agent, (b) any Bank and (c) any Issuer, as applicable.

“Redeemable Preferred Stock” of any Person means any equity interest of such Person that by its terms (or by the terms of any equity interest into which it is convertible or for which it is exchangeable), or otherwise (including on the happening of an event), is required to be redeemed for cash or other property or is redeemable for cash or other property at the option of the holder thereof, in whole or in part, on or prior to the Termination Date; or is exchangeable for Indebtedness at any time, in whole or in part, on or prior to the Termination Date; provided that Redeemable Preferred Stock shall not include any equity interest by virtue of the fact that it may be exchanged or converted at the option of the holder or of the Company for equity interests of the Company having no preference as to dividends, distributions or liquidation over any other equity interests of the Company.

“Regulation D” means Regulation D of the FRB as from time to time in effect and any successor thereto or other regulation or official interpretation of the FRB relating to reserve requirements applicable to member banks of the Federal Reserve System.

15

709152408 03173762

“Reimbursement Obligations” means, at any time, the aggregate of all obligations of the Company then outstanding under Section 2.16 to reimburse the Issuers for amounts paid by the Issuers in respect of any one or more drawings under Letters of Credit.

“Reportable Event” means any of the events required to be reported by Section 4043(c) of ERISA or the regulations thereunder, other than any such event for which the 30-day notice requirement under ERISA has been waived in regulations issued by the PBGC.

“Requirement of Law” means, as to any Person, any law (statutory or common), treaty, rule or regulation or determination of an arbitrator or of a Governmental Authority, in each case applicable to or binding upon the Person or any of its property or to which the Person or any of its property is subject.

“Reserve Requirement” means, with respect to an Interest Period, the maximum aggregate reserve requirement (including all basic, supplemental, marginal and other reserves) which is imposed under Regulation D on Eurocurrency liabilities during such Interest Period.

“Responsible Officer” means the chief executive officer or the president of the Company, or any other officer having substantially the same authority and responsibility; or, with respect to compliance with financial covenants, the chief financial officer, the treasurer or the assistant treasurer of the Company, or any other officer having substantially the same authority and responsibility. Any document or certificate hereunder that is signed or executed by a Responsible Officer shall be conclusively presumed to have been authorized by all necessary corporate, partnership and/or other action on the part of the Company, and such officer shall be conclusively presumed to have acted on behalf of the Company.

“S&P” means Standard & Poor’s Financial Services LLC, a subsidiary of The McGraw-Hill Companies Inc., and any successor thereto that is a nationally recognized rating agency (or, if neither such division nor any successor shall be in the business of rating long-term indebtedness, a nationally recognized rating agency in the United States as mutually agreed between the Majority Banks and the Company).

“Sanctioned Country” means a country subject to a sanctions program identified on the list maintained by OFAC and available at http://www.treas.gov/offices/enforcement/ofac/sanctions/index.html, or as otherwise published from time to time.

“Sanctioned Person” means (a) a Person named on the list of Specially Designated Nationals or Blocked Persons maintained by OFAC available at http://www.treas.gov/offices/enforcement/ofac/sdn/index.html, or as otherwise published from time to time, or (b) (i) an agency of the government of a Sanctioned Country, (ii) an organization controlled by a Sanctioned Country, or (iii) a Person resident in a Sanctioned Country, to the extent subject to a sanctions program administered by OFAC.

“SEC” means the Securities and Exchange Commission, or any Governmental Authority succeeding to any of its principal functions.

“Securitization Obligations” means, with respect to any Securitization Transaction, the aggregate investment or claim held at any time by all purchasers, assignees or transferees of (or of interests in) or holders of obligations that are supported or secured by accounts receivable, lease receivables and other rights to payment in connection with such Securitization Transaction.

16

709152408 03173762

“Securitization Transaction” means any sale, assignment or other transfer by the Company or any Subsidiary (other than a Project Finance Subsidiary) of accounts receivable, lease receivables or other payment obligations owing to the Company or such Subsidiary or any interest in any of the foregoing, together in each case with any collections and other proceeds thereof, any collection or deposit accounts related thereto, and any collateral, guaranties or other property or claims in favor of the Company or such Subsidiary supporting or securing payment by the obligor thereon of, or otherwise related to, any such receivables.

“Significant Subsidiary” means a “Significant Subsidiary” as defined in Rule 1‑02(w) of Regulation S-X of the SEC, as in effect on the date hereof.

“Solvent” means, as to any Person at any time, that (a) the fair value of the property of such Person is greater than the amount of such Person’s liabilities (including the probable liability of such Person on disputed, contingent and unliquidated liabilities) as such value is established and liabilities evaluated for purposes of Section 101(32) of the Bankruptcy Code; (b) the present fair saleable value of the property of such Person is not less than the amount that will be required to pay the probable liability of such Person on its debts as they become absolute and matured; (c) such Person is able to realize upon its property and pay its debts and other liabilities (including the probable liability of such Person on disputed, contingent and unliquidated liabilities) as they mature in the normal course of business; (d) such Person does not intend to, and does not believe that it will, incur debts or liabilities beyond such Person’s ability to pay as such debts and liabilities mature; and (e) such Person is not engaged in business or a transaction, and is not about to engage in business or a transaction, for which such Person’s property would constitute unreasonably small capital.

“Subsidiary” of a Person means any corporation, association, partnership, limited liability company, joint venture or other business entity of which more than 50% of the voting stock, membership interests or other equity interests (in the case of Persons other than corporations), is owned or controlled directly or indirectly by the Person, or one or more of the Subsidiaries of the Person, or a combination thereof. Unless the context otherwise clearly requires, references herein to a “Subsidiary” refer to a Subsidiary of the Company.

“Surety Instruments” means all letters of credit (including standby and commercial), banker’s acceptances, bank guaranties, shipside bonds, surety bonds and similar instruments.

“Swap Contract” means swap agreements (as such term is defined in Section 101(53B) of the Bankruptcy Code) and any other agreements or arrangements designed to provide protection against fluctuations in interest or currency exchange rates or commodity prices, including Commodity Contracts and Financial Contracts.

“Swap Termination Value” means, in respect of any one or more Swap Contracts, after taking into account the effect of any legally enforceable netting agreement relating to such Swap Contracts, (a) for any date on or after the date such Swap Contracts have been closed out and termination value(s) determined in accordance therewith, such termination value(s), and (b) for any date prior to the date referenced in clause (a) the amount(s) determined as the mark-to-market value(s) for such Swap Contracts, as determined by the Company based upon one or more mid-market or other readily available quotations provided by any recognized dealer in such Swap Contracts (which may include any Bank).

17

709152408 03173762

“Taxes” means all present or future taxes, duties, levies, imposts, deductions, withholdings (including backup withholding), assessments, fees or other charges imposed by any Governmental Authority, including any interest, additions to tax or penalties applicable thereto.

“Termination Date” means May 8, 2019 or any earlier date on which the Aggregate Commitment is reduced to zero or otherwise terminated pursuant to the terms hereof.

“Total Capitalization” means, with respect to any Person, the sum of (a) the total consolidated stockholders’ or owners’ equity of such Person determined in accordance with GAAP (excluding any non-cash gain or loss with respect to Covered Contracts resulting from the requirements of Accounting Standards Codification 815-20-25-104, formerly known as FASB Statement No. 133, “Accounting for Derivative Instruments and Hedging Activities”) plus (b) the Total Debt of such Person.

“Total Debt” means, with respect to any Person, the total consolidated Indebtedness of such Person, excluding (a) Indebtedness under Covered Contracts and (b) 80% of the amount of all contingent reimbursement or payment obligations with respect to unsecured surety bonds incurred in the ordinary course of business includable in the computation of “Indebtedness” pursuant to item (d) of the definition thereof but for this exclusion.

“Transferee” is defined in Section 10.08(f).

“Type” means with respect to any Advance, its nature as a Base Rate Advance or a Eurodollar Advance.

“Unfunded Pension Liability” means the excess of a Pension Plan’s benefit liabilities under Section 302(d)(7) of ERISA, over the current value of that Plan’s assets, determined in accordance with the assumptions used for funding the Pension Plan pursuant to Section 412 of the Code for the applicable plan year.

“United States” and “U.S.” each mean the United States of America.

“U.S. Bank” means U.S. Bank National Association.

“U.S. Person” means any Person that is a “United States Person” as defined in Section 7701(a)(30) of the Code.

“U.S. Tax Compliance Certificate” has the meaning assigned to such term in Section 3.06(g).

“Wholly-Owned Subsidiary” means any entity in which (other than, in the case of a corporation, directors’ qualifying shares required by law) 100% of the capital stock or other equity interests of each class, if applicable, having ordinary voting power, and 100% of the capital stock or other equity interests of every other class, if applicable, in each case, at the time as of which any determination is being made, is owned, beneficially and of record, by the Company, or by one or more of the other Wholly-Owned Subsidiaries, or both.

“Williston Basin” is defined in Section 7.05.

“Withholding Agent” means each of the Company and the Administrative Agent.

18

709152408 03173762

1.02    Other Interpretive Provisions. (a) The meanings of defined terms are equally applicable to the singular and plural forms of the defined terms

(b)    The words “hereof”, “herein”, “hereunder” and similar words refer to this Agreement as a whole and not to any particular provision of this Agreement; and Section, Schedule, Article and Exhibit references are to this Agreement unless otherwise specified.

(c)    (i)The term “documents” includes any and all instruments, documents, agreements, certificates, indentures, notices and other writings, however evidenced.

(ii)    The term “including” is not limiting and means “including without limitation.”

(iii)    In the computation of periods of time from a specified date to a later specified date, the word “from” means “from and including”; the words “to” and “until” each mean “to but excluding”, and the word “through” means “to and including.”

(iv)    The term “property” includes any kind of property or asset, real, personal or

mixed, tangible or intangible.

(d)    Unless otherwise expressly provided herein, (i) references to agreements (including this Agreement) and other contractual instruments shall be deemed to include all subsequent amendments and other modifications thereto, but only to the extent such amendments and other modifications are not prohibited by the terms of any Loan Document, and (ii) references to any statute or regulation are to be construed as including all statutory and regulatory provisions consolidating, amending, replacing, supplementing or interpreting the statute or regulation.

(e)    The captions and headings of this Agreement are for convenience of reference only and shall not affect the interpretation of this Agreement.

(f)    This Agreement and other Loan Documents may use several different limitations, tests or measurements to regulate the same or similar matters. All such limitations, tests and measurements are cumulative and shall each be performed in accordance with their terms. Unless otherwise expressly provided, any reference to any action of the Administrative Agent or the Banks by way of consent, approval or waiver shall be deemed modified by the phrase “in its/their sole discretion.”

(g)    This Agreement and the other Loan Documents are the result of negotiations among and have been reviewed by counsel to the Administrative Agent, the Company and the other parties, and are the products of all parties. Accordingly, they shall not be construed against the Banks or the Administrative Agent merely because of the Administrative Agent’s or Banks’ involvement in their preparation.

1.03    Accounting Principles. (a) Unless the context otherwise clearly requires, all accounting terms not expressly defined herein shall be construed, and all financial computations required under this Agreement shall be made, in accordance with GAAP, consistently applied. Notwithstanding the foregoing, the Company may notify the Administrative Agent at any time that it has adopted IFRS in lieu of GAAP and, upon any such notice, references herein to GAAP shall thereafter be construed to mean IFRS as in effect from time to time. If at any time the

19

709152408 03173762

adoption of IFRS by the Company or any change in GAAP would affect the computation of any financial ratio or requirement set forth in any Loan Document, and the Company, the Administrative Agent or the Majority Banks shall so request, the Administrative Agent, the Banks and the Company shall negotiate in good faith to amend such ratio or requirement to preserve the original intent thereof in light of such adoption of IFRS or change in GAAP (subject to the approval of the Majority Banks); providedthat, until so amended, such ratio or requirement shall continue to be computed in accordance with GAAP as in effect and applied immediately before such adoption of IFRS or change in GAAP shall have become effective and the Company shall provide to the Administrative Agent and the Banks reconciliation statements showing the difference in such calculation, together with the delivery of monthly, quarterly and annual financial statements required hereunder. Notwithstanding the foregoing, for all purposes hereof, no effect shall be given hereunder to any change under GAAP that results in operating leases being treated as capital leases.

(b)    References herein to “fiscal year” and “fiscal quarter” refer to such fiscal periods of the Company.

1.04    Amendment and Restatement. The Company and the Banks acknowledge and agree that (a) effective at the time at which all conditions precedent set forth in Section 4.01 have been satisfied, this Agreement shall amend and restate in its entirety the Existing Credit Agreement and (b) there are no outstanding Loans under the Existing Credit Agreement.

ARTICLE II

THE FACILITY

2.01    The Facility.

(a)    Commitments of the Banks. Each Bank severally agrees to make revolving loans (each a “Loan”) to the Company, and each Issuer agrees to issue Letters of Credit for the account of the Company (or jointly and severally for the account of the Company and Centennial International), and each Bank severally agrees to participate in each such Letter of Credit as more fully set forth in Section 2.16, from time to time on or prior to the Termination Date; provided that (i) the aggregate amount of the outstanding Letter of Credit Obligations shall not exceed $100,000,000, (ii) the aggregate stated amount of Letters of Credit issued for the account of the Company and Centennial International shall not at any time exceed $50,000,000, (iii) after giving effect to any Credit Extension (and the use of proceeds thereof), the Company shall be in compliance with the last sentence of Section 7.12, (iv) the Outstanding Credit Exposure of any Bank shall not at any time exceed such Bank’s Commitment, (v) the Aggregate Outstanding Credit Exposure shall not at any time exceed the Aggregate Commitment and (vi) unless otherwise agreed to by a particular Issuer, the aggregate stated amount of the outstanding Letters of Credit issued by each Issuer shall not exceed $20,000,000. Subject to the terms of this Agreement, the Company may borrow, repay and reborrow Loans at any time prior to the Termination Date.

(b)    Repayment of Facility. The principal amount of each Advance and all other unpaid Obligations shall be paid in full by the Company on the Termination Date.

2.02    Advances.

20

709152408 03173762

(a)Advances. Each Advance hereunder shall consist of Loans made from the several Banks ratably in proportion to the amounts of their respective Commitments.

(b)Advance Rate Options. The Advances may be Base Rate Advances or Eurodollar Advances, or a combination thereof, selected by the Company in accordance with Section 2.02(c). No Advance may mature after the Termination Date.

(c)Method of Selecting Rate Options and Interest Periods for Advances. The Company shall select the Rate Option and, in the case of each Eurodollar Advance, the Interest Period applicable thereto, from time to time. The Company shall give the Administrative Agent irrevocable notice (a “Borrowing Notice”) substantially in the form of Exhibit H not later than 11:30 a.m. (New York time) at least one Business Day before the Borrowing Date of each Base Rate Advance and at least three Business Days before the Borrowing Date for each Eurodollar Advance. A Borrowing Notice shall specify:

(i)    the Borrowing Date, which shall be a Business Day, of such Advance,

(ii)    the aggregate amount of such Advance,

(iii)    the Rate Option selected for such Advance, and

(iv)    in the case of each Eurodollar Advance, the Interest Period applicable thereto

(which may not end after the Termination Date).

(d)Conversion and Continuation of Outstanding Advances. Base Rate Advances shall continue as Base Rate Advances unless and until such Base Rate Advances are either converted into Eurodollar Advances in accordance with this Section 2.02(d) or are prepaid in accordance with Section 2.06. Each Eurodollar Advance shall continue as a Eurodollar Advance until the end of the then applicable Interest Period therefor, at which time such Eurodollar Advance shall be automatically converted into a Base Rate Advance unless such Eurodollar Advance shall have been either (a) prepaid in accordance with Section 2.06 or (b) continued as a Eurodollar Advance for the same or another Interest Period in accordance with this Section 2.02(d). Subject to the terms of Section 2.05, the Company may elect from time to time to convert an Advance having one Rate Option to an Advance having a different Rate Option, or to continue the Rate Option applicable to all or any part of an Advance; provided that any conversion or continuation of any Eurodollar Advance shall be made on, and only on, the last day of the Interest Period applicable thereto. The Company shall give the Administrative Agent irrevocable notice (a “Rate Option Notice”) of each conversion of a Base Rate Advance into a Eurodollar Advance, or continuation of a Eurodollar Advance, not later than 11:30 a.m. (New York time) at least three Business Days prior to the date of the requested conversion or continuation, specifying:

(i)    the requested date, which shall be a Business Day, of such conversion or continuation,

(ii)    the aggregate amount and Rate Option applicable to the Advance which is to be converted or continued, and

21

709152408 03173762

(iii)    the amount and Rate Option(s) of Advance(s) into which such Advance is to be converted or continued and, in the case of a conversion into or continuation of a Eurodollar Advance, the duration of the Interest Period applicable thereto.

2.03    Method of Borrowing. Not later than 1:00 p.m. (New York time) on each Borrowing Date, each Bank shall make available its Loan or Loans, in funds immediately available in New York to the Administrative Agent at its address specified pursuant to Section 10.02. The Administrative Agent will make the funds so received from the Banks available to the Company at the Administrative Agent’s aforesaid address.

2.04    Fees; Changes in Aggregate Commitment.

(a)    Facility Fee. The Company agrees to pay to the Administrative Agent for the account of each Bank a facility fee equal to the Applicable Amount on the average daily amount of such Bank’s Commitment (whether used or unused) from the date hereof to and including the Termination Date, payable in arrears on each Payment Date hereafter and on the Termination Date.

(b)    Changes in Aggregate Commitment.

(A)The Company may permanently reduce the Aggregate Commitment in whole, or in part ratably among the Banks in integral multiples of $5,000,000, upon at least five Business Days’ written notice to the Administrative Agent, which notice shall specify the amount of any such reduction; provided that the amount of the Aggregate Commitment may not be reduced below the Aggregate Outstanding Credit Exposure. All accrued facility fees shall be payable on the effective date of any termination of the Commitments.

(B)So long as no Default or Event of Default exists, the Company may, from time to time, by means of a letter delivered to the Administrative Agent substantially in the form of Exhibit G, request that the Aggregate Commitment be increased, by a minimum amount of $25,000,000 and higher integral multiples of $5,000,000; provided that the aggregate amount of all increases under this Section 2.04(b) shall not exceed $150,000,000, by (a) increasing the Commitment of one or more Banks which have agreed to such increase and/or (b) adding one or more commercial banks or other Persons as a party hereto (each an “Additional Bank”) with a Commitment in an amount agreed to by any such Additional Bank; provided that no Additional Bank shall be added as a party hereto without the written consent of the Administrative Agent (which shall not be unreasonably withheld). Any increase in the Aggregate Commitment pursuant to this clause (B) shall be effective three Business Days after the date on which the Administrative Agent has received and accepted the applicable increase letter in the form of Annex I to Exhibit G (in the case of an increase in the Commitment of an existing Bank) or assumption letter in the form of Annex II to Exhibit G (in the case of the addition of a commercial bank or other Person as a new Bank). The Administrative Agent shall promptly notify the Company and the Banks of any increase in the amount of the Aggregate Commitment pursuant to this clause (B) and of the Commitment of each Bank after giving effect thereto. The Company acknowledges that, in order to maintain Advances in accordance with each Bank’s pro-rata share of all outstanding Advances

22

709152408 03173762

prior to any increase in the Aggregate Commitment pursuant to this clause (B), a reallocation of the Commitments as a result of a non-pro-rata increase in the Aggregate Commitment may require prepayment of all or portions of certain Advances on the date of such increase (and any such prepayment shall be subject to the provisions of Section 3.05). For the avoidance of doubt, no Bank shall be required to participate in any increase in the Aggregate Commitment except in its sole discretion.

2.05    Minimum Amount of Each Advance. Except as provided in Section 2.16(f), each Eurodollar Advance shall be in the minimum amount of $5,000,000 (and in multiples of $1,000,000 if in excess thereof), and each Base Rate Advance shall be in the minimum amount of $1,000,000 (and in multiples of $1,000,000 if in excess thereof); provided that any Base Rate Advance may be in the amount of the unused Commitments. The Company shall not request a Eurodollar Advance if, after giving effect to the requested Eurodollar Advance, more than 10 separate Eurodollar Advances would be outstanding.

2.06    Optional Principal Payments. The Company may from time to time pay, without penalty or premium, all outstanding Base Rate Advances, or, in a minimum aggregate amount of $1,000,000 or any integral multiple of $1,000,000 in excess thereof, any portion of the outstanding Base Rate Advances upon at least one Business Day’s prior notice to the Administrative Agent. The Company may from time to time pay all outstanding Eurodollar Advances, or, in a minimum aggregate amount of $5,000,000 or any integral multiple of $1,000,000 in excess thereof, any portion of the outstanding Eurodollar Advances upon at least three Business Days’ prior notice to the Administrative Agent, without penalty or premium, but subject to any funding indemnification as provided in Section 3.05.

2.07    Changes in Interest Rate, etc. Each Base Rate Advance shall bear interest on the outstanding principal amount thereof, for each day from and including the date such Advance is made or is converted from a Eurodollar Advance into a Base Rate Advance pursuant to Section 2.02(d) to but excluding the date it is paid (except as otherwise provided in Section 2.08) or is converted into a Eurodollar Advance pursuant to Section 2.02(d), at a rate per annum equal to the Base Rate for such day. Changes in the rate of interest on that portion of any Advance maintained as a Base Rate Advance will take effect simultaneously with each change in the Alternate Base Rate. Each Eurodollar Advance shall bear interest on the outstanding principal amount thereof from and including the first day of the Interest Period applicable thereto to (but not including) the last day of such Interest Period at the interest rate determined as applicable to such Eurodollar Advance.

2.08    Rates Applicable After Default. Notwithstanding anything to the contrary contained in Section 2.02(c) or Section 2.02(d), during the continuance of a Default or an Event of Default the Majority Banks may, at their option, by notice to the Company (which notice may be revoked at the option of the Majority Banks notwithstanding any provision of Section 10.01 requiring unanimous consent of the Banks to changes in interest rates), declare that no Advance may be made as, converted into or continued as a Eurodollar Advance. If any Advance is not paid at maturity, whether by acceleration or otherwise, the Majority Banks may, at their option, by notice to the Company (which notice may be revoked at the option of the Majority Banks notwithstanding any provision of Section 10.01 requiring unanimous consent of the Banks to changes in interest rates), declare that (i) each Eurodollar Advance shall bear interest for the remainder of the applicable Interest Period at the rate otherwise applicable to such Interest Period plus 2% per annum, (ii) each Base Rate Advance shall bear interest at a rate per annum equal to

23

709152408 03173762

the Base Rate otherwise applicable to such Base Rate Advance plus 2% per annum and (iii) the rate applicable to the Letter of Credit Fee shall be increased by 2% per annum.

2.09    Method of Payment. All payments of the Obligations hereunder shall be made, without setoff, deduction, or counterclaim, in immediately available funds, to the Administrative Agent at the Administrative Agent’s address specified pursuant to Section 10.02, or at any other Lending Installation of the Administrative Agent specified in writing by the Administrative Agent to the Company, by 12:00 noon (New York time) on the date when due and shall be applied ratably by the Administrative Agent among the Banks to the payment of all Obligations then due and payable, if any, and otherwise to the payment of the remaining Obligations. Each payment delivered to the Administrative Agent for the account of any Bank shall be delivered promptly by the Administrative Agent to such Bank in the same type of funds that the Administrative Agent received at its address specified pursuant to Section 10.02 or at any Lending Installation specified in a notice received by the Administrative Agent from such Bank. The Administrative Agent is hereby authorized to charge the account of the Company maintained with the Administrative Agent (and/or its Affiliates) for each payment of principal, interest and fees as it becomes due hereunder.

2.10    Evidence of Debt; Telephonic Notices. The Credit Extensions made by each Bank shall be evidenced by one or more accounts or records maintained by such Bank and by the Administrative Agent in the ordinary course of business. The accounts or records maintained by the Administrative Agent and each Bank shall be conclusive absent manifest error of the amount of the Credit Extensions made by the Banks to the Company and the interest and payments thereon. Any failure to so record or any error in doing so shall not, however, limit or otherwise affect the obligation of the Company hereunder to pay any amount owing hereunder. In the event of any conflict between the accounts and records maintained by any Bank and the accounts and records of the Administrative Agent in respect of such matters, the accounts and records of the Administrative Agent shall control in the absence of manifest error. Upon the request of any Bank made through the Administrative Agent, the Company shall execute and deliver to such Bank (through the Administrative Agent) a Note, which shall evidence such Bank’s Loans in addition to such accounts or records. Each Bank may attach schedules to its Note and endorse thereon the date, Type (if applicable), amount and maturity of its Loans and payments with respect thereto. The Company hereby authorizes the Banks and the Administrative Agent to extend, convert or continue Advances, effect selections of Rate Options and transfer funds based on telephonic notices made by any person or persons the Administrative Agent or any Bank in good faith believes to be acting on behalf of the Company. The Company agrees to deliver promptly to the Administrative Agent a written confirmation, if such confirmation is requested by the Administrative Agent or any Bank, of each telephonic notice signed by a Responsible Officer. If the written confirmation differs in any material respect from the action taken by the Administrative Agent and the Banks, the records of the Administrative Agent and the Banks shall govern absent manifest error.

2.11    Interest Payment Dates; Interest and Fee Basis. Interest accrued on each Base Rate Advance shall be payable on each Payment Date hereafter and at maturity. Interest accrued on each Eurodollar Advance shall be payable on the last day of its applicable Interest Period, on any date on which the Eurodollar Advance is prepaid, whether by acceleration or otherwise, and at maturity. Interest accrued on each Eurodollar Advance having an Interest Period longer than three months shall also be payable on the last day of each three-month interval during such Interest Period. Interest and fees shall be calculated for actual days elapsed on the basis of a

24

709152408 03173762

360-day year, with the exception that interest on Base Rate Advances shall be calculated on the basis of a 365- or 366-day year, as appropriate. Interest shall be payable for the day an Advance is made but not for the day of any payment thereof on the amount paid if payment is received prior to 12:00 noon (New York time) at the place of payment. If any payment of principal of or interest on an Advance shall become due on a day which is not a Business Day, such payment shall be made on the next succeeding Business Day and, in the case of a principal payment, such extension of time shall be included in computing interest in connection with such payment.

2.12    Notification of Advances, Interest Rates, Prepayments and Commitment Changes. Promptly after receipt thereof, the Administrative Agent will notify each Bank of the contents of each Aggregate Commitment reduction or increase notice, Borrowing Notice, Rate Option Notice and repayment notice received by it hereunder. The Administrative Agent will notify each Bank of the interest rate applicable to each Eurodollar Advance promptly upon determination of such interest rate and will give each Bank prompt notice of each change in the Alternate Base Rate.

2.13    Lending Installations. Each Bank may book its Loans at any Lending Installation selected by such Bank and may change its Lending Installation from time to time. All terms of this Agreement shall apply to any such Lending Installation and the Loans shall be deemed held by each Bank for the benefit of such Lending Installation. Each Bank may, by written notice to the Administrative Agent and the Company, designate a Lending Installation through which Loans will be made by it and for whose account Loan payments are to be made.

2.14    Non-Receipt of Funds by the Administrative Agent. Unless the Company or a Bank, as the case may be, notifies the Administrative Agent prior to the date on which it is scheduled to make payment to the Administrative Agent of (i) in the case of a Bank, the proceeds of a Loan or (ii) in the case of the Company, a payment of principal, interest or fees to the Administrative Agent for the account of the Banks, that it does not intend to make such payment, the Administrative Agent may assume that such payment has been made. The Administrative Agent may, but shall not be obligated to, make the amount of such payment available to the intended recipient in reliance upon such assumption. If such Bank or the Company, as the case may be, has not in fact made such payment to the Administrative Agent, the recipient of such payment shall, on demand by the Administrative Agent, repay to the Administrative Agent the amount so made available together with interest thereon in respect of each day during the period commencing on the date such amount was so made available by the Administrative Agent until the date the Administrative Agent recovers such amount at a rate per annum equal to (i) in the case of payment by a Bank, the Federal Funds Effective Rate for such day or (ii) in the case of payment by the Company, the interest rate applicable to the relevant Loan.

2.15    Replacement of Bank. If (i) any Bank is a Defaulting Bank, (ii) the Company is required pursuant to Section 3.01, 3.02 or 3.06 to make any additional payment to any Bank or (iii) any Bank’s obligation to make or continue, or to convert Base Rate Advances into, Eurodollar Advances shall be suspended pursuant to Section 3.04 (any Bank so affected, an “Affected Bank”), the Company may elect, if any of the foregoing circumstances continue to exist, as applicable, to replace such Affected Bank as a Bank party to this Agreement (unless, in the case of the foregoing clause (ii) or clause (iii), such replacement would not reduce or eliminate such amounts or eliminate such suspension); provided that no Default or Event of Default shall have occurred and be continuing at the time of such replacement and such replacement would not result in the violation of any Requirement of Law by such Affected Bank;

25

709152408 03173762

and provided, further, that, concurrently with such replacement, (A) another bank or other entity which is reasonably satisfactory to the Company and the Administrative Agent shall agree, as of such date, to purchase for cash the Advances and other Obligations due to such Affected Bank pursuant to an assignment substantially in the form of Exhibit F and to become a Bank for all purposes under this Agreement and to assume all obligations of such Affected Bank to be terminated as of such date and to comply with the requirements of Section 10.08 applicable to assignments (it being understood that such Affected Bank shall not be obligated to pay the processing fee described in Section 10.08(e)(ii) in connection with any such assignment) and (B) the Company shall pay to such Affected Bank in same day funds on the day of such replacement (1) all interest, fees and other amounts then accrued but unpaid to such Affected Bank by the Company hereunder to and including the date of termination, including payments due to such Affected Bank under Sections 3.01, 3.02, 3.05 and 3.06, and (2) an amount, if any, equal to the payment which would have been due to such Bank on the day of such replacement under Section 3.07 had the Loans of such Affected Bank been prepaid on such date rather than sold to the replacement Bank.

2.16    Letters of Credit.

(a)    Issuance. Subject to Section 2.01, each Issuer hereby agrees, on the terms and conditions set forth in this Agreement, to issue standby letters of credit (each a “Letter of Credit”) and to renew, extend, increase, decrease or otherwise modify Letters of Credit (“Modify,” and each such action a “Modification”), in each case in a form reasonably acceptable to the Administrative Agent and such Issuer, from time to time from and including the date of this Agreement and prior to the Termination Date upon the request of the Company. No Letter of Credit shall have an expiry date later than the earlier of (x) one year after the issuance thereof (provided that any Letter of Credit may provide for the automatic renewal thereof for additional one-year periods (unless the applicable Issuer elects not to extend)) and (y) five Business Days prior to the Termination Date (unless such Letter of Credit is Cash Collateralized as required by Section 2.16(k)). No Issuer shall be obligated to issue any Letter of Credit if (i) any order, judgment or decree of any Governmental Authority or arbitrator shall by its terms purport to enjoin or restrain such Issuer from issuing such Letter of Credit, or any law applicable to such Issuer or any request or directive (whether or not having the force of law) from any Governmental Authority with jurisdiction over such Issuer shall prohibit, or request that such Issuer refrain from, the issuance of letters of credit generally or such Letter of Credit in particular or shall impose upon such Issuer with respect to such Letter of Credit any restriction, reserve or capital requirement (for which such Issuer is not otherwise compensated hereunder) not in effect on the Execution Date, or shall impose upon such Issuer any unreimbursed loss, cost or expense which was not applicable on the Execution Date and which such Issuer in good faith deems material to it; (ii) except as otherwise agreed by the Administrative Agent and such Issuer, such Letter of Credit is in an initial stated amount less than $500,000; (iii) such Letter of Credit is to be denominated in a currency other than Dollars; or (iv) any Bank is at that time a Defaulting Bank, unless such Issuer has entered into arrangements, including the delivery of Cash Collateral, satisfactory to such Issuer (in its sole discretion) with the Company or such Bank to eliminate such Issuer’s actual or potential Fronting Exposure (after giving effect to Section 2.18(a)(iv)) with respect to such Defaulting Bank and all other Obligations as to which such Issuer has actual or potential Fronting Exposure, as it may elect in its sole discretion.

(b)    Participations. Upon the issuance or Modification by an Issuer of a Letter of Credit in accordance with this Section 2.16 (or, in the case of any Existing Letter of Credit, on

26

709152408 03173762

the date hereof), such Issuer shall be deemed, without further action by any Person, to have unconditionally and irrevocably sold to each Bank, and each Bank shall be deemed, without further action by any Person, to have unconditionally and irrevocably purchased from such Issuer, a participation in such Letter of Credit (and each Modification thereof) and the related Letter of Credit Obligations in proportion to its Pro Rata Share.

(c)    Notice. Subject to Section 2.16(a), the Company shall give the Administrative Agent and the applicable Issuer notice prior to 11:00 a.m. (New York time) at least three Business Days (or such lesser period of time as such Issuer may agree in its sole discretion) prior to the proposed date of issuance or Modification of each Letter of Credit, (i) specifying the beneficiary, the proposed date of issuance (or Modification) and the expiry date of such Letter of Credit, (ii) describing the proposed terms of such Letter of Credit and the nature of the transactions proposed to be supported thereby and (iii) if such Letter of Credit is to be issued jointly and severally for the account of the Company and Centennial International, signed by both such entities and confirming that, after giving effect to the issuance of such Letter of Credit, the Company is in compliance with the last sentence of Section 7.12. Upon receipt of such notice the Administrative Agent shall promptly notify each Bank of the contents thereof and of the amount of such Bank’s participation in such proposed Letter of Credit. The issuance or Modification by an Issuer of any Letter of Credit shall, in addition to the conditions precedent set forth in Article IV (the satisfaction of which such Issuer shall have no duty to ascertain, it being understood, however, that such Issuer shall not issue any Letter of Credit if it has received written notice from the Company, the Administrative Agent or any Bank that any such conditions precedent have not been satisfied), be subject to the conditions precedent that (i) the applicable Issuer has received notice from the Administrative Agent confirming that there is availability for the issuance of such Letter of Credit and (ii) such Letter of Credit shall be satisfactory to such Issuer and that the Company shall have executed and delivered such application agreement and/or such other instruments and agreements relating to such Letter of Credit as such Issuer shall have reasonably requested (each a “Letter of Credit Application”). In the event of any conflict between the terms of this Agreement and the terms of any Letter of Credit Application, the terms of this Agreement shall control.

(d)    Letter of Credit Fees. The Company shall pay to the Administrative Agent, for the account of the Banks ratably in accordance with their respective Pro Rata Shares, with respect to each Letter of Credit, a letter of credit fee (the “Letter of Credit Fee”) at a per annum rate equal to the Applicable Amount in effect from time to time on the maximum undrawn amount which may at any time thereafter be available under such Letter of Credit, such fee to be payable in arrears on each Payment Date hereafter, on the Termination Date and thereafter on demand (any such payment, an “LC Disbursement”). The Company shall also pay to each Issuer for its own account (x) a fronting fee as set forth in the applicable Fee Letter, with such fee to be payable in arrears on each Payment Date hereafter, and (y) documentary and processing charges in connection with the issuance or Modification of and draws under the applicable Letters of Credit in accordance with such Issuer’s standard schedule for such charges as in effect from time to time.

(e)    Administration; Reimbursement by Banks. Upon receipt from the beneficiary of any Letter of Credit of any demand for payment under such Letter of Credit, the applicable Issuer shall notify the Administrative Agent and the Administrative Agent shall promptly notify the Company and each other Bank as to the amount to be paid by such Issuer as a result of such demand. The responsibility of any Issuer to the Company and each Bank shall

27

709152408 03173762

be only to determine that the documents delivered under each applicable Letter of Credit in connection with a demand for payment are in conformity in all material respects with such Letter of Credit. Each Issuer shall endeavor to exercise the same care in its issuance and administration of Letters of Credit as it does with respect to letters of credit in which no participations are granted, it being understood that in the absence of any gross negligence or willful misconduct by such Issuer, each Bank shall be unconditionally and irrevocably obligated, without regard to the occurrence of any Default or any condition precedent whatsoever, to reimburse such Issuer on demand for (i) such Bank’s Pro Rata Share of the amount of each payment made by such Issuer under each Letter of Credit to the extent such amount is not reimbursed by the Company pursuant to Section 2.16(f) below, plus (ii) interest on the foregoing amount, for each day from the date of the applicable payment by such Issuer to the date on which such Issuer is reimbursed by such Bank for its Pro Rata Share thereof, at a rate per annum equal to the Federal Funds Effective Rate or, beginning on the third Business Day after demand for such amount by such Issuer, the rate applicable to Base Rate Advances.

(f)    Reimbursement by Company. The Company shall reimburse (which reimbursement may be by the making of Base Rate Advances pursuant to this Section 2.16(f) or otherwise) the applicable Issuer through the Administrative Agent prior to 12:00 noon (New York time) on the date that any amount is paid by such Issuer under any Letter of Credit (each such date, an “Honor Date”) or, if the Company does not receive notice of such payment by such Issuer prior to 10:00 a.m. (New York time) on an Honor Date, on the next succeeding Business Day after the Honor Date (in which case such reimbursement shall include interest for the period from the Honor Date to the date of reimbursement at the rate then applicable to Base Rate Advances). If the Company fails to reimburse the applicable Issuer for the full amount of any drawing under any Letter of Credit on the date and by the time specified in the previous sentence (by the making of Base Rate Advances pursuant to this Section 2.16(f) or otherwise), then (a) the Company shall be deemed to have requested that Base Rate Advances in an amount equal to the unreimbursed amount be made by the Banks on such date (and the Administrative Agent shall promptly notify each Bank thereof); (b) subject to the conditions set forth in Section 4.02 (but without regard to the minimum and integral multiple requirements for borrowings set forth in Section 2.05), the Banks shall make such Advances on such date; and (c) the Administrative Agent shall deliver the proceeds of such Advances to the applicable Issuer to pay such unreimbursed amount. The Company shall be irrevocably and unconditionally obligated to reimburse each Issuer on or before the applicable Honor Date for any amount to be paid by such Issuer upon any drawing under any Letter of Credit, without presentment, demand, protest or other formalities of any kind; provided that the Company shall not be precluded from asserting any claim for direct (but not consequential) damages suffered by the Company to the extent, but only to the extent, caused by (i) the willful misconduct or gross negligence of such Issuer in determining whether a request presented under any Letter of Credit complied with the terms of such Letter of Credit or (ii) such Issuer’s failure to pay under any Letter of Credit after the presentation to it of a request strictly complying with the terms and conditions of such Letter of Credit. Each Issuer will pay to each Bank ratably in accordance with its Pro Rata Share all amounts received by it from the Company for application in payment, in whole or in part, of the Reimbursement Obligation in respect of any Letter of Credit issued by such Issuer, but only to the extent such Bank made payment to such Issuer in respect of such Letter of Credit pursuant to Section 2.16(e).

(g)    Obligations Absolute. The Company’s obligations under this Section 2.16 shall be absolute and unconditional under any and all circumstances and irrespective of any

28

709152408 03173762

setoff, counterclaim or defense to payment which the Company may have or have had against the applicable Issuer, any Bank or any beneficiary of a Letter of Credit. The Company further agrees with each Issuer and the Banks that no Issuer or Bank shall be responsible for, and the Company’s Reimbursement Obligation in respect of any Letter of Credit shall not be affected by, among other things, the validity or genuineness of documents or of any endorsements thereon, even if such documents should in fact prove to be in any or all respects invalid, fraudulent or forged, or any dispute between or among the Company, any of its Affiliates, the beneficiary of any Letter of Credit or any financing institution or other party to whom any Letter of Credit may be transferred or any claims or defenses whatsoever of the Company or of any of its Affiliates against the beneficiary of any Letter of Credit or any such transferee. No Issuer shall be liable for any error, omission, interruption or delay in transmission, dispatch or delivery of any message or advice, however transmitted, in connection with any Letter of Credit. The Company agrees that any action taken or omitted by the applicable Issuer or any Bank under or in connection with any Letter of Credit and the related drafts and documents, if done without gross negligence or willful misconduct, shall be binding upon the Company and shall not put such Issuer or any Bank under any liability to the Company. Nothing in this Section 2.16(g) is intended to limit the right of the Company to make a claim against the applicable Issuer for damages as contemplated by the proviso to the third sentence of Section 2.16(f).

(h)    Actions of Issuer. Each Issuer shall be entitled to rely, and shall be fully protected in relying, upon any Letter of Credit, draft, writing, resolution, notice, consent, certificate, affidavit, letter, telegram, facsimile, email, telex message, statement, order or other document believed by it to be genuine and correct and to have been signed, sent or made by the proper Person or Persons, and upon advice and statements of legal counsel, independent accountants and other experts selected by such Issuer. Each Issuer shall be fully justified in failing or refusing to take any action under this Agreement unless it shall first have received such advice or concurrence of the Majority Banks as it reasonably deems appropriate or it shall first be indemnified to its reasonable satisfaction by the Banks against any and all liability and expense which may be incurred by it by reason of taking or continuing to take any such action. Notwithstanding any other provision of this Section 2.16, each Issuer shall in all cases be fully protected in acting, or in refraining from acting, under this Agreement in accordance with a request of the Majority Banks, and such request and any action taken or failure to act pursuant thereto shall be binding upon the Banks and any future holder of a participation in any applicable Letter of Credit.

(i)    Indemnification. The Company agrees to indemnify and hold harmless each Bank, the applicable Issuer and the Administrative Agent, and their respective directors, officers, agents and employees, from and against any and all claims and damages, losses, liabilities, costs or expenses which such Bank, such Issuer or the Administrative Agent may incur (or which may be claimed against such Bank, such Issuer or the Administrative Agent by any Person whatsoever) by reason of or in connection with the issuance, execution and delivery or transfer of or payment or failure to pay under any Letter of Credit or any actual or proposed use of any Letter of Credit, including any claims, damages, losses, liabilities, costs or expenses which such Issuer may incur by reason of or in connection with (i) the failure of any other Bank to fulfill or comply with its obligations to such Issuer hereunder (but nothing herein contained shall affect any right the Company may have against any defaulting Bank) or (ii) by reason of or on account of such Issuer issuing any Letter of Credit which specifies that the term “Beneficiary” therein includes any successor by operation of law of the named Beneficiary, but which Letter of Credit does not require that any drawing by any such successor Beneficiary be accompanied by a

29

709152408 03173762

copy of a legal document, satisfactory to such Issuer, evidencing the appointment of such successor Beneficiary; provided that the Company shall not be required to indemnify any Bank, the applicable Issuer or the Administrative Agent for any claims, damages, losses, liabilities, costs or expenses to the extent, but only to the extent, caused by (x) the willful misconduct or gross negligence of such Issuer in determining whether a request presented under any Letter of Credit issued by such Issuer complied with the terms of such Letter of Credit or (y) such Issuer’s failure to pay under any Letter of Credit after the presentation to it of a request strictly complying with the terms and conditions of such Letter of Credit. Nothing in this Section 2.16(i) is intended to limit the obligations of the Company under any other provision of this Agreement.

(j)    Banks’ Indemnification. Each Bank shall, ratably in accordance with its Pro Rata Share, indemnify each applicable Issuer and its affiliates and their respective directors, officers, agents and employees (to the extent not reimbursed by the Company) against any cost, expense (including reasonable counsel fees and charges), claim, demand, action, loss or liability (except such as result from such indemnitees’ gross negligence or willful misconduct or such Issuer’s failure to pay under any Letter of Credit after the presentation to it of a request strictly complying with the terms and conditions of such Letter of Credit) that such indemnitees may suffer or incur in connection with this Section 2.16 or any action taken or omitted by such indemnitees hereunder.

(k)    LC Collateral Account. The Company agrees that it will establish on the Termination Date (or on such earlier date as may be required pursuant to Section 8.02), and thereafter maintain so long as any Letter of Credit is outstanding or any amount is payable to any Issuer or the Banks in respect of any Letter of Credit, a special collateral account pursuant to arrangements satisfactory to the Administrative Agent (the “LC Collateral Account”) at the Administrative Agent’s office at the address specified pursuant to Section 10.02, in the name of the Company but under the sole dominion and control of the Administrative Agent, for the benefit of the Banks, and in which the Company shall have no interest other than as set forth in Section 8.02. The Company shall cause to be maintained on deposit in the LC Collateral Account at all times on and after the Termination Date an amount equal to 105% of the Letter of Credit Obligations, and the Company hereby pledges, assigns and grants to the Administrative Agent, on behalf of and for the ratable benefit of the Banks and the Issuers, a security interest in all of the Company’s right, title and interest in and to all funds which may from time to time be on deposit in the LC Collateral Account, to secure the prompt and complete payment and performance of the Obligations. The Administrative Agent will invest any funds on deposit from time to time in the LC Collateral Account in certificates of deposit of U.S. Bank having a maturity not exceeding 30 days. At any time prior to the Termination Date, the Administrative Agent will, not later than three Business Days following the request of the Company and so long as no Default or Event of Default then exists, return to the Company funds that were deposited by the Company in the LC Collateral Account pursuant to this clause (k), together with any accrued interest thereon.

(l)    Rights as a Bank. In its capacity as a Bank, each Issuer shall have the same rights and obligations as any other Bank.

2.17    Additional Cash Collateral. Without limiting the obligations of the Company under Section 2.16(k), at any time that there shall exist a Defaulting Bank, within two (2) Business Days following the written request of the Administrative Agent or any Issuer (with a copy to the Administrative Agent), the Company shall Cash Collateralize the Issuers’ Fronting

30

709152408 03173762

Exposure with respect to such Defaulting Bank (determined after giving effect to Section 2.18(a)(iv) and any Cash Collateral provided by such Defaulting Bank) in an amount not less than the Minimum Collateral Amount.

(a)    Grant of Security Interest. The Company, and to the extent provided by any Defaulting Bank, such Defaulting Bank, hereby grants to the Administrative Agent, for the benefit of the Issuers, and agrees to maintain, a first priority security interest in all such Cash Collateral as security for the Defaulting Banks’ obligations to fund participations in respect of Letter of Credit Obligations, to be applied pursuant to clause (b) below. If at any time the Administrative Agent determines that Cash Collateral is subject to any right or claim of any Person other than the Administrative Agent and the Issuers as herein provided (other than Liens of the type described in Section 7.01(c) or (l)), or that the total amount of such Cash Collateral is less than the Minimum Collateral Amount, the Company will, promptly upon demand by the Administrative Agent, pay or provide to the Administrative Agent additional Cash Collateral in an amount sufficient to eliminate such deficiency (after giving effect to any Cash Collateral provided by the Defaulting Bank).

(b)    Application. Notwithstanding anything to the contrary contained in this Agreement, Cash Collateral provided under this Section 2.17 or Section 2.18 in respect of Letters of Credit shall be applied to the satisfaction of the Defaulting Banks’ obligations to fund participations in respect of Letter of Credit Obligations (including, as to Cash Collateral provided by a Defaulting Bank, any interest accrued on such obligation) for which the Cash Collateral was so provided, prior to any other application of such property as may otherwise be provided for herein.

(c)    Termination of Requirement. Cash Collateral (or the appropriate portion thereof) provided to reduce any Issuer’s Fronting Exposure shall no longer be required to be held as Cash Collateral pursuant to this Section 2.17, and shall be returned to the Person that provided such Cash Collateral not later than three Business Days after such Person’s request, in each case following (i) the elimination of the applicable Fronting Exposure (including by the termination of Defaulting Bank status of the applicable Bank in accordance with Section 2.18(b)), or (ii) the determination by the Administrative Agent and each Issuer that there exists excess Cash Collateral; provided that, subject to Section 2.18 (including any agreement pursuant thereto whereby a Defaulting Bank agrees to maintain Cash Collateral with the Administrative Agent as a condition to such Defaulting Bank ceasing to be deemed a Defaulting Bank), the Person providing Cash Collateral and each Issuer may agree that Cash Collateral shall be held to support future anticipated Fronting Exposure or other obligations (and, in the case of any such Cash Collateral that was provided by the Company and will be so held, such Cash Collateral shall remain subject to the security interest granted hereunder).

2.18    Defaulting Banks.

(a)    Defaulting Bank Adjustments. Notwithstanding anything to the contrary contained in this Agreement, if any Bank becomes a Defaulting Bank, then, until such time as such Bank is no longer a Defaulting Bank, to the extent permitted by applicable law:

(i)    Waivers and Amendments. Such Defaulting Bank’s right to approve or disapprove any amendment, waiver or consent with respect to this Agreement shall be restricted as set forth in the definition of Majority Banks.

31

709152408 03173762

(ii)    Defaulting Bank Waterfall. Any payment of principal, interest, fees or other amounts received by the Administrative Agent for the account of such Defaulting Bank (whether voluntary or mandatory, at maturity, pursuant to Article VIII or otherwise) or received by the Administrative Agent from a Defaulting Bank pursuant to Section 10.10 shall be applied at such time or times as may be determined by the Administrative Agent as follows: first, to the payment of any amounts owing by such Defaulting Bank to the Administrative Agent hereunder; second, to the payment on a pro rata basis of any amounts owing by such Defaulting Bank to any Issuer hereunder; third, to Cash Collateralize the Issuers’ Fronting Exposure with respect to such Defaulting Bank in accordance with Section 2.17; fourth, as the Company may request (so long as no Default or Event of Default exists), to the funding of any Advance in respect of which such Defaulting Bank has failed to fund its portion thereof as required by this Agreement, as determined by the Administrative Agent; fifth, if so determined by the Administrative Agent and the Company, to be held in a deposit account and released pro rata in order to (x) satisfy such Defaulting Bank’s potential future funding obligations with respect to Advances under this Agreement and (y) Cash Collateralize the Issuers’ future Fronting Exposure with respect to such Defaulting Bank with respect to future Letters of Credit issued under this Agreement, in accordance with Section 2.17; sixth, to the payment of any amounts owing to the Banks, the Issuers as a result of any judgment of a court of competent jurisdiction obtained by any Bank or the Issuers against such Defaulting Bank as a result of such Defaulting Bank’s breach of its obligations under this Agreement; seventh, so long as no Default or Event of Default exists, to the payment of any amounts owing to the Company as a result of any judgment of a court of competent jurisdiction obtained by the Company against such Defaulting Bank as a result of such Defaulting Bank's breach of its obligations under this Agreement; and eighth, to such Defaulting Bank or as otherwise directed by a court of competent jurisdiction; provided that if (x) such payment is a payment of the principal amount of any Advances or unpaid Reimbursement Obligations in respect of which such Defaulting Bank has not fully funded its appropriate share, and (y) such Advances were made or the related Letters of Credit were issued at a time when the conditions set forth in Section 4.02 were satisfied or waived, such payment shall be applied solely to pay the Advances of, and LC Disbursements owed to, all Non-Defaulting Banks on a pro rata basis prior to being applied to the payment of any Loans of, or LC Disbursements owed to, such Defaulting Bank until such time as all Advances and funded and unfunded participations in Letter of Credit Obligations are held by the Banks pro rata in accordance with the Commitments under the applicable Facility without giving effect to Section 2.18(a)(iv). Any payments, prepayments or other amounts paid or payable to a Defaulting Bank that are applied (or held) to pay amounts owed by a Defaulting Bank or to post Cash Collateral pursuant to this Section 2.18(a)(ii) shall be deemed paid to and redirected by such Defaulting Bank, and each Bank irrevocably consents hereto.

(iii)    Certain Fees. (A) Each Defaulting Bank shall be entitled to receive a facility fee for any period during which that Bank is a Defaulting Bank only to extent allocable to the sum of (1) the outstanding principal amount of the Loans funded by it, and (2) its Pro Rata Share of the stated amount of Letters of Credit for which it has provided Cash Collateral pursuant to Section 2.17.

(B)Each Defaulting Bank shall be entitled to receive Letter of Credit Fees for any period during which that Bank is a Defaulting Bank

32

709152408 03173762

only to the extent allocable to its Pro Rata Share of the stated amount of Letters of     Credit for which it has provided Cash Collateral pursuant to Section 2.17.

(C)With respect to any facility fee or Letter of Credit Fee not required to be paid to any Defaulting Bank pursuant to clause (A) or (B) above, the Company shall (x) pay to each Non-Defaulting Bank that portion of any such fee otherwise payable to such Defaulting Bank with respect to such Defaulting Bank’s participation in Letter of Credit Obligations that has been reallocated to such Non-Defaulting Bank pursuant to clause (iv) below, (y) pay to each Issuer, as applicable, the amount of any such fee otherwise payable to such Defaulting Bank to the extent allocable to such Issuer’s Fronting Exposure to such Defaulting Bank, and (z) not be required to pay the remaining amount of any such fee.

(iv)    Reallocation of Participations to Reduce Fronting Exposure. All or any part of such Defaulting Bank’s participation in Letter of Credit Obligations shall be reallocated among the Non-Defaulting Banks in accordance with their respective Pro Rata Shares (calculated without regard to such Defaulting Bank’s Commitment and Outstanding Credit Exposure) but only to the extent that (x) the conditions set forth in Section 4.02 are satisfied at the time of such reallocation (and, unless the Company shall have otherwise notified the Administrative Agent at such time, the Company shall be deemed to have represented and warranted that such conditions are satisfied at such time), and (y) such reallocation does not cause the Outstanding Credit Exposure of any Non-Defaulting Bank to exceed such Non-Defaulting Bank’s Commitment. No reallocation hereunder shall constitute a waiver or release of any claim of any party hereunder against a Defaulting Bank arising from that Bank having become a Defaulting Bank, including any claim of a Non-Defaulting Bank as a result of such Non-Defaulting Bank’s increased exposure following such reallocation.

(v)    Cash Collateral. If the reallocation described in clause (iv) above cannot, or can only partially, be effected, the Company shall, without prejudice to any right or remedy available to it hereunder or under law, Cash Collateralize the Issuers’ Fronting Exposure in accordance with the procedures set forth in Section 2.17.

(b)    Defaulting Bank Cure. If the Company, the Administrative Agent and each Issuer agree in writing that a Bank is no longer a Defaulting Bank, the Administrative Agent will so notify the parties hereto, whereupon as of the effective date specified in such notice and subject to any conditions agreed to by the Company, the Administrative Agent, each Issuer and such Bank set forth in such notice, such Bank will, to the extent applicable, purchase at par that portion of outstanding Loans of the other Banks or take such other actions as the Administrative Agent may determine to be necessary to cause the Loans and funded and unfunded participations in Letters of Credit to be held pro rata by the Banks in accordance with the Commitments under the applicable Facility (without giving effect to Section 2.18(a)(iv)) whereupon such Bank will cease to be a Defaulting Bank; provided that no adjustments will be made retroactively with respect to fees accrued or payments made by or on behalf of the Company while that Bank was a Defaulting Bank; and provided, further, that except to the extent otherwise expressly agreed by the affected parties, no change hereunder from Defaulting Bank to

33

709152408 03173762

Bank will constitute a waiver or release of any claim of any party hereunder arising from that Bank’s having been a Defaulting Bank.

(c)    New Letters of Credit. So long as any Bank is a Defaulting Bank, no Issuer shall be required to issue, extend, renew or increase any Letter of Credit unless it is satisfied that it will have no Fronting Exposure after giving effect thereto.

ARTICLE III

YIELD PROTECTION; TAXES

3.01    Increased Costs Generally. If, on or after the date of this Agreement, there occurs any adoption of or change in any law, governmental or quasi-governmental rule, regulation, policy, guideline, interpretation, or directive (whether or not having the force of law) or in the interpretation, promulgation, implementation or administration thereof by any governmental or quasi-governmental authority, central bank or comparable agency charged with the interpretation or administration thereof, including, notwithstanding the foregoing, all requests, rules, guidelines or directives (x) in connection with the Dodd-Frank Wall Street Reform and Consumer Protection Act or (y) promulgated by the Bank for International Settlements, the Basel Committee on Banking Regulations and Supervisory Practices (or any successor or similar authority) or the United States financial regulatory authorities, in each case of clauses (x) and (y), regardless of the date enacted, adopted, issued, promulgated or implemented, or compliance by any Bank or applicable Lending Installation or any Issuer with any request or directive (whether or not having the force of law) of any such authority, central bank or comparable agency (any of the foregoing, a “Change in Law”) which:

(a)    subjects any Recipient to any Taxes (other than (A) Indemnified Taxes, (B) Taxes described in clauses (b) through (d) of the definition of Excluded Taxes and (C) Connection Income Taxes) on its loans, loan principal, letters of credit, commitments, or other obligations, or its deposits, reserves, other liabilities or capital attributable thereto, or

(b)    imposes or increases or deems applicable any reserve, assessment, insurance charge, special deposit or similar requirement against assets of, deposits with or for the account of, or credit extended by, any Bank or any applicable Lending Installation or any Issuer (other than reserves and assessments taken into account in determining the Eurodollar Rate), or

(c)    imposes any other condition (other than Taxes) the result of which is to increase the cost to any Bank or any applicable Lending Installation or any Issuer of funding or maintaining its Eurodollar Loans, or of issuing or participating in Letters of Credit, or reduces any amount receivable by any Bank or any applicable Lending Installation or any Issuer in connection with its Eurodollar Loans, Letters of Credit or participations therein, or requires any Bank or any applicable Lending Installation or any Issuer to make any payment calculated by reference to the amount of Eurodollar Loans, Letters of Credit or participations therein held or interest or Letter of Credit Fees received by it, by an amount deemed material by such Bank or such Issuer as the case may be,

and the result of any of the foregoing is to increase the cost to such Person of making or maintaining its Loans or Commitment or of issuing or participating in Letters of Credit or to reduce the return received by such Person in connection with such Loans or Commitment, Letters of Credit or participations therein, then, within 15 days after demand by such Person, the

34

709152408 03173762

Company shall pay such Person, as the case may be, such additional amount or amounts as will compensate such Person for such increased cost or reduction in amount received.

3.02    Changes in Capital Adequacy Regulations. If any Bank or Issuer determines that any Change in Law affecting such Bank or Issuer or any lending office of such Bank or such Bank’s or Issuer’s holding company, if any, regarding capital or liquidity requirements, has or would have the effect of reducing the rate of return on such Bank’s or Issuer’s capital or on the capital of such Bank’s or Issuer’s holding company, if any, as a consequence of this Agreement, the Commitment of such Bank or the Loans made by, or participations in Letters of Credit held by, such Bank, or the Letters of Credit issued by any Issuer, to a level below that which such Bank or Issuer or such Bank’s or Issuer’s holding company could have achieved but for such Change in Law (taking into consideration such Bank’s or Issuer’s policies and the policies of such Bank’s or Issuer’s holding company with respect to capital adequacy), then from time to time the Company will pay to such Bank or Issuer, as the case may be, such additional amount or amounts as will compensate such Bank or Issuer or such Bank’s or Issuer’s holding company for any such reduction suffered.

3.03    Certificates for Reimbursement; Delay in Requests.

(a)    A certificate of a Bank or Issuer setting forth the amount or amounts necessary to compensate such Bank or Issuer or its holding company, as the case may be, as specified in Section 3.01 or 3.02 and delivered to the Company, shall be conclusive absent manifest error. The Company shall pay such Bank or Issuer, as the case may be, the amount shown as due on any such certificate within 15 days after receipt thereof.

(b)    Failure or delay on the part of any Bank or Issuer to demand compensation pursuant to this Section shall not constitute a waiver of such Bank’s or Issuer’s right to demand such compensation; provided that the Company shall not be required to compensate a Bank or Issuer pursuant to this Section for any increased costs incurred or reductions suffered more than 180 days prior to the date that such Bank or Issuer, as the case may be, notifies the Company of the Change in Law giving rise to such increased costs or reductions, and of such Bank’s or Issuer’s intention to claim compensation therefor (except that, if the Change in Law giving rise to such increased costs or reductions is retroactive, then the 180 day period referred to above shall be extended to include the period of retroactive effect thereof).

3.04    Availability of Types of Advances. If (a) any Bank determines that the making, maintaining or funding of its Eurodollar Loans at a suitable Lending Installation would violate any applicable law, rule, regulation, or directive, whether or not having the force of law, or (b) if the Majority Banks determine that (i) deposits of a type and maturity appropriate to match fund Eurodollar Advances are not available or (ii) the interest rate applicable to Eurodollar Advances does not accurately reflect the cost of making or maintaining Eurodollar Advances, then the Administrative Agent shall suspend the availability of Eurodollar Advances and, in the case of clause (a) only, require any affected Eurodollar Advances to be repaid or converted to Base Rate Advances, subject to the payment of any funding indemnification amounts required by Section 3.05.

3.05    Funding Indemnification. If (a) any payment of a Eurodollar Advance occurs on a date which is not the last day of the applicable Interest Period, whether because of acceleration, prepayment or otherwise, (b) a Eurodollar Advance is not made on the date

35

709152408 03173762

specified by the Company for any reason other than default by the Banks, (c) a Eurodollar Loan is converted other than on the last day of the Interest Period applicable thereto, (d) the Company fails to borrow, convert, continue or prepay any Eurodollar Loan on the date specified in any notice delivered pursuant hereto or (e) any Eurodollar Loan is assigned other than on the last day of the Interest Period applicable thereto as a result of a request by the Company pursuant to Section 2.15, the Company will indemnify each Bank for any costs, expenses and Interest Differential (as determined by such Bank) incurred as a result thereof.  The term “Interest Differential” shall mean that sum equal to the greater of zero or the financial loss incurred by the applicable Bank resulting from any action described in clauses (a) through (e) above, calculated as the difference between the amount of interest such Bank would have earned (from the investments in money markets as of the Borrowing Date of such Loan) had such action not occurred and the interest such Bank will actually earn (from like investments in money markets as of the date of prepayment) as a result of the redeployment of such funds.  Because of the short-term nature of this facility, the Company agrees that Interest Differential shall not be discounted to its present value.

3.06    Taxes.

(a)    Issuer. For purposes of this Section 3.06, the term “Bank” includes any Issuer.

(b)    Payments Free of Taxes. Any and all payments by or on account of any obligation of the Company under any Loan Document shall be made without deduction or withholding for any Taxes, except as required by applicable law. If any applicable law (as determined in the good faith discretion of an applicable Withholding Agent) requires the deduction or withholding of any Tax from any such payment by a Withholding Agent, then the applicable Withholding Agent shall be entitled to make such deduction or withholding and shall timely pay the full amount deducted or withheld to the relevant Governmental Authority in accordance with applicable law and, if such Tax is an Indemnified Tax, then the sum payable by the Company shall be increased as necessary so that after such deduction or withholding has been made (including such deductions and withholdings applicable to additional sums payable under this Section) the applicable Recipient receives an amount equal to the sum it would have received had no such deduction or withholding been made.

(c)    Payment of Other Taxes by the Company. The Company shall timely pay to the relevant Governmental Authority in accordance with applicable law, or at the option of the Administrative Agent timely reimburse it for the payment of, any Other Taxes.

(d)    Indemnification by the Company. The Company shall indemnify each Recipient, within 10 days after demand therefor, for the full amount of any Indemnified Taxes (including Indemnified Taxes imposed or asserted on or attributable to amounts payable under this Section) payable or paid by such Recipient or required to be withheld or deducted from a payment to such Recipient and any reasonable expenses arising therefrom or with respect thereto, whether or not such Indemnified Taxes were correctly or legally imposed or asserted by the relevant Governmental Authority. A certificate as to the amount of such payment or liability delivered to the Company by a Bank (with a copy to the Administrative Agent), or by the Administrative Agent on its own behalf or on behalf of a Bank, shall be conclusive absent manifest error.

36

709152408 03173762

(e)Indemnification by the Banks. Each Bank shall severally indemnify the Administrative Agent, within 10 days after demand therefor, for (i) any Indemnified Taxes attributable to such Bank (but only to the extent that the Company has not already indemnified the Administrative Agent for such Indemnified Taxes and without limiting the obligation of the Company to do so) and (ii) any Excluded Taxes attributable to such Bank, in each case, that are payable or paid by the Administrative Agent in connection with any Loan Document, and any reasonable expenses arising therefrom or with respect thereto, whether or not such Taxes were correctly or legally imposed or asserted by the relevant Governmental Authority. A certificate as to the amount of such payment or liability delivered to any Bank by the Administrative Agent shall be conclusive absent manifest error. Each Bank hereby authorizes the Administrative Agent to set off and apply any and all amounts at any time owing to such Bank under any Loan Document or otherwise payable by the Administrative Agent to such Bank from any other source against any amount due to the Administrative Agent under this clause (e).

(f)Evidence of Payments. As soon as practicable after any payment of Taxes by the Company to a Governmental Authority pursuant to this Section 3.06, the Company shall deliver to the Administrative Agent the original or a certified copy of a receipt issued by such Governmental Authority evidencing such payment, a copy of the return reporting such payment or other evidence of such payment reasonably satisfactory to the Administrative Agent.

(g)Status of Banks.

(i)Any Bank that is entitled to an exemption from or reduction of withholding Tax with respect to payments made under any Loan Document shall deliver to the Company and the Administrative Agent, at the time or times reasonably requested by the Company or the Administrative Agent, such properly completed and executed documentation reasonably requested by the Company or the Administrative Agent as will permit such payments to be made without withholding or at a reduced rate of withholding. In addition, any Bank, if reasonably requested by the Company or the Administrative Agent, shall deliver such other documentation prescribed by applicable law or reasonably requested by the Company or the Administrative Agent as will enable the Company or the Administrative Agent to determine whether or not such Bank is subject to backup withholding or information reporting requirements. Notwithstanding anything to the contrary in the preceding two sentences, the completion, execution and submission of such documentation (other than such documentation set forth in Section 3.06(g)(ii)(A), (ii)(B) and (ii)(D) below) shall not be required if in the applicable Bank’s reasonable judgment such completion, execution or submission would subject such Bank to any material unreimbursed cost or expense or would materially prejudice the legal or commercial position of such Bank.

(ii)Without limiting the generality of the foregoing,

(A)any Bank that is a U.S. Person shall deliver to the Company and the Administrative Agent on or prior to the date on which such Bank becomes a Bank under this Agreement (and from time to time thereafter upon the reasonable request of the Company or the Administrative Agent), executed originals of IRS Form W-9 certifying that such Bank is exempt from U.S. federal backup withholding tax;

37

709152408 03173762

(B)any Foreign Bank shall, to the extent it is legally entitled to do so, deliver to the Company and the Administrative Agent (in such number of copies as shall be requested by the recipient) on or prior to the date on which such Foreign Bank becomes a Bank under this Agreement (and from time to time thereafter upon the reasonable request of the Company or the Administrative Agent), whichever of the following is applicable:

(1)in the case of a Foreign Bank claiming the benefits of an income tax treaty to which the United States is a party (x) with respect to payments of interest under any Loan Document, executed originals of IRS Form W-8BEN establishing an exemption from, or reduction of, U.S. federal withholding Tax pursuant to the “interest” article of such tax treaty and (y) with respect to any other applicable payments under any Loan Document, IRS Form W-8BEN establishing an exemption from, or reduction of, U.S. federal withholding Tax pursuant to the “business profits” or “other income” article of such tax treaty;

(2)executed originals of IRS Form W-8ECI;

(3)in the case of a Foreign Bank claiming the benefits of the exemption for portfolio interest under Section 881(c) of the Code, (x) a certificate substantially in the form of Exhibit E-1 to the effect that such Foreign Bank is not a “bank” within the meaning of Section 881(c)(3)(A) of the Code, a “10 percent shareholder” of the Company within the meaning of Section 871(h)(3)(B) of the Code, or a “controlled foreign corporation” described in Section 881(c)(3)(C) of the Code (a “U.S. Tax Compliance Certificate”) and (y) executed originals of IRS Form W-8BEN; or

(4)to the extent a Foreign Bank is not the beneficial owner, executed originals of IRS Form W-8IMY, accompanied by IRS Form W-8ECI, IRS Form W-8BEN, a U.S. Tax Compliance Certificate substantially in the form of Exhibit E-2 or Exhibit E-3, IRS Form W-9, and/or other certification documents from each beneficial owner, as applicable; provided that if the Foreign Bank is a partnership and one or more direct or indirect partners of such Foreign Bank are claiming the portfolio interest exemption, such Foreign Bank may provide a U.S. Tax Compliance Certificate substantially in the form of Exhibit E-4 on behalf of each such direct and indirect partner;

(C)any Foreign Bank shall, to the extent it is legally entitled to do so, deliver to the Company and the Administrative Agent (in such number of copies as shall be requested by the recipient) on or prior to the date on which such Foreign Bank becomes a Bank under this Agreement (and from time to time thereafter upon the reasonable request of the Company or the Administrative Agent), executed originals of any other form prescribed by applicable law as a basis for claiming exemption from or a reduction in U.S. federal withholding Tax, duly completed, together with such supplementary documentation as may be prescribed by applicable law to permit the Company or the Administrative Agent to determine the withholding or deduction required to be made; and

(D)if a payment made to a Bank under any Loan Document would be subject to U.S. federal withholding Tax imposed by FATCA if such Bank were to fail to comply with the applicable reporting requirements of FATCA (including those contained

38

709152408 03173762

in Section 1471(b) or 1472(b) of the Code, as applicable), such Bank shall deliver to the Company and the Administrative Agent at the time or times prescribed by law and at such time or times reasonably requested by the Company or the Administrative Agent such documentation prescribed by applicable law (including as prescribed by Section 1471(b)(3)(C)(i) of the Code) and such additional documentation reasonably requested by the Company or the Administrative Agent as may be necessary for the Company and the Administrative Agent to comply with their obligations under FATCA and to determine that such Bank has complied with such Bank’s obligations under FATCA or to determine the amount to deduct and withhold from such payment. Solely for purposes of this clause (D), “FATCA” shall include any amendments made to FATCA after the date of this Agreement.

Each Bank agrees that if any form or certification it previously delivered expires or becomes obsolete or inaccurate in any respect, it shall update such form or certification or promptly notify the Company and the Administrative Agent in writing of its legal inability to do so.

(h)Treatment of Certain Refunds. If any party determines, in its sole discretion exercised in good faith, that it has received a refund of any Taxes as to which it has been indemnified pursuant to this Section 3.06 (including by the payment of additional amounts pursuant to this Section 3.06), it shall pay to the indemnifying party an amount equal to such refund (but only to the extent of indemnity payments made under this Section with respect to the Taxes giving rise to such refund), net of all out-of-pocket expenses (including Taxes) of such indemnified party and without interest (other than any interest paid by the relevant Governmental Authority with respect to such refund). Such indemnifying party, upon the request of such indemnified party, shall repay to such indemnified party the amount paid over pursuant to this clause (h) (plus any penalties, interest or other charges imposed by the relevant Governmental Authority) in the event that such indemnified party is required to repay such refund to such Governmental Authority. Notwithstanding anything to the contrary in this clause (h), in no event will the indemnified party be required to pay any amount to an indemnifying party pursuant to this clause (h) the payment of which would place the indemnified party in a less favorable net after-Tax position than the indemnified party would have been in if the indemnification payments or additional amounts giving rise to such refund had never been paid. This clause shall not be construed to require any indemnified party to make available its Tax returns (or any other information relating to its Taxes that it deems confidential) to the indemnifying party or any other Person.

3.07    Mitigation Obligations; Replacement of Banks.

(a)    Mitigation Obligations. If any Bank requests compensation under Section 3.01 or 3.02, or requires the Company to pay any Indemnified Taxes or additional amounts to any Bank or any Governmental Authority for the account of any Bank pursuant to Section 3.06, then such Bank shall use reasonable efforts to designate a different lending office for funding or booking its Loans hereunder or to assign its rights and obligations hereunder to another of its offices, branches or affiliates, if, in the judgment of such Bank, such designation or assignment (i) would eliminate or reduce amounts payable pursuant to Section 3.01, 3.02 or 3.06, as the case may be, in the future, and (ii) would not subject such Bank to any unreimbursed cost or expense and would not otherwise be disadvantageous to such Bank. The Company hereby

39

709152408 03173762

agrees to pay all reasonable costs and expenses incurred by any Bank in connection with any such designation or assignment.

(b)    Replacement of Banks. If any Bank requests compensation under Section 3.01 or 3.02, or requires the Company to pay any Indemnified Taxes or additional amounts to any Bank or any Governmental Authority for the account of any Bank pursuant to Section 3.06, and, in each case, such Bank has declined or is unable to designate a different lending office in accordance with Section 3.07(a) (each such Bank, an “Increased Cost Bank”), or if any Bank is a Defaulting Bank or a Non-Consenting Bank, then the Company may, at its sole expense and effort, upon notice to such Bank and the Administrative Agent, require such Bank to assign and delegate, without recourse (in accordance with and subject to the restrictions contained in, and consents required by, Section 10.08), all of its interests, rights (other than its existing rights to payments pursuant to Section 3.01, 3.02 or 3.06) and obligations under this Agreement and the related Loan Documents to an Eligible Assignee that shall assume such obligations (which assignee may be another Bank, if a Bank accepts such assignment); provided that:

(A)the Company shall have paid to the Administrative Agent the assignment fee (if any) specified in Section 10.08;

(B)such Bank shall have received payment of an amount equal to the outstanding principal of its Loans and participations in LC Disbursements, accrued interest thereon, accrued fees and all other amounts payable to it hereunder and under the other Loan Documents (including any amounts under Section 3.05) from the assignee (to the extent of such outstanding principal and accrued interest and fees) or the Company (in the case of all other amounts);

(C)in the case of any such assignment resulting from a claim for compensation under Section 3.01 or 3.02, such assignment will result in a reduction in such compensation or payments thereafter;

(D)such assignment does not conflict with applicable law; and

(E)in the case of any assignment resulting from a Bank becoming a Non-Consenting Bank, the applicable assignee shall have consented to the applicable amendment, waiver or consent.

(c)    A Bank shall not be required to make any such assignment or delegation if, prior thereto, as a result of a waiver by such Bank or otherwise, the circumstances entitling the Company to require such assignment and delegation cease to apply. Each Bank and Issuer hereby grants to the Administrative Agent an irrevocable power of attorney (which power is coupled with an interest) to execute and deliver, on behalf of such Bank or Issuer, as the case may be, as assignor, any Assignment Agreement necessary to effect any assignment of such Bank’s or Issuer’s interests hereunder in the circumstances contemplated by this Section 3.07. Each Bank agrees that if the Company exercises its option hereunder to cause an assignment by such Bank as an Increased Cost Bank, Non-Consenting Bank or Defaulting Bank, such Bank shall, promptly after receipt of written notice of such election, execute and deliver all documentation necessary to effect such assignment in accordance with Section 3.07. In the event that a Bank does not comply with the requirements of the immediately preceding sentence within one Business Day after receipt of such notice, each Bank hereby authorizes and directs the

40

709152408 03173762

Administrative Agent to execute and deliver such documentation as may be required to give effect to an assignment in accordance with Section 10.08 on behalf of an Increased Cost Bank, Non-Consenting Bank or Defaulting Bank and any such documentation so executed by the Administrative Agent shall be effective for purposes of documenting an assignment pursuant to Section 10.08.

ARTICLE IV

CONDITIONS PRECEDENT

4.01    Initial Credit Extension. The obligation of the Banks and the Issuers to make the initial Credit Extension is subject to the following conditions precedent (unless all of the Banks, in their sole and absolute discretion, shall agree otherwise):

(a)    The Administrative Agent shall have received all of the following, each of which shall be originals unless otherwise specified, each properly executed by a Responsible Officer, each dated as of the date of this Agreement and each in form and substance satisfactory to the Administrative Agent and the Banks (unless otherwise specified or, in the case of the date of any of the following, unless the Administrative Agent otherwise agrees or directs):

(1)one executed counterpart of this Agreement, together with arrangements satisfactory to Administrative Agent for additional executed counterparts, sufficient in number for distribution to the Banks and the Company;

(2)a Note executed by the Company in favor of each Bank requesting a Note;

(3)copies of the resolutions of the Board of Directors or the executive committee of the Company approving and authorizing the execution, delivery and performance by the Company of the Loan Documents to which it is a party, certified as of the date of this Agreement by the Secretary or an Assistant Secretary of the Company;

(4)a certificate of the Secretary or Assistant Secretary of the Company, certifying the names, titles and true signatures of the Responsible Officers and any other officers of the Company authorized to execute and deliver the Loan Documents to which it is a party, upon which certificate the Administrative Agent, the Issuers and the Banks shall be entitled to rely until informed of any change in writing by the Company;

(5)copies of the articles or certificate of incorporation of the Company as in effect on the date of this Agreement and the bylaws of the Company as in effect on the date of this Agreement, certified by the Secretary or Assistant Secretary of the Company as of the date of this Agreement;

(6)a good standing certificate for the Company from the Secretary of State of the State of Delaware;

(7)the Opinions of Counsel;

(8)a certificate signed by a Responsible Officer certifying that the conditions specified in Sections 4.01(c), 4.01(d) and 4.01(f) have been satisfied;

41

709152408 03173762

(9)written money transfer instructions, in substantially the form of Exhibit D, addressed to the Administrative Agent and signed by a Responsible Officer, together with such other related money transfer authorizations as the Administrative Agent may have reasonably requested;

(10)if the initial Credit Extension will be the issuance of a Letter of Credit, a properly completed Letter of Credit Application; and

(11)such other assurances, certificates, documents, consents or opinions as the Administrative Agent reasonably may require.

(b)    Attorney Costs of the Co-Lead Arrangers to the extent invoiced prior to or on the Execution Date, plus such additional amounts of Attorney Costs as shall constitute the reasonable estimate of Attorney Costs incurred or to be incurred by the Co-Lead Arrangers through the closing proceedings (provided that such estimate shall not thereafter preclude final settling of accounts between the Company and the Co-Lead Arrangers) shall have been paid.

(c)    The representations and warranties of the Company contained in Article V shall be true and correct in all material respects.

(d)    The Company shall be in compliance with all the terms and provisions of the Loan Documents, and, after giving effect to the initial Advance, no Default or Event of Default shall exist.

(e)    The Company shall have paid to the Administrative Agent for the account of the Banks such upfront fees as have been agreed to by the Company, the Administrative Agent and the Co-Lead Arrangers pursuant to the Fee Letters.

(f)    There shall have occurred since December 31, 2013 no event or circumstance that has resulted or could reasonably be expected to result in a Material Adverse Effect.

4.02    Each Credit Extension. The obligation of the Banks and the Issuers to make any Credit Extension (including the initial Credit Extension) is subject to the following conditions precedent:

(a)    the representations and warranties of the Company contained in Article V (except (i) in the case of a conversion or continuation pursuant to Section 2.02(d), the representations set forth in Sections 5.05, 5.11(b) and 5.12 and in the second and third sentences of Section 5.14 and (ii) in the case of a Loan the proceeds of which will be used to pay maturing commercial paper of the Company, the representations set forth in Sections 5.05(b) and 5.11(b)) are true and correct in all material respects as though made on and as of the date of such Credit Extension (except to the extent such representations and warranties expressly refer to an earlier date, in which case they are true and correct as of such earlier date);

(b)    no Default or Event of Default exists or would result from such Credit Extension; and

(c)    the Administrative Agent shall have received, in form and substance satisfactory to the Administrative Agent, such other assurances, certificates, documents or

42

709152408 03173762

consents related to the foregoing as the Administrative Agent or Majority Banks reasonably may require.

On the date of each Credit Extension, the Company shall be deemed to have represented and warranted that the representations and warranties contained in Article V (except (x) in the case of a conversion or continuation pursuant to Section 2.02(d), the representations set forth in Sections 5.05, 5.11(b) and 5.12 and in the second and third sentences of Section 5.14 and (y) in the case of a Loan the proceeds of which will be used to pay maturing commercial paper of the Company, the representations set forth in Sections 5.05(b) and 5.11(b)) are true and correct in all material respects as though made on and as of the date of such Credit Extension (except to the extent such representations and warranties expressly refer to an earlier date, in which case they are true and correct as of such earlier date).

ARTICLE V

REPRESENTATIONS AND WARRANTIES

The Company represents and warrants to the Administrative Agent, each Issuer and each Bank that:

5.01    Existence and Power; Standing; Compliance With Laws. The Company and each of its Subsidiaries: (a) is duly organized, validly existing and in good standing under the laws of the jurisdiction of its organization; (b) has the power and authority and all governmental licenses, authorizations, consents and approvals to (i) own its assets and carry on its business and (ii) with respect to the Company, to execute, deliver, and perform its obligations under the Loan Documents; (c) is duly qualified as a foreign corporation and is licensed and in good standing under the laws of each jurisdiction where its ownership, lease or operation of property or the conduct of its business requires such qualification or license; and (d) is in compliance with all Requirements of Law; except, in each case referred to in clauses (a) (other than with respect to the Company), (b)(i), (c) and (d), to the extent that the failure to do so could not reasonably be expected to have a Material Adverse Effect.

5.02    Corporate Authorization; No Contravention or Conflict. The execution, delivery and performance by the Company of this Agreement and each other Loan Document to which the Company is a party, have been duly authorized by all necessary corporate action, and do not and will not: (a) contravene the terms of any of the Company’s Organization Documents; (b) conflict with or result in any breach or contravention of, or the creation of any Lien (other than any Lien created under any Loan Document) under, any document evidencing any Contractual Obligation to which the Company is a party or any order, injunction, writ or decree of any Governmental Authority to which the Company or its property is subject; or (c) violate any Requirement of Law.

5.03    Governmental Authorization. No approval, consent, exemption, authorization, or other action by, or notice to, or filing with, any Governmental Authority is necessary or required in connection with the execution, delivery or performance by, or enforcement against, the Company of the Agreement or any other Loan Document.

5.04    Validity and Binding Effect. This Agreement and each other Loan Document to which the Company is a party constitute the legal, valid and binding obligations of the Company, enforceable against the Company in accordance with their respective terms, except as

43

709152408 03173762

enforceability may be limited by applicable bankruptcy, insolvency, or similar laws affecting the enforcement of creditors’ rights generally or by equitable principles relating to enforceability.

5.05    Litigation; Environmental Claims. Except as set forth in the Company’s financial statements dated December 31, 2013, there are, as of the Execution Date, no actions, suits, proceedings, claims (including Environmental Claims) or disputes pending, or, to the knowledge of the Company, threatened, at law, in equity, in arbitration or by or before any Governmental Authority, against the Company, or its Subsidiaries or any of their respective properties which: (a) purport to affect or pertain to this Agreement or any other Loan Document, or any of the transactions contemplated hereby or thereby; or (b) if determined adversely to the Company or its Subsidiaries, would reasonably be expected to have a Material Adverse Effect. No injunction, writ, temporary restraining order or any order of any nature has been issued by any court or other Governmental Authority purporting to enjoin or restrain the execution, delivery or performance of this Agreement or any other Loan Document, or directing that the transactions provided for herein or therein not be consummated as herein or therein provided.

5.06    No Default. No Default or Event of Default exists or would result from the incurring of any Obligations by the Company. As of the Execution Date, neither the Company nor any Subsidiary is in default under or with respect to any Contractual Obligation in any respect which, individually or together with all such defaults, could reasonably be expected to have a Material Adverse Effect, or that would, if such default had occurred after the Execution Date, create an Event of Default under Section 8.01(e).

5.07    ERISA Compliance. Each of the Company and its ERISA Affiliates is in compliance in all material respects with the applicable provisions of ERISA and the Code and published interpretations thereunder, except for any such failure that, individually or in the aggregate, could not reasonably be expected to result in a Material Adverse Effect. No ERISA Event has occurred or is reasonably expected to occur that, when taken together with all other such ERISA Events for which liability is reasonably expected to occur, could reasonably be expected to result in a Material Adverse Effect.

5.08    Use of Proceeds; Margin Regulations. The proceeds of the Loans are to be used solely for the purposes set forth in and permitted by Section 6.11 and Section 7.06. Neither the Company nor any Subsidiary is generally engaged in the business of purchasing or selling Margin Stock or extending credit for the purpose of purchasing or carrying Margin Stock. Margin Stock constitutes less than 25% of the value of those assets of the Company and its Subsidiaries which are subject to any limitation on sale, pledge or other restriction hereunder.

5.09    Title to Properties. To the Company’s knowledge, without having undertaken any search of real property records for this purpose, the Company and each Subsidiary have good and sufficient title to, or valid leasehold interests in, all real property necessary or used in the ordinary conduct of their respective businesses, and good title to all other property and assets reflected in the Company’s most recent consolidated financial statements provided to the Banks as owned by the Company and its Subsidiaries, except for such defects in title as could not, individually or in the aggregate, reasonably be expected to have a Material Adverse Effect. As of the Execution Date, the property of the Company and its Subsidiaries is subject to no Liens, other than Permitted Liens.

44

709152408 03173762

5.10    Taxes. The Company and its Subsidiaries have filed all federal and other tax returns and reports required to be filed, and have paid all federal and other taxes, assessments, fees and other governmental charges levied or imposed upon them or their properties, income or assets otherwise due and payable, except those which are being contested in good faith by appropriate proceedings and for which adequate reserves have been provided in accordance with GAAP and except those the failure to file or pay which would not have a Material Adverse Effect. There is no proposed tax assessment against the Company or any Subsidiary that would, if made, have a Material Adverse Effect.

5.11    Financial Condition. (a) The audited consolidated and consolidating financial statements of the Company and its Subsidiaries dated December 31, 2013, and the related consolidated and consolidating statements of income or operations, shareholders’ equity and cash flows for the fiscal periods ended on such dates:

(i)    were prepared in accordance with GAAP consistently applied throughout the

periods covered thereby, except as otherwise expressly noted therein (and subject, in the case of unaudited statements, to the absence of footnotes and to normal year-end adjustments);

(ii)    fairly present the financial condition of the Company and its Subsidiaries as of the dates thereof and results of operations for the periods covered thereby; and

(iii)    show all material indebtedness and other liabilities, direct or contingent, of the Company and its Subsidiaries as of the dates thereof, including liabilities for taxes, material commitments and Contingent Obligations.

(b)    Since December 31, 2013, there has been no Material Adverse Effect.

5.12    Environmental Matters. The Company conducts in the ordinary course of business a review of the effect of existing Environmental Laws and existing Environmental Claims on its business, operations and properties, and as a result thereof the Company has reasonably concluded that such Environmental Laws and Environmental Claims could not, individually or in the aggregate, reasonably be expected to have a Material Adverse Effect.

5.13    Regulated Entities. None of the Company, any Person controlling the Company, or any Subsidiary, is required to register as an “Investment Company” within the meaning of the Investment Company Act of 1940. The Company is not subject to regulation under the Federal Power Act, the Interstate Commerce Act, any state public utilities code, or any other Federal or state statute or regulation limiting its ability to incur Indebtedness.

5.14    Copyrights, Patents, Trademarks and Licenses, etc. The Company or its Subsidiaries own or are licensed or otherwise have the right to use all of the patents, trademarks, service marks, trade names, copyrights, contractual franchises, authorizations and other rights that are reasonably necessary for the operation of their respective businesses, without conflict with the rights of any other Person, except to the extent that noncompliance would not have a Material Adverse Effect. To the knowledge of the Company, no slogan or other advertising device, product, process, method, substance, part or other material now employed, or now contemplated to be employed, by the Company or any Subsidiary infringes upon any rights held by any other Person, except to the extent that noncompliance would not have a Material Adverse

45

709152408 03173762

Effect. No claim or litigation regarding any of the foregoing is pending or threatened, and no patent, invention, device, application, principle or any statute, law, rule, regulation, standard or code is pending or, to the knowledge of the Company, proposed, which, in either case, could reasonably be expected to have a Material Adverse Effect.

5.15    Subsidiaries. As of the Execution Date, the Company has no Subsidiaries other than those specifically disclosed in part (I) of Schedule 5.15 and has no equity investments in any other corporation or entity other than those specifically disclosed in part (II) of Schedule 5.15.

5.16    Insurance. The properties of the Company and its Subsidiaries are insured with financially sound and reputable insurance companies not Affiliates of the Company, in such amounts, with such deductibles and covering such risks as are customarily carried by companies engaged in similar businesses and owning similar properties in localities where the Company or such Subsidiary operates, except to the extent that noncompliance would not have a Material Adverse Effect.

5.17    Solvency. The Company is Solvent, and the Company and its Subsidiaries, taken as a whole, are Solvent.

5.18    Full Disclosure. None of the representations or warranties made by the Company or any Subsidiary in the Loan Documents as of the date such representations and warranties are made or deemed made, and none of the statements contained in any exhibit, report, statement or certificate furnished by or on behalf of the Company or any Subsidiary in connection with the Loan Documents contains any untrue statement of a material fact or omits any material fact required to be stated therein or necessary to make the statements made therein, in light of the circumstances under which they are made, not misleading as of the time when made or delivered. It is understood that any financial projections contained in any of the aforementioned materials represent projections based on various assumptions that the Company believes in good faith are reasonable in light of the circumstances and that any such projection of future results of operations may or may not occur and no assurance can be given that any such projected results will be achieved.

5.19    Senior Debt. The Obligations will be at least pari passu with all other senior unsecured debt of the Company.

5.20    OFAC; Anti-Terrorism Laws.

(a)    Neither the Company nor any Subsidiary (i) is a Sanctioned Person, (ii) has assets in Sanctioned Countries, or (iii) derives any operating income from investments in, or transactions with, Sanctioned Persons or Sanctioned Countries.  No part of the proceeds of any Loan hereunder will be used directly or, to the Company’s knowledge indirectly to fund any operations in, finance any investments or activities in or make any payments to a Sanctioned Person or a Sanctioned Country.

(b)    Neither the making of the Credit Extensions hereunder nor the use of the proceeds thereof will violate the PATRIOT Act, the Trading with the Enemy Act, or any of the foreign assets control regulations of the United States Treasury Department (31 C.F.R., Subtitle B, Chapter V) or any enabling legislation or executive order relating thereto or successor statute

46

709152408 03173762

thereto.  The Company and its Subsidiaries are in compliance in all material respects with the PATRIOT Act.

ARTICLE VI

AFFIRMATIVE COVENANTS

So long as any Bank has any Commitment hereunder, any Letter of Credit remains outstanding or any Loan or other Obligation remains unpaid or unsatisfied, unless the Majority Banks waive compliance in writing:

6.01    Financial Statements. The Company shall deliver to the Administrative Agent, in form and detail satisfactory to the Administrative Agent and the Majority Banks, with sufficient copies for each Bank (to be promptly forwarded by the Administrative Agent to each of the Banks upon receipt thereof):

(a)    as soon as available, but in no event later than 120 days after the end of each fiscal year (commencing with the fiscal year ending December 31, 2014), copies of the audited consolidated balance sheet of the Company and its Subsidiaries as at the end of such year and the related consolidated statements of income of operations, shareholders’ equity and cash flows for such year, together with exhibits thereto containing the consolidating balance sheet of the Company and its Subsidiaries as at the end of such year and the related consolidating statements of income of operations, shareholders’ equity and cash flows for such year, setting forth in each case in comparative form the figures for the previous fiscal year, and accompanied by the opinion of a nationally-recognized independent public accounting firm (“Independent Auditor”), which opinion shall (i) state that such financial statements present fairly the financial position and results of operations of the Company and its Subsidiaries at the time and for the periods indicated in conformity with GAAP consistently applied throughout the periods covered thereby, except as otherwise expressly noted in such financial statements, (ii) not be qualified or limited as to going concern or because of a restricted or limited examination by the Independent Auditor of any material portion of the Company’s or any Subsidiary’s records and (iii) be delivered to the Administrative Agent;

(b)    as soon as available, but not later than 60 days after the end of each of the first three fiscal quarters of each fiscal year (commencing with the fiscal quarter ending March 31, 2014), a copy of the unaudited consolidated and consolidating balance sheet of the Company and its Subsidiaries as of the end of such quarter and the related consolidated and consolidating statements of income, shareholders’ equity and cash flows for the period commencing on the first day and ending on the last day of such quarter, certified by a Responsible Officer as fairly presenting, in accordance with GAAP (subject to ordinary, good faith year-end audit adjustments), the financial position and the results of operations of the Company and its Subsidiaries at the time and for the periods indicated.

6.02    Certificates; Other Information. The Company shall furnish to the Administrative Agent, with sufficient copies for each Bank:

(a)    concurrently with the delivery of the financial statements referred to in Sections 6.01(a) and (b), a Compliance Certificate executed by a Responsible Officer;

(b)    upon request of any Bank, copies of all financial statements and reports that MDU Resources Group, Inc. sends to its shareholders, and copies of all financial statements

47

709152408 03173762

and regular, periodical or special reports (including Forms 10-K, 10-Q and 8-K) that MDU Resources Group, Inc. may make to, or file with, the SEC;

(c)    upon request of any Bank, copies of the most recent annual report (Form 5500 Series), including any supporting schedules, filed by the Company or any ERISA Affiliate with the IRS with respect to any Plan; and

(d)    promptly, such additional information regarding the business, financial or corporate affairs of the Company or any Subsidiary as the Administrative Agent, at the request of any Bank, may from time to time reasonably request.

6.03    Notices. The Company shall promptly notify the Administrative Agent and each Bank: (a) of the occurrence of any Default or Event of Default, and of the occurrence or existence of any event or circumstance known to the Company that will become a Default or Event of Default; (b) of any matter that has resulted or would reasonably be expected to result in a Material Adverse Effect, including (i) any breach or non-performance of, or any default under, a Contractual Obligation of the Company or any of its Subsidiaries; (ii) any dispute, litigation, investigation, proceeding or suspension between the Company or any of its Subsidiaries and any Governmental Authority; or (iii) the commencement of, or any material development in, any litigation or proceeding affecting the Company or any Subsidiary, including pursuant to any applicable Environmental Laws; (c) of any of the following events affecting the Company, together with a copy of any notice with respect to such event that may be required to be filed with a Governmental Authority and any notice delivered by a Governmental Authority to the Company with respect to such event: (i) an ERISA Event (together with a written notice specifying the nature thereof, what action the Company has taken, is taking or proposes to take with respect thereto, and, when known, any action taken or threatened by the IRS, the PBGC or the Department of Labor with respect thereto); and (ii) the adoption of any Pension Plan, or of any amendment to a Pension Plan if such amendment results in a material increase in contributions or Unfunded Pension Liability; (d) of any material change in accounting policies or financial reporting practices by the Company or any of its Subsidiaries; (e) of any announcement by any rating agency of any change in any component of the Pricing Rating; (f) of any loan or advance made by the Company to Centennial International; and (g) upon the request from time to time of the Administrative Agent, of the Swap Termination Values, together with a description of the method by which such amounts were determined, relating to any then-outstanding Swap Contracts to which the Company or any of its Subsidiaries is party.

Each notice under this Section shall be accompanied by a written statement by a Responsible Officer setting forth details of the occurrence referred to therein, and stating what action the Company or any affected Subsidiary proposes to take with respect thereto and at what time. Each notice under Section 6.03(a) shall describe with particularity any and all clauses or provisions of this Agreement or other Loan Document that the Company believes have been or will be breached or violated.

6.04    Preservation of Existence. Subject to transactions permitted by Section 7.02 or Section 7.03, the Company shall, and shall cause each Subsidiary to: (a) preserve and maintain in full force and effect its existence and good standing under the laws of its state or jurisdiction of organization; (b) preserve and maintain in full force and effect all governmental rights, privileges, qualifications, permits, licenses and franchises necessary or desirable in the normal conduct of its business; (c) use reasonable efforts, in the ordinary course of business, to preserve

48

709152408 03173762

its business organization and goodwill; and (d) preserve or renew all of its registered patents, trademarks, trade names and service marks; except, in each case referred to in clause (a) with respect to any Subsidiary and clauses (b) through (d), to the extent that the failure to do so could not reasonably be expected to have a Material Adverse Effect.

6.05    Maintenance of Property. Subject to transactions permitted by Section 7.02 or Section 7.03, the Company shall maintain, and shall cause each Subsidiary to maintain, and preserve all its property which is used or useful in its business in good working order and condition, ordinary wear and tear excepted, except to the extent that noncompliance would not have a Material Adverse Effect.

6.06    Insurance. The Company shall maintain, and shall cause each of its Subsidiaries to maintain, with financially sound and reputable independent insurers, insurance with respect to its properties and business against loss or damage of the kinds customarily insured against by Persons engaged in the same or similar business, of such types and in such amounts (including deductibles, co-insurance and self-insurance, if adequate reserves are maintained with respect thereto) as are customarily carried under similar circumstances by such other Persons, except to the extent that noncompliance would not have a Material Adverse Effect, and the Company will furnish to any Bank upon request full information as to the insurance carried within fifteen Business Days.

6.07    Payment of Obligations. The Company shall, and shall cause each Subsidiary to, pay and discharge as the same shall become payable, all their respective obligations and liabilities, including: (a) all tax liabilities, assessments and governmental charges or levies upon it or its properties or assets, except where (i) the same are being contested in good faith by appropriate proceedings and (ii) unless the Company has received an opinion of independent tax counsel that more likely than not neither the Company nor any of its Subsidiaries is liable for such amounts, adequate reserves to the extent required under GAAP are being maintained by the Company or such Subsidiary; (b) all lawful claims which, if unpaid, would by law become a Lien upon its property, except to the extent such claims may be contested in good faith by appropriate proceedings or as to which a bona fide dispute may exist or with respect to which adequate reserves to the extent required under GAAP have been taken; and (c) all indebtedness, as and when payable, but subject to any subordination provisions contained in any instrument or agreement evidencing such Indebtedness, except to the extent such claims may be contested in good faith by appropriate proceedings or as to which a bona fide dispute may exist or with respect to which adequate reserves, to the extent required under GAAP, have been taken; except, in each case referred to in clauses (a) through (c), to the extent that the failure to do so could not reasonably be expected to have a Material Adverse Effect.

6.08    Compliance with Laws. The Company shall comply, and shall cause each Subsidiary to comply, in all respects with all Requirements of Law of any Governmental Authority having jurisdiction over it or its business, except such as may be contested in good faith or as to which a bona fide dispute may exist and except to the extent that noncompliance would not reasonably be expected to have a Material Adverse Effect.

6.09    Inspection of Property and Books and Records. The Company shall maintain and shall cause each Subsidiary to maintain proper books of record and account, in which full, true and correct entries in conformity with GAAP consistently applied shall be made of all financial transactions and matters involving the assets and business of the Company and such

49

709152408 03173762

Subsidiaries. The Company shall permit, and shall cause each Subsidiary to permit, representatives and independent contractors of the Administrative Agent or any Bank to visit and inspect any of their respective properties, to examine their respective corporate, financial and operating records, and make copies thereof or abstracts therefrom, and to discuss their respective affairs, finances and accounts with their respective directors, officers, and (unless there exists an Event of Default, in the presence of one or more officers of the Company, which persons the Company agrees to make available) independent public accountants, all at such reasonable times during normal business hours and as often as may be reasonably desired, upon reasonable advance notice to the Company; provided that when an Event of Default exists, the Administrative Agent or any Bank may do any of the foregoing at the expense of the Company at any time during normal business hours and without advance notice.

6.10    Environmental Laws. The Company shall, and shall cause each Subsidiary to, conduct its operations and keep and maintain its property in compliance with all Environmental Laws, except to the extent that noncompliance would not have a Material Adverse Effect.

6.11    Use of Proceeds. The Company shall use the proceeds of the Loans for working capital and other general corporate purposes (including for commercial paper back-up and to fund negotiated Acquisitions and other investments otherwise permitted hereunder) not in contravention of any Requirement of Law or of any Loan Document.

6.12    OFAC, PATRIOT Act Compliance.  The Company shall, and shall cause each Subsidiary to, (i) refrain from doing business in a Sanctioned Country or with a Sanctioned Person in violation of the economic sanctions of the United States administered by OFAC, and (ii) provide, to the extent commercially reasonable, such information and take such actions as are reasonably requested by the Administrative Agent or any Bank in order to assist the Administrative Agent and the Banks in maintaining compliance with the PATRIOT Act.

ARTICLE VII

NEGATIVE COVENANTS

So long as any Bank has any Commitment hereunder, any Letter of Credit remains outstanding or any Loan or other Obligation remains unpaid or unsatisfied, unless the Majority Banks waive compliance in writing:

7.01    Limitation on Liens. The Company shall not, and shall not suffer or permit any Subsidiary (other than any Project Finance Subsidiary or any International Subsidiary) to, directly or indirectly, make, create, incur, assume or suffer to exist any Lien upon or with respect to any part of its property, whether now owned or hereafter acquired, other than the following (“Permitted Liens”):

(a)    any Lien existing on property of the Company or any Subsidiary on the Execution Date and set forth in Schedule 7.01 securing Indebtedness outstanding on such date;

(b)    any Lien created under any Loan Document;

(c)    Liens for taxes, fees, assessments or other governmental charges which are not delinquent or remain payable without penalty, or to the extent that non-payment thereof is permitted by Section 6.07;

50

709152408 03173762

(d)    carriers’, warehousemen’s, mechanics’, landlords’, materialmen’s, repairmen’s, operators’ (including Liens arising under operating, pooling or unitizing agreements of a scope and nature customary in the oil and gas industry) or other similar Liens arising in the ordinary course of business which are not delinquent or remain payable without penalty or which are being contested in good faith and by appropriate proceedings, which proceedings have the effect of preventing the forfeiture or sale of the property subject thereto, and for which adequate reserves are maintained on the books of such Person;

(e)    Liens (other than any Lien imposed by ERISA) consisting of pledges or deposits required in the ordinary course of business under workers’ compensation laws, unemployment insurance and other social security or retirement benefits, or similar legislation;

(f)    Liens on the property of the Company or its Subsidiaries securing (i) the non-delinquent performance of bids, trade contracts (other than for borrowed money), leases, statutory obligations, (ii) contingent obligations on surety, reclamation and appeal bonds, and (iii) other non-delinquent obligations of a like nature, in each case, incurred in the ordinary course of business, provided all such Liens in the aggregate would not (even if enforced) cause a Material Adverse Effect;

(g)    Liens consisting of judgment or judicial attachment liens, provided that the enforcement of such Liens is effectively stayed and the aggregate amount of the obligations secured by all such liens for the Company and its Subsidiaries (other than any Project Finance Subsidiary) does not exceed $50,000,000 at any time;

(h)    easements, rights-of-way, restrictions and other similar encumbrances incurred in the ordinary course of business which, in the aggregate, are not substantial in amount, and which do not in any case materially detract from the value of the property subject thereto or interfere with the ordinary conduct of the businesses of the Company and its Subsidiaries;

(i)Liens on assets of Persons which become Subsidiaries after the Execution Date or liens existing on any property acquired by the Company or any Subsidiary at the time such property is acquired, provided that (A) such Liens existed at the time the respective Persons became Subsidiaries or at the time such property was acquired, as applicable, and were not created in anticipation thereof and (B) such Liens shall extend solely to the property so acquired and to identifiable proceeds thereof, and shall not attach to any other property of the Company or its Subsidiaries;

(j)purchase money security interests on any real or personal property acquired or held by the Company or its Subsidiaries in the ordinary course of business, securing Indebtedness incurred or assumed for the purpose of financing all or any part of the cost of acquiring such property; provided that (i) any such Lien attaches to such property concurrently with or within 20 days after the acquisition thereof, (ii) such Lien attaches solely to the property so acquired in such transaction, and (iii) the principal amount of the debt secured thereby does not exceed 100% of the cost of such property;

(k)Liens securing obligations in respect of capital leases on assets subject to such leases, provided that such capital leases are otherwise permitted hereunder;

(l)Liens arising solely by virtue of any statutory or common law provision relating to banker’s liens, rights of set-off or similar rights and remedies as to deposit accounts or

51

709152408 03173762

other funds maintained with a creditor depository institution; provided that (i) such deposit account is not a dedicated cash collateral account and is not subject to restrictions against access by the Company in excess of those set forth by regulations promulgated by the FRB, and (ii) such deposit account is not intended by the Company or any Subsidiary to provide collateral to the depository institution;

(m)Liens arising in connection with Securitization Transactions; provided that the amount of all Securitization Obligations shall not at any time exceed $75,000,000;

(n)Liens on the stock or other equity interests of any Project Finance Subsidiary or Joint Venture to secure obligations of such Project Finance Subsidiary or Joint Venture, as applicable (provided that the agreement under which any such Lien is created shall expressly state that it is non-recourse to the pledgor);

(o)Liens securing Indebtedness of a Subsidiary owed to the Company;

(p)other Liens securing Indebtedness otherwise permitted herein not exceeding $35,000,000 in the aggregate; and

(q)any Lien renewing, extending or refunding any Lien permitted by clause (a), (i) or (j) of this Section 7.01; provided that (i) the principal amount of the Indebtedness secured by the subject Liens is not increased over the amount of the Indebtedness secured thereby immediately prior to such extension, renewal or refunding, (ii) such Lien is not extended to any other property and (iii) immediately after such extension, renewal or refunding, no Default or Event of Default would exist.

7.02    Disposition of Assets. The Company shall not, and shall not suffer or permit any Subsidiary (other than any Project Finance Subsidiary or any International Subsidiary) to, directly or indirectly, sell, assign, lease, convey, transfer or otherwise dispose of (whether in one or a series of transactions) any assets (including accounts and notes receivable, with or without recourse, and including any interest in any Subsidiary) or enter into any agreement to do any of the foregoing, except:

(i)    dispositions of inventory (including inventory comprised of electric energy, gas, oil, coal, aggregate and other materials and products generated, manufactured, produced, mined or purchased for sale, distribution or use in the ordinary course of business), or used, worn-out, damaged or surplus equipment, all in the ordinary course of business;

(ii)    the sale of equipment to the extent that such equipment is exchanged for credit against the purchase price of similar replacement equipment, or the proceeds of such sale are reasonably promptly applied to the purchase price of such replacement equipment;

(iii)    dispositions of assets by the Company or any Subsidiary to the Company or any Subsidiary (other than a Project Finance Subsidiary) pursuant to reasonable business requirements;

(iv)    exchanges of property on which recognition of gain or loss would be exempted from recognition pursuant to section 1031 of the Code; or

52

709152408 03173762

(v)    the sale, assignment or other transfer of accounts receivable, lease receivables or other rights to payment pursuant to any Securitization Transaction;

provided that dispositions not prohibited by other provisions of this Agreement and not otherwise permitted by the foregoing which are made for fair market value are permitted so long as (w) at the time of any disposition, no Default or Event of Default shall exist or shall result from such disposition, (x) the aggregate sales price from such disposition shall be paid (1) in cash, (2) in marketable securities that are the subject of widely or regularly distributed standard price quotations, and/or (3) through the issuance of indebtedness by the buyer of such assets; provided that the aggregate outstanding principal amount of all such indebtedness shall not at any time exceed $35,000,000, (y) the aggregate value of all assets so sold by the Company and its Subsidiaries pursuant to clauses (i) through (iv), together, shall not exceed in any fiscal year 20% of total consolidated assets (as determined in accordance with GAAP) of the Company and its Subsidiaries, based upon the most recent financial statements delivered to the Administrative Agent under Section 6.01, and (z) the aggregate amount of all Securitization Obligations shall not at any time exceed $75,000,000; and provided, further, that in no event shall the Company sell, assign, lease, convey, transfer or otherwise dispose of any capital stock or other equity interests in any of the Principal Operating Subsidiaries, except pursuant to a merger or other transaction permitted in accordance with Section 7.03.

7.03    Consolidations and Mergers. The Company shall not, and shall not suffer or permit any Subsidiary (other than any Project Finance Subsidiary or any International Subsidiary) to, merge or consolidate with or into, or convey, transfer, lease or otherwise dispose of (whether in one transaction or in a series of transactions) all or substantially all of its assets (whether now owned or hereafter acquired) to or in favor of, any Person, except:

(a)    any Subsidiary may merge or consolidate with or into (i) the Company, provided that the Company shall be the continuing or surviving corporation, or (ii) any one or more Subsidiaries (other than a Project Finance Subsidiary or an International Subsidiary (unless such merger or consolidation involves only International Subsidiaries)); provided that if (A) any transaction shall be between a Subsidiary and a Wholly-Owned Subsidiary, the Wholly-Owned Subsidiary shall be the continuing or surviving entity and (B) any transaction shall involve a Principal Operating Subsidiary, a Principal Operating Subsidiary shall be the continuing or surviving entity;

(b)    the Company and any Subsidiary may convey, transfer, lease or otherwise dispose of all or substantially all of its assets in compliance with the provisions of Section 7.02;

(c)    any Subsidiary may convey, transfer, lease or otherwise dispose of all or substantially all of its assets (upon voluntary liquidation or otherwise) to the Company or another Wholly-Owned Subsidiary (other than a Project Finance Subsidiary or an International Subsidiary (unless such transaction involves only International Subsidiaries));

(d)    any Subsidiary may merge, consolidate or combine with or into any other Person; provided that the successor formed by such consolidation or combination or the survivor of such merger is a Subsidiary and the Company directly or indirectly through Wholly-Owned Subsidiaries owns at least the same percentage of outstanding stock or other equity interests of the successor or survivor Subsidiary as the Subsidiary involved in the consolidation, combination or merger; and provided, further, that (i) the prior, effective written consent or approval to such

53

709152408 03173762

consolidation, combination or merger of the board of directors or equivalent governing body of the other party is obtained and (ii) in the case of a merger, consolidation or combination with or into an entity that, if it were a separate Subsidiary of the Company, would be deemed to constitute a Significant Subsidiary, the Pricing Rating immediately before giving effect to such transaction is not below, and the Pricing Rating would not reasonably be expected solely as a result of such transaction to decline below, BBB+; and

(e)    the Company may merge, consolidate or combine with another entity if the Company is the Person surviving the merger, consolidation or combination; provided that (i) the prior, effective written consent or approval to such consolidation, combination or merger of the board of directors or equivalent governing body of the other party is obtained and (ii) in the case of a merger, consolidation or combination with or into an entity that, if it were a separate Subsidiary of the Company, would be deemed to constitute a Significant Subsidiary, the Pricing Rating immediately before giving effect to such transaction is not below, and the Pricing Rating would not reasonably be expected solely as a result of such transaction to decline below, BBB+.

7.04    Loans and Investments. The Company shall not purchase or acquire, or suffer or permit any Subsidiary (other than a Project Finance Subsidiary) to purchase or acquire, or make any legally binding commitment therefor, any capital stock or other equity interests, or any obligations or other securities of, or any interest in, any Person, or make, or make any legally binding commitment to make, any Acquisitions, or make, or make any legally binding commitment to make, any advance, loan, extension of credit or capital contribution to or any other investment in, any Person, including any Affiliate of the Company, except for:

(a)    investments in cash equivalents and short-term marketable securities pursuant to and in accordance with the terms of the Company’s then-current investment policy duly adopted by the board of directors of the Company (the “Investment Policy”);

(b)    investments in capital stock, equity or long-term fixed income securities of any Subsidiary (other than a Project Finance Subsidiary) that is not a Wholly-Owned Subsidiary, or otherwise undertaken in accordance with the Investment Policy, which do not in the aggregate exceed $100,000,000 in value at any time (value for this purpose being defined as the greatest of face value, market value or original cost to the Company or any Subsidiary);

(c)    extensions of credit in the nature of accounts receivable or notes receivable arising from the sale or lease of goods or services in the ordinary course of business;

(d)    subject to Section 7.12, advances, loans and other extensions of credit by the Company to any of its Wholly-Owned Subsidiaries (other than a Project Finance Subsidiary) or by any of its Wholly-Owned Subsidiaries to another of its Wholly-Owned Subsidiaries (other than a Project Finance Subsidiary);

(e)    equity investments in or capital contributions to any Wholly-Owned Subsidiary (other than a Project Finance Subsidiary) by the Company or any of its Wholly-Owned Subsidiaries;

(f)    investments incurred in order to consummate Acquisitions; provided that such Acquisitions are undertaken in accordance with all material applicable Requirements of Law and the prior, effective written consent or approval to such Acquisition of the board of directors or equivalent governing body of the acquiree is obtained;

54

709152408 03173762

(g)    (i) the guaranty of up to $75,000,000 of indebtedness of DPR, which amount shall increase to $175,000,000 in the event that DPR becomes a Subsidiary; and (ii) other investments in, Guaranty Obligations in respect of, or advances, loans, extensions of credit or capital contributions to, any Project Finance Subsidiary; provided that, notwithstanding any other provision of this Section 7.04, the aggregate amount of all such investments, Guaranty Obligations, advances, loans, extensions of credit and capital contributions (without giving effect to any changes in the value thereof after the making thereof) shall not in the aggregate exceed $100,000,000 in value at any time;

(h)    investments in the MDU Resources Group, Inc. Benefits Protection Trust in accordance with past practice of the Company; or

(i)    other investments; provided that the value of the aggregate amount of investments permitted by this clause (i) shall not exceed 20% of Consolidated Net Worth at any time.

Nothing contained in this Section 7.04 (other than clause (g) hereof) shall prohibit the Company or any Subsidiary from incurring Guaranty Obligations to the extent permitted by Section 7.11 and Section 7.12.

7.05    Transactions with Affiliates. The Company shall not enter into any material transaction or arrangement or series of related transactions or arrangements that in the aggregate would be material with any Affiliate of the Company, and the Company shall not suffer or permit any Subsidiary (other than a Project Finance Subsidiary) to enter into any material transaction or arrangement or series of related transactions or arrangements that in the aggregate would be material with any Affiliate of the Company other than another Subsidiary of the Company that is a Wholly-Owned Subsidiary (but which is not a Project Finance Subsidiary), except (i) upon fair and reasonable terms no less favorable to the Company or such Subsidiary than would be obtained, taking into account all facts and circumstances, in a comparable arm’s-length transaction with a Person not an Affiliate of the Company or such Subsidiary, (ii) in connection with any transaction permitted by Section 7.04(g), or (iii) (A) in the ordinary course and pursuant to the reasonable requirements of the business of Williston Basin Interstate Pipeline Company (“Williston Basin”) as may be required by the Federal Energy Regulatory Commission or other appropriate Governmental Authorities having jurisdiction over Williston Basin, or (B) pursuant to the Asset Purchase Agreement, dated August 6, 1982, by and between Montana-Dakota Utilities Co. (“Montana-Dakota”) and Williston Basin, as amended by Amendment to the Asset Purchase Agreement, dated January 21, 1985, entered into in furtherance of the Revised Stipulation and Agreement of Settlement in FERC Docket No. CP82-487-000 et al. (the “Settlement Agreement”), to the extent that Article Twelve thereof requires Williston Basin, if and when it implements a pricing mechanism for Williston Basin owned production which results in prices higher than cost-of-service pricing for such production, to make a payment to Montana-Dakota which is equal in amount to the adjustment made by Montana-Dakota pursuant to Section 10.1 of such Settlement Agreement; provided that all such transactions and agreements permitted by this clause (iii) do not, individually or in the aggregate, result in a Material Adverse Effect.

7.06    Use of Proceeds. The Company shall not, and shall not suffer or permit any Subsidiary to, use any portion of the Loan proceeds, directly or indirectly, (a) to purchase or carry Margin Stock, (b) to repay or otherwise refinance Indebtedness of the Company or others

55

709152408 03173762

incurred to purchase or carry Margin Stock, (c) to extend credit for the purpose of purchasing or carrying any Margin Stock, or (d) to make any Acquisition that is opposed by either the board of directors or similar governing body, or by stockholders or other equity holders possessing a majority of the voting power of the outstanding voting stock or other equity interests, as the case may be, of the entity that is subject to, or whose assets are the subject of, such Acquisition.

7.07    Joint Ventures. The Company shall not, and shall not suffer or permit any Subsidiary to, enter into any Joint Venture that is or will be engaged in any line of business other than (a) businesses engaged in by MDU Resources Group, Inc. and its Subsidiaries as of the date of this Agreement, or (b) businesses closely related to any business engaged in by MDU Resources Group, Inc. and its Subsidiaries as of the date of this Agreement.

7.08    Restricted Payments. The Company shall not, and shall not suffer or permit any Subsidiary (other than a Project Finance Subsidiary) to, declare or make any dividend payment or other distribution of assets, properties, cash, rights, obligations or securities on account of any shares of any class of its capital stock or other equity interests, or purchase, redeem or otherwise acquire for value any shares of its capital stock or any other equity interests or any warrants, rights or options to acquire such shares or other equity interests, now or hereafter outstanding; except that (a) any Subsidiary may declare and pay dividends or make distributions to the Company or a Wholly-Owned Subsidiary, and (b) the Company or any Subsidiary may:

(i)    declare and make dividend payments or other distributions payable solely in its common stock or other equity interests;

(ii)    purchase, redeem or otherwise acquire shares of its common stock or other equity interests or warrants or options to acquire any such shares with the proceeds received from the substantially concurrent issue of new shares of its common stock or other equity interests; and

(iii)    declare or pay cash dividends or other distributions to its equity holders and purchase, redeem or otherwise acquire shares of its capital stock or other equity interests or warrants, rights or options to acquire any such shares or other equity interests for cash in an aggregate amount for any fiscal year not to exceed the Maximum Annual RP Amount (as defined below); provided that in each case immediately after giving effect to such proposed action, no Default or Event of Default would exist. As used herein, “Maximum Annual RP Amount” means, for any fiscal year, 100% of the consolidated net income after taxes of the Company or Subsidiary, as the case may be, arising during the immediately preceding fiscal year and computed on a cumulative consolidated basis, excluding non-cash writedowns.

7.09    Change in Business. The Company shall not, and shall not suffer or permit any Subsidiary to, engage in any material line of business substantially different from those lines of business carried on by MDU Resources Group, Inc. and its Subsidiaries on the date hereof.

7.10    Accounting Changes. The Company shall not, and shall not suffer or permit any Subsidiary to, make any significant change in accounting treatment or reporting practices, except as required or permitted by GAAP (or, if applicable, IFRS), or change the fiscal year of the Company.

56

709152408 03173762

7.11    Maximum Company Capitalization Ratio. The Company shall not permit the Company’s Capitalization Ratio to exceed 65% as of the end of any fiscal quarter during the term hereof.

7.12    Limitation on Subsidiary Indebtedness. The Company will not permit any Subsidiary of the Company to, directly or indirectly, create, incur, assume, guarantee, have outstanding, or otherwise become or remain directly or indirectly liable with respect to, any Indebtedness other than:

(i)    Indebtedness outstanding on the date hereof and disclosed in Schedule 7.12; provided that such Indebtedness may not be extended, renewed or refunded except as otherwise permitted by this Agreement;

(ii)    Indebtedness in respect of unsecured surety bonds incurred in the ordinary course of business;

(iii)    Indebtedness of a Subsidiary owed to the Company or any Wholly-Owned Subsidiary (other than a Project Finance Subsidiary);

(iv)    Indebtedness under Covered Contracts;

(v)    Indebtedness of Williston Basin to the extent such Indebtedness does not exceed $500,000,000;

(vi)    Indebtedness of a Project Finance Subsidiary or Joint Venture for which neither the Company nor or any other Subsidiary (other than another Project Finance Subsidiary) has any liability (other than pursuant to Liens permitted by Section 7.01(n) or to the extent permitted by Section 7.04); and

(vii)    Indebtedness of a Subsidiary (other than a Project Finance Subsidiary) in addition to that otherwise permitted by the foregoing provisions of this Section 7.12; provided that on the date such Subsidiary incurs or otherwise becomes liable with respect to any such additional Indebtedness and immediately after giving effect thereto and to the concurrent retirement of any other Indebtedness, (A) no Default or Event of Default exists and (B) the total amount of all Indebtedness described in this clause (vii) outstanding does not exceed $50,000,000.

For purposes of this Section 7.12, any Person becoming a Subsidiary after the date hereof shall be deemed, at the time it becomes a Subsidiary, to have incurred all of its then outstanding Indebtedness, and any Person extending, renewing or refunding any Indebtedness shall be deemed to have incurred such Indebtedness at the time of such extension, renewal or refunding. Notwithstanding any provision of this Agreement to the contrary, the Company will not at any time permit (a) the sum of (i) the aggregate stated amount of all Letters of Credit issued jointly for the account of the Company and Centennial International plus (ii) the aggregate amount of all intercompany loans and other advances made by the Company or any Subsidiary (other than any International Subsidiary) to the International Subsidiaries to at any time exceed $100,000,000 or (b) the aggregate outstanding principal amount of consolidated Indebtedness of the International Subsidiaries (including with respect to intercompany loans and advances (other than any loan or advance made by any International Subsidiary) and Letters of Credit) to exceed 10% of the result

57

709152408 03173762

of (i) Consolidated Net Worth less (ii) the aggregate book value of the consolidated intangible assets of the Company and its Subsidiaries.

7.13    Agreements Restricting Subsidiary Dividends. With the exception of (a) the referenced sections of the existing agreements specified in Schedule 7.13, (b) Organization Documents of any Subsidiary and Requirements of Law and (c) agreements, instruments or other documents, evidencing Indebtedness and/or Contingent Obligations having an aggregate principal amount not in excess of $15,000,000, to which any Person which becomes a Subsidiary after the Execution Date and which, together with all other Subsidiaries of the Company which became Subsidiaries after the Execution Date that are parties to such agreements, instruments or documents, would, if a single Subsidiary of the Company, be a Significant Subsidiary (a “Restricted Future Subsidiary”) is a party, that existed at the time the Person became a Subsidiary and were not entered into in anticipation thereof, the Company agrees that it will not, and it will not permit any Person that, as of the Execution Date, is a Subsidiary or any Restricted Future Subsidiary (other than any Project Finance Subsidiary) to, be a party to or enter into any agreement, instrument or other document which contractually prohibits or restricts the ability of any Subsidiary to pay dividends or make any other similar distributions to the Company or any of its wholly-owned Subsidiaries that owns outstanding shares of capital stock or similar equity interests of such Subsidiary.

7.14    Activities of International Subsidiaries. The Company agrees that it will not permit any International Subsidiary, directly or indirectly, to be primarily engaged in the ownership or financing of assets located in, or to conduct the primary portion of its operations in, the United States.

ARTICLE VIII

EVENTS OF DEFAULT

8.01    Event of Default. Any of the following shall constitute an “Event of Default”:

(a)    Non-Payment. The Company fails to pay (i) within two days after the same becomes due, any amount of principal of any Loan or any Reimbursement Obligations, (ii) within five days after the same becomes due, any interest or fee hereunder, or (iii) within five days after the same becomes due pursuant to delivery of a written demand therefor by the Administrative Agent or any Bank, any other amount payable hereunder or under any other Loan Document; or

(b)    Representation or Warranty. Any representation or warranty by the Company or any Subsidiary made or deemed made herein or in any other Loan Document, or which is contained in any certificate, document or financial or other statement by the Company, any Subsidiary, or any Responsible Officer, furnished at any time under this Agreement, or in or under any other Loan Document, is incorrect in any material respect on or as of the date made or deemed made; or

(c)    Specific Defaults. (i) The Company fails to perform or observe any term, covenant or agreement contained in Article VII; or (ii) the Company fails to perform or observe any term, covenant or agreement contained in any of Section 6.01, 6.02, 6.03, 6.04(a) (with respect to the Company) or 6.09 and such failure continues for a period of three days after the date such performance or observance is first required; or

58

709152408 03173762

(d)    Other Defaults. The Company fails to perform or observe any other term or covenant contained in this Agreement or any other Loan Document, and such default shall continue unremedied for a period of 30 days after the earlier of (i) the date upon which a Responsible Officer knew or reasonably should have known of such failure or (ii) the date upon which written notice thereof is given to the Company by the Administrative Agent or any Bank; or

(e)    Cross-Default. The Company or any Subsidiary (other than DPR if it becomes a Subsidiary) (i) fails to make any payment in respect of any Indebtedness or Contingent Obligation having an aggregate principal amount (including undrawn committed or available amounts and including amounts owing to all creditors under any combined or syndicated credit arrangement) of more than $35,000,000 when due (whether by scheduled maturity, required prepayment, acceleration, demand, or otherwise) and such failure continues after the applicable grace or notice period, if any, specified in the relevant document on the date of such failure; or (ii) fails to perform or observe any other condition or covenant, or any other event shall occur or condition exist, under any agreement or instrument relating to any such Indebtedness or Contingent Obligation, and such failure continues after the applicable grace or notice period, if any, specified in the relevant document on the date of such failure if the effect of such failure, event or condition is to cause, or to permit the holder or holders of such Indebtedness or beneficiary or beneficiaries of such Indebtedness (or a trustee or agent on behalf of such holder or holders or beneficiary or beneficiaries) to cause, such Indebtedness to be declared to be due and payable prior to its stated maturity, or such Contingent Obligation to become payable or cash collateral in respect thereof to be demanded; or

(f)    Insolvency; Voluntary Proceedings. The Company or any Subsidiary (i) ceases or fails to be Solvent, or generally fails to pay, or admits in writing its inability to pay, its debts as they become due, subject to applicable grace periods, if any, whether at stated maturity or otherwise; (ii) voluntarily ceases to conduct its business in the ordinary course; (iii) commences any Insolvency Proceeding with respect to itself; or (iv) takes any action to effectuate or authorize any of the foregoing; or

(g)    Involuntary Proceedings. (i) Any involuntary Insolvency Proceeding is commenced or filed against the Company or any Subsidiary, or any writ, judgment, warrant of attachment, execution or similar process is issued or levied against a substantial part of the Company’s or any Subsidiary’s properties, and any such proceeding or petition shall not be dismissed, or such writ, judgment, warrant of attachment, execution or similar process shall not be released, vacated or fully bonded within 60 days after commencement, filing or levy; (ii) the Company or any Subsidiary admits the material allegations of a petition against it in any Insolvency Proceeding, or an order for relief (or similar order under non-U.S. law) is ordered in any Insolvency Proceeding; or (iii) the Company or any Subsidiary acquiesces in the appointment of a receiver, trustee, custodian, conservator, liquidator, mortgagee in possession (or agent therefor), or other similar Person for itself or a substantial portion of its property or business; or

(h)    ERISA. (i) An ERISA Event with respect to a Pension Plan or Multiemployer Plan, or an ERISA Termination Event with respect to a Pension Plan, shall occur which has resulted or would reasonably be expected to result in liability of the Company under Title IV of ERISA to the Pension Plan, Multiemployer Plan or the PBGC in an aggregate amount in excess of 10% of Consolidated Net Worth; (ii) the commencement or increase of contributions

59

709152408 03173762

to, or the adoption of or the amendment of, a Pension Plan by the Company or an ERISA Affiliate which has resulted or could reasonably be expected to result in an increase in Unfunded Pension Liability among all Pension Plans in an aggregate amount in excess of 10% of Consolidated Net Worth; or (iii) the Company or an ERISA Affiliate shall fail to pay when due, after the expiration of any applicable grace period, any installment payment with respect to its withdrawal liability under Section 4201 of ERISA under a Multiemployer Plan which has resulted or could reasonably be expected to result in a Material Adverse Effect; or

(i)    Judgments. (x) One or more non-interlocutory judgments, non-interlocutory orders, decrees or arbitration awards is entered against the Company or any Subsidiary involving in the aggregate a liability (to the extent not covered by independent third-party insurance as to which the insurer does not dispute coverage) of $25,000,000 or more; or (y) any non‑monetary final judgment is entered against the Company or any Subsidiary that has, or could reasonably be expected to have, a material adverse effect on the ability of the Company to perform its obligations under the Loan Documents; and in either case, the same shall remain unsatisfied, unvacated, unstayed pending appeal, unbonded or discharged for a period of 60 days after the entry thereof; or

(j)    Change of Control. There occurs any Change of Control; or

(k)    Invalidity of Loan Documents. Any Loan Document ceases to be in full force and effect or the Company contests in any manner the validity or enforceability thereof.

8.02    Remedies. If any Event of Default occurs, the Administrative Agent shall, at the request of, or may, with the consent of, the Majority Banks,

(a)    declare the commitment of each Bank to make Loans and of the Issuers to issue Letters of Credit to be suspended or terminated, whereupon such commitments shall be suspended or terminated, as applicable;

(b)    declare all or any part of the Obligations to be immediately due and payable, without presentment, demand, protest or other notice of any kind, all of which are hereby expressly waived by the Company;

(c)    exercise on behalf of itself and the Banks all rights and remedies available to it and the Banks under the Loan Documents or applicable law; and/or

(d)    upon notice to the Company and in addition to the continuing right to demand payment of all amounts payable under this Agreement, make demand on the Company to pay, and the Company will, forthwith upon such demand and without any further notice or act, pay to the Administrative Agent an amount in immediately available funds equal to the excess of (i) the amount of Letter of Credit Obligations at such time over (ii) the amount on deposit in the LC Collateral Account at such time which is free and clear of all rights and claims of third parties and has not been applied against the Obligations (such difference, the “Collateral Shortfall Amount”), which funds shall be deposited and held in the LC Collateral Account;

provided that upon the occurrence of any event specified in clause (f) or (g) of Section 8.01 (in the case of clause (i) of clause (g) upon the expiration of the 60-day period mentioned therein), the obligation of each Bank to make Loans and the obligation and power of each Issuer to issue Letters of Credit shall automatically terminate and the Obligations shall automatically become

60

709152408 03173762

due and payable without further act of the Administrative Agent or any Bank and the Company will be and become thereby unconditionally obligated, without any further notice, act or demand, to pay to the Administrative Agent the Collateral Shortfall Amount; provided, further, that if, within 30 days after acceleration of the Obligations or termination of the obligations of the Banks to make Loans and of the Issuers to issue Letters of Credit as a result of any Event of Default (other than any Event of Default as described in clause (f) or (g) of Section 8.01 with respect to the Company) and before any judgment or decree for the payment of the Obligations due shall have been obtained or entered, the Majority Banks (in their sole discretion) shall so direct, the Administrative Agent shall, by notice to the Company, rescind and annul such acceleration and/or termination.

ARTICLE IX

THE ADMINISTRATIVE AGENT

9.01    Appointment; Nature of Relationship. (a) U.S. Bank is hereby appointed by each of the Banks as its contractual representative (herein referred to as the “Administrative Agent”) hereunder and under each other Loan Document, and each of the Banks irrevocably authorizes the Administrative Agent to act as the contractual representative of such Bank with the rights and duties expressly set forth herein and in the other Loan Documents. The Administrative Agent agrees to act as such contractual representative upon the express conditions contained in this Article IX. Notwithstanding the use of the defined term “Administrative Agent,” it is expressly understood and agreed that the Administrative Agent shall not have any fiduciary responsibilities to any Bank by reason of this Agreement or any other Loan Document and that the Administrative Agent is merely acting as the contractual representative of the Banks with only those duties as are expressly set forth in this Agreement and the other Loan Documents. In its capacity as the Banks’ contractual representative, the Administrative Agent (i) does not hereby assume any fiduciary duties to any of the Banks, (ii) is a “representative” of the Banks within the meaning of Section 9-102 of the Uniform Commercial Code and (iii) is acting as an independent contractor, the rights and duties of which are limited to those expressly set forth in this Agreement and the other Loan Documents. Each of the Banks hereby agrees to assert no claim against the Administrative Agent on any agency theory or any other theory of liability for breach of fiduciary duty, all of which claims each Bank hereby waives.

(b) Each Issuer shall act on behalf of the Banks with respect to any Letter of Credit issued by it and the documents associated therewith. Each Issuer shall have all of the benefits and immunities provided to the Administrative Agent in this Article IX with respect to any acts taken or omissions suffered by such Issuer in connection with Letters of Credit issued by it or proposed to be issued by it and the applications and agreements for letters of credit pertaining to such Letters of Credit as fully as if the term “Administrative Agent”, as used in this Article IX, included such Issuer with respect to such acts or omissions and as additionally provided in this Agreement with respect to such Issuer.

9.02    Powers. The Administrative Agent shall have and may exercise such powers under the Loan Documents as are specifically delegated to the Administrative Agent by the terms of each thereof, together with such powers as are reasonably incidental thereto. The Administrative Agent shall have no implied duties to the Banks, or any obligation to the Banks to take any action thereunder except any action specifically provided by the Loan Documents to be taken by the Administrative Agent.

61

709152408 03173762

9.03    General Immunity. Neither the Administrative Agent nor any of its directors, officers, agents or employees shall be liable to the Company or any Bank for any action taken or omitted to be taken by it or them hereunder or under any other Loan Document or in connection herewith or therewith except to the extent such action or inaction is determined in a final non-appealable judgment by a court of competent jurisdiction to have arisen from the gross negligence or willful misconduct of such Person.

9.04    No Responsibility for Loans, Recitals, etc. Neither the Administrative Agent nor any of its directors, officers, agents or employees shall be responsible for or have any duty to ascertain, inquire into, or verify (a) any statement, warranty or representation made in connection with any Loan Document or any borrowing hereunder; (b) the performance or observance of any of the covenants or agreements of any obligor under any Loan Document, including any agreement by an obligor to furnish information directly to each Bank; (c) the satisfaction of any condition specified in Article IV, except receipt of items required to be delivered solely to the Administrative Agent; (d) the existence or possible existence of any Default or Event of Default; (e) the validity, enforceability, effectiveness, sufficiency or genuineness of any Loan Document or any other instrument or writing furnished in connection therewith; (f) the value, sufficiency, creation, perfection or priority of any Lien in any collateral security; or (g) the financial condition of the Company or any guarantor of any of the Obligations or of any of the Company’s or any such guarantor’s respective Subsidiaries. The Administrative Agent shall have no duty to disclose to the Banks information that is not required to be furnished by the Company to the Administrative Agent at such time, but is voluntarily furnished by the Company to the Administrative Agent (either in its capacity as Administrative Agent or in its individual capacity).

9.05    Action on Instructions of Banks. The Administrative Agent shall in all cases be fully protected in acting, or in refraining from acting, hereunder and under any other Loan Document in accordance with written instructions signed by the Majority Banks, and such instructions and any action taken or failure to act pursuant thereto shall be binding on all of the Banks. The Banks hereby acknowledge that the Administrative Agent shall be under no duty to take any discretionary action permitted to be taken by it pursuant to the provisions of this Agreement or any other Loan Document unless it shall be requested in writing to do so by the Majority Banks. The Administrative Agent shall be fully justified in failing or refusing to take any action hereunder and under any other Loan Document unless it shall first be indemnified to its satisfaction by the Banks pro rata against any and all liability, cost and expense that it may incur by reason of taking or continuing to take any such action.

9.06    Employment of Agents and Counsel. The Administrative Agent may execute any of its duties as Administrative Agent hereunder and under any other Loan Document by or through employees, agents, and attorneys-in-fact and shall not be answerable to the Banks, except as to money or securities received by it or its authorized agents, for the default or misconduct of any such agents or attorneys-in-fact selected by it with reasonable care. The Administrative Agent shall be entitled to advice of counsel concerning the contractual arrangement between the Administrative Agent and the Banks and all matters pertaining to the Administrative Agent’s duties hereunder and under any other Loan Document.

9.07    Reliance on Documents; Counsel. The Administrative Agent shall be entitled to rely upon any Note, notice, consent, certificate, affidavit, letter, telegram, statement, paper or document believed by it to be genuine and correct and to have been signed or sent by the proper

62

709152408 03173762

person or persons, and, in respect to legal matters, upon the opinion of counsel selected by the Administrative Agent, which counsel may be employees of the Administrative Agent. For purposes of determining compliance with the conditions specified in Section 4.01, each Bank that has executed this Agreement shall be deemed to have consented to, approved or accepted or to be satisfied with, each document or other matter either sent by the Administrative Agent to such Bank for consent, approval, acceptance or satisfaction, or required thereunder to be consented to or approved by or acceptable or satisfactory to the Bank.

9.08    Administrative Agent’s Reimbursement and Indemnification. The Banks agree to reimburse and indemnify the Administrative Agent ratably in proportion to their respective Commitments (or, if the Commitments have been terminated, in proportion to their Commitments immediately prior to such termination) (i) for any amounts not reimbursed by the Company for which the Administrative Agent is entitled to reimbursement by the Company under the Loan Documents, (ii) for any other expenses incurred by the Administrative Agent on behalf of the Banks, in connection with the preparation, execution, delivery, administration and enforcement of the Loan Documents (including for any expenses incurred by the Administrative Agent in connection with any dispute between the Administrative Agent and any Bank or between two or more of the Banks) and (iii) for any liabilities, obligations, losses, damages, penalties, actions, judgments, suits, costs, expenses or disbursements of any kind and nature whatsoever which may be imposed on, incurred by or asserted against the Administrative Agent in any way relating to or arising out of the Loan Documents or any other document delivered in connection therewith or the transactions contemplated thereby (including for any such amounts incurred by or asserted against the Administrative Agent in connection with any dispute between the Administrative Agent and any Bank or between two or more of the Banks), or the enforcement of any of the terms of the Loan Documents or of any such other documents; provided that (i) no Bank shall be liable for any of the foregoing to the extent any of the foregoing is found in a final non-appealable judgment by a court of competent jurisdiction to have resulted from the gross negligence or willful misconduct of the Administrative Agent and (ii) any indemnification required pursuant to Section 3.06(e) shall, notwithstanding the provisions of this Section 9.08, be paid by the relevant Bank in accordance with the provisions thereof. The obligations of the Banks under this Section 9.08 shall survive payment of the Obligations and termination of this Agreement.

9.09    Notice of Default. The Administrative Agent shall not be deemed to have knowledge or notice of the occurrence of any Default or Event of Default hereunder, except with respect to a Default or Event of Default arising from the non-payment of principal, interest or fees required to be paid to the Administrative Agent for the account of the Banks, unless the Administrative Agent has received written notice from a Bank or the Company referring to this Agreement describing such Default or Event of Default and stating that such notice is a “notice of default”. If the Administrative Agent receives such a notice, the Administrative Agent shall give prompt notice thereof to the Banks.

9.10    Rights as a Bank. If the Administrative Agent is a Bank, the Administrative Agent shall have the same rights and powers hereunder and under any other Loan Document with respect to its Commitment and its Loans as any Bank and may exercise the same as though it were not the Administrative Agent, and the term “Bank” or “Banks” shall, at any time when the Administrative Agent is a Bank, unless the context otherwise indicates, include the Administrative Agent in its individual capacity. The Administrative Agent and its Affiliates may accept deposits from, lend money to, and generally engage in any kind of trust, debt, equity or

63

709152408 03173762

other transaction, in addition to those contemplated by this Agreement or any other Loan Document, with the Company or any of its Affiliates in which the Company or such Affiliates is not restricted hereby from engaging with any other Person. The Administrative Agent, in its individual capacity, is not obligated to remain a Bank.

9.11    Bank Credit Decision. Each Bank acknowledges that it has, independently and without reliance upon the Administrative Agent, any Co-Lead Arranger, any Issuer or any other Bank and based on the financial statements prepared by the Company and such other documents and information as it has deemed appropriate, made its own credit analysis and decision to enter into this Agreement and the other Loan Documents. Each Bank also acknowledges that it will, independently and without reliance upon the Administrative Agent, any Co-Lead Arranger, any Issuer or any other Bank and based on such documents and information as it shall deem appropriate at the time, continue to make its own credit decisions in taking or not taking action under this Agreement and the other Loan Documents.

9.12    Successor Administrative Agent. The Administrative Agent may resign at any time by giving written notice thereof to the Banks and the Company, such resignation to be effective upon the appointment of a successor Administrative Agent or, if no successor Administrative Agent has been appointed, 45 days after the retiring Administrative Agent gives notice of its intention to resign. If at any time the Person serving as Administrative Agent is a Defaulting Bank, the Administrative Agent may be removed by written notice received by the Administrative Agent from the Majority Banks, such removal to be effective on the date specified by the Majority Banks; provided that the Administrative Agent may not be removed unless the Administrative Agent (in its individual capacity) and any affiliate thereof acting as Issuer is relieved of all of its duties as Issuer pursuant to documentation reasonably satisfactory to such Person on or prior to the date of such removal. Upon any such resignation or removal, the Majority Banks shall have the right to appoint, on behalf of the Company and the Banks, a successor Administrative Agent. If no successor Administrative Agent shall have been so appointed by the Majority Banks within thirty days after the resigning Administrative Agent’s giving notice of its intention to resign, then the resigning Administrative Agent may appoint, on behalf of the Company and the Banks, a successor Administrative Agent. Notwithstanding the previous sentence, the Administrative Agent may at any time without the consent of the Company or any Bank, appoint any of its Affiliates which is a commercial bank as a successor Administrative Agent hereunder. If the Administrative Agent has resigned or been removed and no successor Administrative Agent has been appointed, the Banks may perform all the duties of the Administrative Agent hereunder and the Company shall make all payments in respect of the Obligations to the applicable Bank and for all other purposes shall deal directly with the Banks. No successor Administrative Agent shall be deemed to be appointed hereunder until such successor Administrative Agent has accepted the appointment. Any such successor Administrative Agent shall be a commercial bank having capital and retained earnings of at least $100,000,000. Upon the acceptance of any appointment as Administrative Agent hereunder by a successor Administrative Agent, such successor Administrative Agent shall thereupon succeed to and become vested with all the rights, powers, privileges and duties of the resigning or removed Administrative Agent. Upon the effectiveness of the resignation or removal of the Administrative Agent, the resigning or removed Administrative Agent shall be discharged from its duties and obligations hereunder and under the Loan Documents. After the effectiveness of the resignation or removal of an Administrative Agent, the provisions of this Article IX shall continue in effect for the benefit of such Administrative Agent in respect of any actions taken or omitted to be taken by it while it was acting as the Administrative Agent hereunder and under the

64

709152408 03173762

other Loan Documents. If there is a successor to the Administrative Agent by merger, or the Administrative Agent assigns its duties and obligations to an Affiliate pursuant to this Section 9.12, then the term “Prime Rate” as used in this Agreement shall mean the prime rate, base rate or other analogous rate of the new Administrative Agent.

9.13    Administrative Agent’s and Co-Lead Arrangers’ Fees. The Company agrees to pay to the Administrative Agent and to the Co-Lead Arrangers, for their respective accounts, the fees agreed to by the Company, the Administrative Agent and the Co-Lead Arrangers pursuant to the separate fee letters dated as of April 15, 2014, or as otherwise agreed from time to time.

9.14    Delegation to Affiliates. The Company and the Banks agree that the Administrative Agent may delegate any of its duties under this Agreement to any of its Affiliates. Any such Affiliate (and such Affiliate’s directors, officers, agents and employees) which performs duties in connection with this Agreement shall be entitled to the same benefits of the indemnification, waiver and other protective provisions to which the Administrative Agent is entitled under Articles VIII and IX.

9.15    Other Agents. Neither the Syndication Agent nor the Co-Documentation Agents shall have any right, power, obligation, liability, responsibility or duty under this Agreement other than those applicable to all Banks as such. Without limiting the foregoing, neither the Syndication Agent nor the Co-Documentation Agents shall have or be deemed to have a fiduciary relationship with any Bank. Each Bank hereby makes the same acknowledgments with respect to the Syndication Agent and each Co-Documentation Agent as it makes with respect to the Administrative Agent in Section 9.11.

ARTICLE X

MISCELLANEOUS

10.01    Amendments and Waivers. No amendment or waiver of any provision of this Agreement or any other Loan Document, and no consent with respect to any departure by the Company therefrom, shall be effective unless the same shall be in writing and signed by the Majority Banks (or by the Administrative Agent at the written request of the Majority Banks) and the Company and acknowledged by the Administrative Agent, and then any such waiver or consent shall be effective only in the specific instance and for the specific purpose for which given; provided that no such waiver, amendment, or consent shall (a) without the written approval of each Bank directly affected thereby: (i) increase or extend the Commitment (except pursuant to Section 2.04(b)(B)), or amend or modify the Pro Rata Share, of any Bank (or reinstate any Commitment terminated pursuant toSection 8.02); (ii) postpone or delay any date fixed by this Agreement or any other Loan Document for any payment of principal, interest, fees or other amounts due to the Banks (or any of them) hereunder or under any other Loan Document; or (iii) reduce the principal of, or the rate of interest specified herein on, any Loan, or any fees or other amounts payable hereunder or under any other Loan Document; and (b) without the consent of each Bank: (i) change the percentage of the Commitments or of the aggregate unpaid principal amount of the Loans which is required for the Banks or any of them to take any action hereunder; (ii) amend this Section, the definition of “Majority Banks,” Section 10.10, Article IV, Article IX or any provision herein providing for consent or other action by all Banks; or (iii) release any funds from the LC Collateral Account, except to the extent that such release is expressly permitted hereunder; and provided, further, that (x) no amendment, waiver or consent

65

709152408 03173762

shall, unless in writing and signed by the Administrative Agent in addition to the Majority Banks or all the Banks, as the case may be, affect the rights or duties of the Administrative Agent under this Agreement or any other Loan Document, (y) no amendment of any provision of this Agreement relating to any Issuer shall be effective without the written consent of such Issuer and (z) any Fee Letter may be amended, or rights or privileges thereunder waived, in a writing executed by the respective parties thereto. Notwithstanding anything to the contrary herein, no Defaulting Bank shall have any right to approve or disapprove any amendment, waiver or consent hereunder (and any amendment, waiver or consent which by its terms requires the consent of all Banks or each affected Bank may be effected with the consent of the applicable Banks other than Defaulting Banks), except that (A) the Commitment of any Defaulting Bank may not be increased or extended without the consent of such Bank and (B) any waiver, amendment or modification requiring the consent of all Banks or each affected Bank that by its terms affects any Defaulting Bank disproportionately adversely relative to other affected Banks shall require the consent of such Defaulting Bank.

10.02    Notices.

(a)    Notices Generally. Except as otherwise permitted by Section 2.10 with respect to borrowing notices, all notices, requests and other communications to any party hereunder shall be in writing (including electronic transmission, facsimile transmission or similar writing) and shall be given to such party: (x) in the case of the Company or the Administrative Agent, at its address or facsimile number set forth in Schedule 10.02, (y) in the case of any Bank, at its address or facsimile number set forth in Schedule 10.02 or (z) in the case of any party, at such other address or facsimile number as such party may hereafter specify for the purpose by notice to the Administrative Agent and the Company. Each such notice, request or other communication shall be effective (i) if given by facsimile transmission, when transmitted to the facsimile number specified in this Section and confirmation of receipt is received, (ii) if given by mail, 72 hours after such communication is deposited in the mails with first class postage prepaid, addressed as aforesaid, or (iii) if given by any other means, when delivered (or, in the case of electronic transmission, as provided by Section 10.02(b)) at the address specified in this Section; provided that notices to the Administrative Agent under Article II shall not be effective until received.

(b)    Electronic Communications. Notices and other communications to the Banks and the Issuers hereunder may be delivered or furnished by electronic communication (including e‑mail and Internet or intranet websites) pursuant to procedures approved by the Administrative Agent, provided that the foregoing shall not apply to notices to any Bank or Issuer pursuant to Article II if such Bank or Issuer, as applicable, has notified the Administrative Agent that it is incapable of receiving notices under such Article by electronic communication. The Administrative Agent or the Company may, in its discretion, agree to accept notices and other communications to it hereunder by electronic communications pursuant to procedures approved by it; provided that approval of such procedures may be limited to particular notices or communications.

Unless the Administrative Agent otherwise prescribes, (i) notices and other communications sent to an e-mail address shall be deemed received upon the sender’s receipt of an acknowledgement from the intended recipient (such as by the “return receipt requested” function, as available, return e-mail or other written acknowledgement), and (ii) notices or communications posted to an Internet or intranet website shall be deemed received upon the

66

709152408 03173762

deemed receipt by the intended recipient, at its e-mail address as described in the foregoing clause (i), of notification that such notice or communication is available and identifying the website address therefor; provided that, for both clauses (i) and (ii) above, if such notice, email or other communication is not sent during the normal business hours of the recipient, such notice or communication shall be deemed to have been sent at the opening of business on the next business day for the recipient.

(c)    Change of Address, etc. The Company, the Administrative Agent and any Bank may each change the address or facsimile number for service of notice and other communications by a notice in writing to the other parties hereto.

10.03    No Waiver; Cumulative Remedies. The rights, powers, privileges and remedies of the Administrative Agent, the Banks and the Issuers provided herein or in any other Loan Document are cumulative and not exclusive of any right, power, privilege or remedy provided by law or equity or under any other instrument, document or agreement now existing or hereafter arising. No failure to exercise and no delay in exercising, on the part of the Administrative Agent, any Bank or any Issuer, any right, remedy, power or privilege hereunder, shall operate as a waiver thereof; nor shall any single or partial exercise of any right, remedy, power or privilege hereunder preclude any other or further exercise thereof or the exercise of any other right, remedy, power or privilege.

10.04    Several Obligations; Benefits of this Agreement. The respective obligations of the Banks hereunder are several and not joint and no Bank shall be the partner or agent of any other (except to the extent to which the Administrative Agent is authorized to act as such). The failure of any Bank to perform any of its obligations hereunder shall not relieve any other Bank from any of its obligations hereunder. This Agreement shall not be construed so as to confer any right or benefit upon any Person other than the parties to this Agreement and their respective successors and assigns; provided that the parties hereto expressly agree that the Co-Lead Arrangers shall enjoy the benefits of the provisions of Sections 9.11, 10.05 and 10.21 to the extent specifically set forth therein and shall have the right to enforce such provisions on its own behalf and in its own name to the same extent as if it were a party to this Agreement.

10.05    Expenses; Indemnification. (a) The Company shall reimburse the Administrative Agent and the Co-Lead Arrangers for any reasonable costs, internal charges and out-of-pocket expenses (including Attorney Costs) paid or incurred by the Administrative Agent or the Co-Lead Arrangers in connection with the preparation, negotiation, execution, delivery, syndication, distribution (including via the internet), review, amendment, modification, and administration of the Loan Documents. The Company also agrees to reimburse the Administrative Agent, each Co-Lead Arranger, each Issuer and each Bank for any costs, internal charges and out-of-pocket expenses (including Attorney Costs) paid or incurred by the Administrative Agent, such Co-Lead Arranger, such Issuer or such Bank in connection with the collection and enforcement of the Loan Documents.

(b)    The Company hereby further agrees to indemnify the Administrative Agent, each Co-Lead Arranger, each Issuer, each Bank, their respective Affiliates, and each of their directors, officers, agents and employees against all losses, claims, damages, penalties, judgments, liabilities and expenses (including all expenses of litigation or preparation therefor whether or not the Administrative Agent, any Co-Lead Arranger, any Issuer, any Bank or any Affiliate is a party thereto) which any of them may pay or incur arising out of or relating to this

67

709152408 03173762

Agreement, the other Loan Documents, the transactions contemplated hereby or the direct or indirect application or proposed application of the proceeds of any Loan hereunder except to the extent that they are determined in a final non-appealable judgment by a court of competent jurisdiction to have resulted from the gross negligence or willful misconduct of the party, or the party’s Affiliates, seeking indemnification. The obligations of the Company under this Section 10.05 shall survive the termination of this Agreement.

10.06    Marshalling; Payments Set Aside. None of the Administrative Agent, the Banks or the Issuers shall be under any obligation to marshall any assets in favor of the Company or any other Person or against or in payment of any or all of the Obligations. To the extent that the Company makes a payment to the Administrative Agent, the Banks or the Issuers, or the Administrative Agent, the Banks or the Issuers exercise their right of set-off, and such payment or the proceeds of such set-off or any part thereof are subsequently invalidated, declared to be fraudulent or preferential, set aside or required (including pursuant to any settlement entered into by the Administrative Agent, such Bank or such Issuer in its discretion) to be repaid to a trustee, receiver or any other party, in connection with any Insolvency Proceeding or otherwise, then (a) to the extent of such recovery the obligation or part thereof originally intended to be satisfied shall be revived and continued in full force and effect as if such payment had not been made or such set-off had not occurred, and (b) each Bank severally agrees to pay to the Administrative Agent upon demand its pro rata share of any amount so recovered from or repaid by the Administrative Agent.

10.07    Successors and Assigns. The terms and provisions of the Loan Documents shall be binding upon and inure to the benefit of the Administrative Agent, the Company, the Banks and the Issuers and their respective successors and assigns, except that (i) the Company shall not have the right to assign its rights or obligations under the Loan Documents and (ii) any assignment by any Bank must be made in compliance with Section 10.08. The parties to this Agreement acknowledge that clause (ii) of this Section 10.07 relates only to absolute assignments and does not prohibit assignments creating security interests, including (x) any pledge or assignment by any Bank of all or any portion of its rights under this Agreement and any Note to a Federal Reserve Bank or (y) in the case of a Bank which is a fund, any pledge or assignment of all or any portion of its rights under this Agreement and any Note to its trustee in support of its obligations to its trustee; provided that no such pledge or assignment creating a security interest shall release the transferor Bank from its obligations hereunder unless and until the parties thereto have complied with the provisions of Section 10.08. The Administrative Agent may treat the Person which made any Loan or which holds any Note as the owner thereof for all purposes hereof unless and until such Person complies with Section 10.08; provided that the Administrative Agent may in its discretion (but shall not be required to) follow instructions from the Person which made any Loan or which holds any Note to direct payments relating to such Loan or Note to another Person. Any assignee of the rights to any Loan or any Note agrees by acceptance of such assignment to be bound by all the terms and provisions of the Loan Documents. Any request, authority or consent of any Person, who at the time of making such request or giving such authority or consent is the owner of the rights to any Loan (whether or not a Note has been issued in evidence thereof), shall be conclusive and binding on any subsequent holder or assignee of the rights to such Loan.

10.08    Participations; Assignments, etc. (a) Permitted Participants; Effect. Any Bank may, in the ordinary course of its business and in accordance with applicable law, at any time sell to one or more banks or other entities (“Participants”) participating interests in any Loan

68

709152408 03173762

owing to such Bank, any Note held by such Bank, the Commitment of such Bank or any other interest of such Bank under the Loan Documents. Upon any such sale by a Bank of participating interests to a Participant, such Bank’s obligations under the Loan Documents shall remain unchanged, such Bank shall remain solely responsible to the other parties hereto for the performance of such obligations, such Bank shall remain the owner of its Loans and the holder of any Note issued to it in evidence thereof for all purposes under the Loan Documents, all amounts payable by the Company under this Agreement shall be determined as if such Bank had not sold such participating interests, and the Company and the Administrative Agent shall continue to deal solely and directly with such Bank in connection with such Bank’s rights and obligations under the Loan Documents.

(b)    Voting Rights. Each Bank shall retain the sole right to approve, without the consent of any Participant, any amendment, modification or waiver of any provision of the Loan Documents other than any amendment, modification or waiver which requires the unanimous consent of all Banks under Section 10.01.

(c)    Benefit of Setoff. The Company agrees that each Participant shall be deemed to have the right of setoff provided in Section 10.10 in respect of its participating interest in amounts owing under the Loan Documents to the same extent as if the amount of its participating interest were owing directly to it as a Bank under the Loan Documents; provided that each Bank shall retain the right of setoff provided in Section 10.10 with respect to the amount of participating interests sold to each Participant. The Banks agree to share with each Participant, and each Participant, by exercising the right of setoff provided in Section 10.10, agrees to share with each Bank, any amount received pursuant to the exercise of its right of setoff, such amounts to be shared in accordance with Section 10.10 as if each Participant were a Bank.

(d)    Permitted Assignments. Any Bank may, in the ordinary course of its business and in accordance with applicable law, at any time assign to one or more Eligible Assignees (“Purchasers”) all or any part of its rights and obligations under the Loan Documents. Any assignment shall be made pursuant to a document substantially in the form of Exhibit F or in such other form as may be agreed to by the parties thereto. The consent of the Company and the Administrative Agent (in each case not to be unreasonably withheld or delayed) shall be required prior to an assignment becoming effective with respect to a Purchaser which is not a Bank or an Affiliate thereof; provided that if a Default or an Event of Default has occurred and is continuing, the consent of the Company shall not be required. The consent of each Issuer (not to be unreasonably withheld or delayed) shall be required prior to an assignment becoming effective unless the applicable Purchaser is a Bank. Each such assignment with respect to a Purchaser which is not a Bank or an Affiliate thereof shall (unless each of the Company and the Administrative Agent otherwise consents) be in an amount not less than the lesser of (i) $5,000,000 or (ii) the remaining amount of the assigning Bank’s Commitment (calculated as at the date of such assignment) or outstanding Loans (if such Commitment has been terminated).

(e)    Effect; Effective Date. Upon (i) delivery to the Administrative Agent of a notice of assignment, substantially in the form attached as Annex I to Exhibit F (a “Notice of Assignment”), together with any consents required by Section 10.08(d), and (ii) payment by the assigning Bank of a $4,000 fee to the Administrative Agent for processing such assignment, such assignment shall become effective on the effective date specified in such Notice of Assignment. The Notice of Assignment shall contain a representation by the Purchaser to the effect that none

69

709152408 03173762

of the consideration used to make the purchase of the Commitment and Loans under the applicable assignment agreement constitutes “plan assets” as defined under ERISA and that the rights and interests of the Purchaser in and under the Loan Documents will not be “plan assets” under ERISA. On and after the effective date of such assignment, such Purchaser shall for all purposes be a Bank party to this Agreement and any other Loan Document executed by or on behalf of the Banks and shall have all the rights and obligations of a Bank under the Loan Documents, to the same extent as if it were an original party hereto, and no further consent or action by the Company, the Banks or the Administrative Agent shall be required to release the transferor Bank with respect to the percentage of the Aggregate Commitment and Loans assigned to such Purchaser; provided that, except to the extent otherwise expressly agreed by the affected parties, no assignment by a Defaulting Bank will constitute a waiver or release of any claim of any party hereunder arising from that Bank’s having been a Defaulting Bank. Upon the consummation of any assignment to a Purchaser pursuant to this Section 10.08(e), the transferor Bank, the Administrative Agent and the Company shall, if the transferor Bank or the Purchaser desires that its Loans be evidenced by Notes, make appropriate arrangements so that new Notes or, as appropriate, replacement Notes are issued to such transferor Bank and new Notes or, as appropriate, replacement Notes, are issued to such Purchaser, in each case in principal amounts reflecting their respective Commitments, as adjusted pursuant to such assignment.

(f)    Dissemination of Information. The Company authorizes each Bank to disclose to any Participant or Purchaser or any other Person acquiring an interest in the Loan Documents by operation of law (each a “Transferee”) and any prospective Transferee any and all information in such Bank’s possession concerning the creditworthiness of the Company and its Subsidiaries; provided that each Transferee and prospective Transferee agrees to be bound by Section 10.09 of this Agreement.

(g)    Tax Treatment. If any interest in any Loan Document is transferred to any Transferee which is organized under the laws of any jurisdiction other than the United States or any State thereof, the transferor Bank shall cause such Transferee, concurrently with the effectiveness of such transfer, to comply with the provisions of Section 3.06(g).

10.09    Confidentiality. Each Bank agrees to take and to cause its Affiliates to take normal and reasonable precautions and exercise due care to maintain the confidentiality of all information identified as “confidential” or “secret” by the Company and provided to it by the Company or any Subsidiary, or by the Administrative Agent on the Company’s or such Subsidiary’s behalf, under this Agreement or any other Loan Document, and neither it nor any of its Affiliates shall use any such information other than in connection with or in enforcement of this Agreement and the other Loan Documents or in connection with other business now or hereafter existing or contemplated with the Company or any Subsidiary; except to the extent such information (i) was or becomes generally available to the public other than as a result of disclosure by the Bank, or (ii) was or becomes available on a non-confidential basis from a source other than the Company, provided that such source is not bound by a confidentiality agreement with the Company known to the Bank; provided that any Bank may disclose such information (A) at the request or pursuant to any requirement of any Governmental Authority to which the Bank is subject or in connection with an examination of such Bank by any such authority; (B) pursuant to subpoena or other court process; (C) when required to do so in accordance with the provisions of any applicable Requirement of Law; (D) to the extent reasonably required in connection with any litigation or proceeding to which the Administrative Agent, any Bank or their respective Affiliates may be party; (E) to the extent reasonably required

70

709152408 03173762

in connection with the exercise of any remedy hereunder or under any other Loan Document; (F) to such Bank’s independent auditors and other professional advisors; (G) to any Participant or Assignee, actual or potential, provided that such Person agrees in writing to keep such information confidential to the same extent required of the Banks hereunder; (H) as to any Bank or its Affiliate, as expressly permitted under the terms of any other document or agreement regarding confidentiality to which the Company or any Subsidiary is party or is deemed party with such Bank or such Affiliate; (I) to its Affiliates and to the partners, directors, officers, employees, agents, trustees, administrators, managers, independent auditors and other professional advisors and representatives of such Bank and of such Bank’s Affiliates who are advised of the confidential nature of such information; (J) to the National Association of Insurance Commissioners or any similar organization or any nationally recognized rating agency that requires access to information about such Bank’s investment portfolio in connection with ratings issued with respect to such Bank; and (K) to any direct or indirect contractual counterparty to any swap or derivative transaction relating to the Company and its obligations, provided that such Person agrees in writing to keep such information confidential to the same extent required of the Banks hereunder. Notwithstanding anything herein to the contrary, the Administrative Agent, each Issuer and each Bank may disclose to any Person, without limitation of any kind, the U.S. tax treatment and tax structure of the transactions contemplated hereby and all materials of any kind (including opinions or other tax analyses) that are provided to the Administrative Agent, any Issuer or any Bank relating to such U.S. tax treatment and tax structure.

10.10    Set-off; Ratable Payments. In addition to, and without limitation of, any rights of the Banks under applicable law, if any Event of Default occurs and is continuing, any and all deposits (including all account balances, whether provisional or final and whether or not collected or available) and any other Indebtedness at any time held or owing by any Bank or any Affiliate of any Bank to or for the credit or account of the Company may be offset and applied toward the payment of the Obligations owing to such Bank, whether or not the Obligations, or any part hereof, shall then be due; provided that in the event that any Defaulting Bank shall exercise any such right of setoff, (x) all amounts so set off shall be paid over immediately to the Administrative Agent for further application in accordance with the provisions of Section 2.18 and, pending such payment, shall be segregated by such Defaulting Bank from its other funds and deemed held in trust for the benefit of the Administrative Agent, the Issuers, and the Banks, and (y) the Defaulting Bank shall provide promptly to the Administrative Agent a statement describing in reasonable detail the Obligations owing to such Defaulting Bank as to which it exercised such right of setoff. If any Bank, whether by setoff or otherwise, has payment made to it upon its Loans or its participations in Letters of Credit (other than payments received pursuant to Section 3.01, 3.02, 3.05 or 3.06 and payments made to any Issuer in respect of Reimbursement Obligations so long as the Banks have not funded their participations therein) in a greater proportion than that received by any other Bank, such Bank agrees, promptly upon demand, to purchase a portion of the Outstanding Credit Exposures held by the other Banks so that after such purchase each Bank will hold its Pro Rata Share of the Aggregate Outstanding Credit Exposure. If any Bank, whether in connection with setoff or amounts which might be subject to setoff or otherwise, receives collateral or other protection for its Obligations or such amounts which may be subject to setoff, such Bank agrees, promptly upon demand, to take such action necessary such that all Banks share in the benefits of such collateral ratably in accordance with their respective Pro Rata Shares. In case any such payment is disturbed by legal process, or otherwise, appropriate further adjustments shall be made.

71

709152408 03173762

10.11    Automatic Debits of Fees. With respect to any facility fee, agency fee, arrangement fee, or other fee, or any other cost or expense (including Attorney Costs) due and payable to the Administrative Agent, U.S. Bank or any other Co-Lead Arranger under the Loan Documents, the Company hereby irrevocably authorizes the Administrative Agent and/or U.S. Bank to debit any deposit account of the Company with Administrative Agent and/or U.S. Bank in an amount such that the aggregate amount debited from all such deposit accounts does not exceed such fee or other reasonable cost or expense. If there are insufficient funds in such deposit accounts to cover the amount of the fee or other cost or expense then due, such debits will be reversed (in whole or in part, in the Administrative Agent’s and/or U.S. Bank’s sole discretion) and such amount not debited shall be deemed to be unpaid. No such debit under this Section shall be deemed a set-off.

10.12    Notification of Addresses, Lending Installations, Etc. Each Bank shall promptly notify the Administrative Agent in writing of any changes in the address to which notices to the Bank should be directed, of addresses of any Lending Installation, of payment instructions in respect of all payments to be made to it hereunder and of such other administrative information as the Administrative Agent shall reasonably request.

10.13    Counterparts. This Agreement may be executed in any number of separate counterparts, each of which, when so executed, shall be deemed an original, and all of such counterparts taken together shall be deemed to constitute but one and the same instrument.

10.14    Severability. The illegality or unenforceability of any provision of this Agreement or any instrument or agreement required hereunder shall not in any way affect or impair the legality or enforceability of the remaining provisions of this Agreement or any instrument or agreement required hereunder.

10.15    GOVERNING LAW AND JURISDICTION. (A) THE LOAN DOCUMENTS (OTHER THAN THOSE CONTAINING A CONTRARY EXPRESS CHOICE OF LAW PROVISION) SHALL BE GOVERNED BY, AND CONSTRUED IN ACCORDANCE WITH, THE INTERNAL LAW OF THE STATE OF NEW YORK WITHOUT REGARD TO PRINCIPLES OF CONFLICTS OF LAW (OTHER THAN TITLE 14 OF ARTICLE 5 OF THE NEW YORK GENERAL OBLIGATIONS LAW); PROVIDED THAT THE ADMINISTRATIVE AGENT AND THE BANKS SHALL RETAIN ALL RIGHTS ARISING UNDER FEDERAL LAW.

(B)    ANY LEGAL ACTION OR PROCEEDING WITH RESPECT TO THIS AGREEMENT OR ANY OTHER LOAN DOCUMENT MAY BE BROUGHT IN THE COURTS OF THE STATE OF NEW YORK OR OF THE UNITED STATES FOR THE SOUTHERN DISTRICT OF NEW YORK, AND BY EXECUTION AND DELIVERY OF THIS AGREEMENT, EACH OF THE COMPANY, THE ADMINISTRATIVE AGENT, EACH ISSUER AND EACH BANK CONSENTS, FOR ITSELF AND IN RESPECT OF ITS PROPERTY, TO THE NON-EXCLUSIVE JURISDICTION OF THOSE COURTS. EACH OF THE COMPANY, THE ADMINISTRATIVE AGENT, EACH ISSUER AND EACH BANK IRREVOCABLY WAIVES ANY OBJECTION, INCLUDING ANY OBJECTION TO THE LAYING OF VENUE OR BASED ON THE GROUNDS OF FORUM NON CONVENIENS, WHICH IT MAY NOW OR HEREAFTER HAVE TO THE BRINGING OF ANY ACTION OR PROCEEDING IN SUCH JURISDICTION IN RESPECT OF THIS AGREEMENT OR

72

709152408 03173762

ANY DOCUMENT RELATED HERETO. THE COMPANY, THE ADMINISTRATIVE AGENT, EACH ISSUER AND THE BANKS EACH WAIVE PERSONAL SERVICE OF ANY SUMMONS, COMPLAINT OR OTHER PROCESS, WHICH MAY BE MADE BY ANY OTHER MEANS PERMITTED BY NEW YORK LAW.

(C)    NOTHING HEREIN SHALL LIMIT THE RIGHT OF THE ADMINISTRATIVE AGENT, ANY ISSUER OR ANY BANK TO BRING PROCEEDINGS AGAINST THE COMPANY IN THE COURTS OF ANY OTHER JURISDICTION. ANY JUDICIAL PROCEEDING BY THE COMPANY AGAINST THE ADMINISTRATIVE AGENT, ANY ISSUER OR ANY BANK OR ANY AFFILIATE OF THE ADMINISTRATIVE AGENT, ANY ISSUER OR ANY BANK INVOLVING, DIRECTLY OR INDIRECTLY, ANY MATTER IN ANY WAY ARISING OUT OF, RELATED TO, OR CONNECTED WITH ANY LOAN DOCUMENT SHALL BE BROUGHT ONLY IN A COURT IN NEW YORK, NEW YORK.

10.16    WAIVER OF JURY TRIAL. THE COMPANY, THE BANKS, THE ISSUERS AND THE ADMINISTRATIVE AGENT EACH WAIVE THEIR RESPECTIVE RIGHTS TO A TRIAL BY JURY OF ANY CLAIM OR CAUSE OF ACTION BASED UPON OR ARISING OUT OF OR RELATED TO THIS AGREEMENT, THE OTHER LOAN DOCUMENTS, OR THE TRANSACTIONS CONTEMPLATED HEREBY OR THEREBY, IN ANY ACTION, PROCEEDING OR OTHER LITIGATION OF ANY TYPE BROUGHT BY ANY OF THE PARTIES AGAINST ANY OTHER PARTY OR ANY AGENT-RELATED PERSON, PARTICIPANT OR ASSIGNEE, WHETHER WITH RESPECT TO CONTRACT CLAIMS, TORT CLAIMS, OR OTHERWISE. THE COMPANY, THE BANKS, THE ISSUERS AND THE ADMINISTRATIVE AGENT EACH AGREE THAT ANY SUCH CLAIM OR CAUSE OF ACTION SHALL BE TRIED BY A COURT TRIAL WITHOUT A JURY. WITHOUT LIMITING THE FOREGOING, THE PARTIES FURTHER AGREE THAT THEIR RESPECTIVE RIGHT TO A TRIAL BY JURY IS WAIVED BY OPERATION OF THIS SECTION AS TO ANY ACTION, COUNTERCLAIM OR OTHER PROCEEDING WHICH SEEKS, IN WHOLE OR IN PART, TO CHALLENGE THE VALIDITY OR ENFORCEABILITY OF THIS AGREEMENT OR THE OTHER LOAN DOCUMENTS OR ANY PROVISION HEREOF OR THEREOF. THIS WAIVER SHALL APPLY TO ANY SUBSEQUENT AMENDMENTS, RENEWALS, SUPPLEMENTS OR MODIFICATIONS TO THIS AGREEMENT AND THE OTHER LOAN DOCUMENTS.

10.17    Entire Agreement. This Agreement, together with the other Loan Documents, embodies the entire agreement and understanding among the Company, the Banks, the Issuers and the Administrative Agent, and supersedes all prior or contemporaneous agreements and understandings of such Persons, verbal or written, relating to the subject matter hereof and thereof (other than the Fee Letters).

10.18    Survival of Representations. All representations and warranties of the Company contained in this Agreement shall survive the making of the Credit Extensions herein contemplated.

73

709152408 03173762

10.19    Governmental Regulation. Anything contained in this Agreement to the contrary notwithstanding, no Bank shall be obligated to extend credit to the Company in violation of any limitation or prohibition provided by any applicable statute or regulation.

10.20    Numbers of Documents. All statements, notices, closing documents, and requests hereunder shall be furnished to the Administrative Agent with sufficient counterparts so that the Administrative Agent may furnish one to each of the Banks.

10.21    Nonliability of Banks. The Company agrees that neither the Administrative Agent, any Co-Lead Arranger, the Syndication Agent, any Co-Documentation Agent, any Issuer nor any Bank shall have liability to the Company (whether sounding in tort, contract or otherwise) for losses suffered by the Company in connection with, arising out of, or in any way related to, the transactions contemplated and the relationship established by the Loan Documents, or any act, omission or event occurring in connection therewith, unless it is determined in a final non-appealable judgment by a court of competent jurisdiction that such losses resulted from the gross negligence or willful misconduct of the party from which recovery is sought. Neither the Administrative Agent, any Co-Lead Arranger, the Syndication Agent, any Co-Documentation Agent, any Issuer nor any Bank, nor any of their respective Affiliates, or any director, officer, agent or employee of any of the foregoing shall have any liability with respect to, and the Company hereby waives, releases and agrees not to sue for, any special, indirect consequential or punitive damages suffered by the Company in connection with, arising out of, or in any way related to the Loan Documents or the transactions contemplated thereby.

10.22    No Advisory or Fiduciary Responsibility. In connection with all aspects of each transaction contemplated hereby (including in connection with any amendment, waiver or other modification hereof or of any other Loan Document), the Company acknowledges and agrees, and acknowledges its Affiliates’ understanding, that: (a)(i) the arranging and other services regarding this Agreement provided by the Administrative Agent and the Co-Lead Arrangers are arm’s-length commercial transactions between the Company and its Affiliates, on the one hand, and the Administrative Agent and the Co-Lead Arrangers, on the other hand, (ii) the Company has consulted its own legal, accounting, regulatory and tax advisors to the extent it has deemed appropriate and (iii) the Company is capable of evaluating, and understands and accepts, the terms, risks and conditions of the transactions contemplated hereby and by the other Loan Documents; (b)(i) the Administrative Agent and each Co-Lead Arranger each is and has been acting solely as a principal and, except as expressly agreed in writing by the relevant parties, has not been, is not, and will not be acting as an advisor, agent or fiduciary for the Company or any of its Affiliates, or any other Person and (ii) neither the Administrative Agent nor any Co-Lead Arranger has any obligation to the Company or any of its Affiliates with respect to the transactions contemplated hereby except those obligations expressly set forth herein and in the other Loan Documents; and (c) the Administrative Agent and the Co-Lead Arrangers and their respective Affiliates may be engaged in a broad range of transactions that involve interests that differ from those of the Company and its Affiliates, and neither the Administrative Agent nor any Co-Lead Arranger has any obligation to disclose any of such interests to the Company or its Affiliates. To the fullest extent permitted by law, the Company hereby waives and releases any claims that it may have against the Administrative Agent and the Co-Lead Arrangers with respect to any breach or alleged breach of agency or fiduciary duty in connection with any aspect of any transaction contemplated hereby.

74

709152408 03173762

10.23    USA Patriot Act Notice. Each Bank that is subject to the Act (as hereinafter defined) and the Administrative Agent (for itself and not on behalf of any Bank) hereby notifies the Company that pursuant to the requirements of the USA Patriot Act (Title III of Pub. L. 107-56 (signed into law October 26, 2001)) (the “Act”), it is required to obtain, verify and record information that identifies the Company, which information includes the name and address of the Company and other information that will allow such Bank or the Administrative Agent, as applicable, to identify the Company in accordance with the Act.

[SIGNATURES BEGIN ON THE FOLLOWING PAGE]

75

709152408 03173762

IN WITNESS WHEREOF, the parties hereto have caused this Agreement to be duly executed and delivered by their proper and duly authorized officers as of the day and year first above written.

CENTENNIAL ENERGY HOLDINGS, INC.
	/s/ Doran N. Schwartz
By:
Name:	Doran N. Schwartz
Title:	Vice President and Chief Financial Officer

[Signature page to the Centennial Energy Holdings, Inc.

Credit Agreement]

U.S. BANK NATIONAL ASSOCIATION, as
Administrative Agent, as an Issuer and as a Bank
By:	/s/ John Prigge
Name:	John Prigge
Title:	Vice President

[Signature page to the Centennial Energy Holdings, Inc.

Credit Agreement]

709152408 03173762

THE BANK OF TOKYO-MITSUBISHI UFJ,
LTD., NEW YORK BRANCH, as Syndication
Agent, as an Issuer and as a Bank
By:	/s/ Paul V. Farrell
Name:	Paul V. Farrell
Title:	Director

[Signature page to the Centennial Energy Holdings, Inc.

Credit Agreement]

709152408 03173762

WELLS FARGO BANK, NATIONAL
ASSOCIATION, as a Co-Documentation Agent, as
an Issuer and as a Bank
By:	/s/ Nick Brokke
Name:	Nick Brokke
Title:	Vice President

[Signature page to the Centennial Energy Holdings, Inc.

Credit Agreement]

709152408 03173762

JPMORGAN CHASE BANK, N.A., as a Co-
Documentation Agent, as an Issuer and as a Bank
By:	/s/ Justin Martin
Name:	Justin Martin
Title:	Authorized Officer

709152408 03173762

ROYAL BANK OF CANADA, as a Co-
Documentation Agent, as an Issuer and as a Bank
By:	/s/ Rahul D. Shah
Name:	Rahul D. Shah
Title:	Authorized Signatory

[Signature page to the Centennial Energy Holdings, Inc.

Credit Agreement]

709152408 03173762

TORONTO DOMINION (NEW YORK) LLC, as a
as a Bank
	/s/ Marie Fernandes
By:
Name:	MARIE FERNANDES
Title:	AUTHORIZED SIGNATORY

[Signature page to the Centennial Energy Holdings, Inc.

Credit Agreement]

709152408 03173762

THE BANK OF NOVA SCOTIA, as a Bank
	/s/ Thane Rattew
By:
Name:	Thane Rattew
Title:	Managing Director

[Signature page to the Centennial Energy Holdings, Inc.

Credit Agreement]

709152408 03173762

CANADIAN IMPERIAL BANK OF
COMMERCE, NEW YORK BRANCH, as a Bank
By:	/s/ Robert Casey
Name:	Robert Casey
Title:	Authorized Signatory
By:	/s/ Anju Abraham
Name:	Anju Abraham
Title:	Authorized Signatory

[Signature page to the Centennial Energy Holdings, Inc.

Credit Agreement]

709152408 03173762

KEYBANK, NATIONAL ASSOCIATION, as a
Bank
By:	/s/ Keven D Smith
Name:	Keven D Smith
Title:	Senior Vice President

[Signature page to the Centennial Energy Holdings, Inc.

Credit Agreement]

709152408 03173762

SUNTRUST BANK, as a Bank
	/s/ Yann Pirio
By:
Name:	Yann Pirio
Title:	Managing Director

[Signature page to the Centennial Energy Holdings, Inc.

Credit Agreement]

709152408 03173762

PNC BANK, NATIONAL ASSOCIATION, as a
Bank
By	/s/ Jon R. Hinard
Name:	Jon R. Hinard
Title:	Senior Vice President

[Signature page to the Centennial Energy Holdings, Inc.

Credit Agreement]

709152408 03173762

GOLDMAN SACHS BANK USA, as a Bank
	/s/ Mark Walton
By:
Name:	Mark Walton
Title:	Authorized Signatory

[Signature page to the Centennial Energy Holdings, Inc.

Credit Agreement]

709152408 03173762

SCHEDULE 2.01

COMMITMENTS

AND PRO RATA SHARES

Bank	Commitment	Pro Rata Share
U.S. Bank National Association	$65,000,000	10.000000000%
The Bank of Tokyo-Mitsubishi UFJ, Ltd., New York Branch	$65,000,000	10.000000000%
JPMorgan Chase Bank, N.A.	$65,000,000	10.000000000%
Wells Fargo Bank, National Association	$65,000,000	10.000000000%
Royal Bank Of Canada	$65,000,000	10.000000000%
Toronto Dominion (New York) LLC	$55,000,000	8.461538462%
The Bank of Nova Scotia	$55,000,000	8.461538461%
Canadian Imperial Bank of Commerce, New York Agency	$55,000,000	8.461538461%
KeyBank, National Association	$45,000,000	6.923076923%
SunTrust Bank	$45,000,000	6.923076923%
PNC Bank, National Association	$35,000,000	5.384615385%
Goldman Sachs Bank USA	$35,000,000	5.384615385%
TOTAL	$650,000,000	100.000000000%

Schedule 2.01 - Page 1

Commitments and Pro Rata Shares

709152408 03173762

SCHEDULE 2.16

EXISTING LETTERS OF CREDIT

LC Number	Issue Date	Expiry Date	Beneficiary	Amount
None

709152408 03173762

SCHEDULE 5.15

SUBSIDIARIES AND MINORITY INTERESTS

I.Company's Subsidiaries

1. Alaska Basic Industries, Inc., an Alaska corporation

2. Ames Sand & Gravel, Inc., a North Dakota corporation

3. Anchorage Sand and Gravel Company, Inc., an Alaska corporation

4. Baldwin Contracting Company, Inc., a California corporation

5. BEH Electric Holdings, LLC, a Nevada limited liability company

6. Bell Electrical Contractors, Inc., a Missouri corporation

7. BMH Mechanical Holdings, LLC, a Nevada limited liability company

8. Bombard Electric, LLC, a Nevada limited liability company

9. Bombard Mechanical, LLC, a Nevada limited liability company

10. Capital Electric Construction Company, Inc., a Kansas corporation

11. Capital Electric Line Builders, Inc., a Kansas corporation

12. Centennial Energy Resources International, Inc., a Delaware corporation

13. Centennial Energy Resources LLC, a Delaware limited liability company

14. Centennial Holdings Capital LLC, a Delaware limited liability company

15. Central Oregon Redi-Mix, L.L.C., an Oregon limited liability company

16. Concrete, Inc., a California corporation

17. Connolly-Pacific Co., a California corporation

18. Continental Line Builders, Inc., a Delaware corporation

19. Coordinating and Planning Services, Inc., a Delaware corporation

20. Desert Fire Holdings, Inc., a Nevada corporation

21. Desert Fire Protection, a Nevada Limited Partnership

22. Desert Fire Protection, Inc., a Nevada corporation

23. Desert Fire Protection, LLC, a Nevada limited liability company

24. D S S Company, a California corporation

25. E.S.I., Inc., an Ohio corporation

26. Fairbanks Materials, Inc., an Alaska corporation

27. Fidelity Exploration & Production Company, a Delaware corporation

28. Fidelity Oil Co., a Delaware corporation

29. Frebco, Inc., an Ohio corporation

30. FutureSource Capital Corp., a Delaware corporation

31. Granite City Ready Mix, Inc., a Minnesota corporation

32. Hamlin Electric Company, a Colorado corporation

33. Harp Engineering, Inc., a Montana corporation

34. Hawaiian Cement, a Hawaii partnership

35. ILB Hawaii, Inc., a Hawaii corporation

36. Independent Fire Fabricators, LLC, a Nevada limited liability company

37. International Line Builders, Inc., a Delaware corporation

38. InterSource Insurance Company, a Vermont corporation

709152408 03173762

39. Jebro Incorporated, an Iowa corporation

40. JTL Group, Inc., a Montana corporation

41. JTL Group, Inc., a Wyoming corporation

42. Kent’s Oil Service, a California corporation

43. Knife River Corporation, a Delaware corporation

44. Knife River Corporation - North Central, a Minnesota corporation

45. Knife River Corporation - Northwest, an Oregon corporation

46. Knife River Corporation - South, a Texas corporation

47. Knife River Dakota, Inc., a Delaware corporation

48. Knife River Hawaii, Inc., a Delaware corporation

49. Knife River Marine, Inc., a Delaware corporation

50. Knife River Midwest, LLC, a Delaware limited liability company

51. KRC Holdings, Inc., a Delaware corporation

52. LME&U Holdings, LLC, a Nevada limited liability company

53. Lone Mountain Excavation & Utilities, LLC, a Nevada limited liability company

54. Loy Clark Pipeline Co., an Oregon corporation

55. LTM, Incorporated, an Oregon corporation

56. MDU Brasil Ltda., a Brazil limited liability company

57. MDU Construction Services Group, Inc., a Delaware corporation

58. MDU Industrial Services, Inc., a Delaware corporation

59. MDU Resources International LLC, a Delaware limited liability company

60. MDU Resources Luxembourg I LLC S.a.r.l., a Luxembourg limited liability company

61. MDU Resources Luxembourg II LLC S.a.r.l., a Luxembourg limited liability company

62. MDU United Construction Solutions, Inc., a Delaware corporation

63. Midland Technical Crafts, Inc., a Delaware corporation

64. Nevada Solar Solutions, LLC, a Delaware limited liability company

65. Northstar Materials, Inc., a Minnesota corporation

66. Oregon Electric Construction, Inc., an Oregon corporation

67. Pouk & Steinle, Inc., a California corporation

68. Prairielands Energy Marketing, Inc., a Delaware corporation

69. Rocky Mountain Contractors, Inc., a Montana corporation

70. USI Industrial Services, Inc., a Delaware corporation,

71. The Wagner Group, Inc., a Delaware corporation

72. Wagner Industrial Electric, Inc., a Delaware corporation

73. The Wagner-Smith Company, an Ohio corporation

74. Wagner-Smith Equipment Co., a Delaware corporation

75. Wagner-Smith Pumps & Systems, Inc., an Ohio corporation

76. Warner Enterprises, Inc., a Nevada corporation

77. WBI Canadian Pipeline, Ltd., a Canadian corporation

78. WBI Energy, Inc., a Delaware corporation

79. WBI Energy Midstream, LLC, a Colorado limited liability company

80. WBI Energy Midstream Utah, LLC, a Delaware limited liability company

81. WBI Energy Services, Inc., a Delaware corporation

82. WBI Energy Transmission, Inc., a Delaware corporation

83. WBI Holdings, Inc., a Delaware corporation

84. WHC, Ltd., a Hawaii corporation

709152408 03173762

II.    Affiliates

1. Dakota Prairie Refining, LLC, a Delaware limited liability company

2. Empresa Catarinense de Transmissão de Energia S.A., a Brazil corporation

709152408 03173762

SCHEDULE 7.01

CERTAIN PERMITTED LIENS

Liens on certain assets of Bitter Creek Pipelines, LLC, under the Agreement for the Construction, Ownership and Operation of the Belfield Gas Plant and Related Facilities Stark and Billings Counties, North Dakota

Any Liens created under any Loan Document, as such term is defined in (1) the Term Loan Agreement, dated March 31, 2014, between the Company and The Bank of Tokyo-Mitsubishi UFJ, Ltd., New York Branch and (2) the Term Loan Agreement, dated April 2, 2014, between the Company and JPMorgan Chase Bank, N.A.; provided that if the Company grants any Lien under either such Agreement, the Company shall grant an equal and ratable Lien to the Administrative Agent to secure the Company’s obligations under this Agreement.

Schedule 7.01 - Page 1

Existing Liens

709152408 03173762

SCHEDULE 7.12

EXISTING INDEBTEDNESS

(As of May 8, 2014)

Centennial Energy Holdings, Inc.	Amount Outstanding
Prudential	$	297,000,000
Term Loan Agreements	$	250,000,000
Note Purchase Agreements	$	461,714,000
Letter of Credit Agreement	$	28,965,410
Commercial Paper	$	185,000,000
Knife River Corporation
Various Other Debt	$	127,000
MDU Construction Services Group, Inc. Various Other Debt	$	266,000
WBI Holdings, Inc.
WBI Prudential Insurance Company	$	100,000,000
Fidelity Exploration & Production Company Various Capital Leases	$	1,315,000
Dakota Prairie Refining, LLC
Term Loan Agreement	$	72,000

Schedule 7.12 - Page 1

Existing Indebtedness

709152408 03173762

SCHEDULE 7.13

AGREEMENTS RESTRICTING

SUBSIDIARY DIVIDENDS

None.

Schedule 7.13 - Page 1

Agreements Restricting

Subsidiary Dividends

709152408 03173762

SCHEDULE 10.02

LENDING INSTALLATIONS; ADDRESSES FOR NOTICES

CENTENNIAL ENERGY HOLDINGS, INC.

Centennial Energy Holdings, Inc.

PO Box 5650

1200 West Century Avenue

Bismarck, ND 58506-5650

Attention: Mr. Doran N. Schwartz

Vice President and Chief Financial Officer

Telephone: (701) 530-1750

Facsimile: (701) 530-1731

U.S. BANK NATIONAL ASSOCIATION,

as Administrative Agent

U.S. Bank National Association

1420 Fifth Avenue, 9th Floor

PD-WA-T9IN

Seattle, WA 98101

Attn: Agency Services

Brenda Miller-Meyers

Telephone: (206) 344-2888 or (877) 653-3117

Facsimile: (206) 587-7022

U.S. BANK NATIONAL ASSOCIATION,

as a Bank

U.S. Bank National Association

461 Fifth Avenue, 8th Floor

New York, NY 10017

Attn: Paul Morrison

Telephone: (646) 935-4538

Facsimile: (646) 935-4552

E-mail: paul.morrison@usbank.com

Schedule 10.02 - Page 1

Notices, etc.

709152408 03173762

EXHIBIT A

FORM OF COMPLIANCE CERTIFICATE

To: The Administrative Agent and the Banks that are parties to the Credit Agreement described below

This Compliance Certificate is furnished pursuant to the Third Amended and Restated Credit Agreement dated as of May 8, 2014 (as amended, modified, renewed or extended from time to time, the “Credit Agreement”) among Centennial Energy Holdings, Inc. (the “Company”), the Banks party thereto, U.S. Bank National Association, as Administrative Agent, JPMorgan Chase Bank, N.A., Wells Fargo Bank, National Association and Royal Bank of Canada, as Co-Documentation Agents, and The Bank of Tokyo-Mitsubishi UFJ, Ltd., as Syndication Agent. Unless otherwise defined herein, capitalized terms used in this Compliance Certificate have the meanings ascribed thereto in the Credit Agreement.

THE UNDERSIGNED HEREBY CERTIFIES THAT:

1. I am the duly elected _________ of the Company;

2. I have reviewed the terms of the Agreement and I have made, or have caused to be made under my supervision, a detailed review of the transactions and conditions of the Company and its Subsidiaries during the accounting period covered by the attached financial statements;

3. The examinations described in paragraph 2 did not disclose, and I have no knowledge of, the existence of any condition or event which constitutes a Default or Event of Default during or at the end of the accounting period covered by the attached financial statements or as of the date of this Certificate, except as set forth below; and

4. Schedule I attached hereto sets forth financial data and computations evidencing the Company’s compliance with certain covenants of the Agreement, all of which data and computations are true, complete and correct.

Described below are the exceptions, if any, to paragraph 3 listing, in detail, the nature of the condition or event, the period during which it has existed and the action which the Company has taken, is taking, or proposes to take with respect to each such condition or event:

Exhibit A ‑ Page 1

Compliance Certificate

709152408 03173762

The foregoing certifications, together with the computations set forth in Schedule I hereto and the financial statements delivered with this Certificate in support hereof, are made and delivered on ________, 20__.

_________________________________

Exhibit A ‑ Page 2

Compliance Certificate

709152408 03173762

SCHEDULE I TO COMPLIANCE CERTIFICATE

Compliance as of __________, 20__ with

Various provisions of the Credit Agreement

I.	Section 7.01 - Liens
	A.	Aggregate amount of all Securitization Obligations secured by Liens	$_________
	B.	Maximum permitted secured Securitization Obligations under Item I.A	$75,000,000
	C.	Other Indebtedness secured by Liens permitted by Section 7.01(p) of the Credit Agreement	$_________
	D.	Maximum permitted secured Indebtedness under Item I.C	$35,000,000
II.	Section 7.02 - Dispositions of Assets
	A.	Aggregate value of all assets sold by the Company and its Subsidiaries pursuant to Sections 7.02(i) through (iv) of the Credit Agreement	$_________
	B.	Maximum permitted value of disposed assets under Item II.A (20% of total consolidated assets)	$_________
III.	Section 7.04 - Investments
	A.	Aggregate amount of guarantees of indebtedness of DPR	$_________
	B.	Maximum permitted guarantees under Item III.A	$[1]75,000,000
	C.	Aggregate amount of other investments in, Guaranty Obligations in respect of, or advances, loans, extensions of credit or capital contributions to, any Project Finance Subsidiary permitted by Section 7.04(g)(ii) of the Credit Agreement	$_________
	D.	Maximum permitted investments, etc. under Item III.C	$100,000,000
	E.	Other investments permitted by Section 7.04(i) of the Credit Agreement	$_________

Exhibit A ‑ Page 3

Compliance Certificate

709152408 03173762

	F.	Maximum permitted investments under Item III.E (20% of Consolidated Net Worth)		$_________
	G.	Investments in capital stock, equity or long-term fixed income securities of any Subsidiary (other than a Project Finance Subsidiary) that is not a Wholly-Owned Subsidiary, or otherwise undertaken pursuant to the Investment Policy		$_________
	H.	Maximum permitted investments under Item III.G		$100,000,000
IV.	Section 7.08 - Restricted Payments
	A.	Cash dividends or other distributions made by [COMPANY/APPLICABLE SUBSIDIARY] to its equity holders; purchases, redemptions or other acquisitions of shares of its capital stock or other equity interests or warrants, rights or options to acquire any such shares or other equity interests		$_________
	B.	Maximum permitted dividends, etc. under Item IV.A (Maximum Annual RP Amount) 1		$_________
V.	Section 7.11 ‑ Company Capitalization Ratio
	A.	Total Debt
		1.	Indebtedness for borrowed money	$_________
		2.	Redeemable Preferred Stock	$_________
		3.	Deferred purchase price of property/services	$_________
		4.	Surety Instrument reimbursement/payment obligations (excluding 80% of contingent liability on unsecured surety bonds)	$_________
		5.	Other indebtedness evidenced by instruments	$_________
		6.	Conditional sale/title retention agreements	$_________
		7.	Capital leases	$_________

___________________________

¹ Maximum Annual RP Amount means, for any fiscal year, 100% of the consolidated net income after taxes of the Company or Subsidiary, as the case may be, during the immediately preceding fiscal year and computed on a cumulative consolidated basis, excluding non-cash writedowns.

Exhibit A ‑ Page 4

Compliance Certificate

709152408 03173762

		8.	Net liabilities under Swap Contracts (excluding Covered Contracts)	$_________
		9.	Other indebtedness secured by property	$_________
		10.	Securitization Obligations	$_________
		11.	Guaranty Obligations	$_________
		12.	Total Debt (sum of Items V.A.1 through V.A.11, on a consolidated basis, without duplication)	$_________
	B.	Total Capitalization
		1.	Total stockholders’ or owners’ equity of the Company (excluding Accounting Standards Codification 815-20-25-104 adjustments in respect of Covered Contracts)	$_________
		2.	Total Debt (Item V.A.l2)	$_________
		3.	Total Capitalization (sum of Item V.B.1 plus Item V.B.2)	$_________
	C.	Capitalization Ratio (Item V.A.12 / Item V.B.3)		______%
	D.	Maximum Capitalization Ratio permitted		65%
VI.	Section 7.12 ‑ Subsidiary Indebtedness
	A.	Sum of (i) the aggregate stated amount of Letters of Credit issued jointly for the account of the Company and Centennial International plus (ii) the aggregate amount of intercompany loans and other advances made by the Company or any Subsidiary (other than any International Subsidiary) to the International Subsidiaries		$_____________
	B.	Maximum permitted Indebtedness under Item VI.A		$100,000,000
	C.	Aggregate outstanding principal amount of Indebtedness of the International Subsidiaries (including with respect to intercompany loans and advances (other than any loan or advance made by an International Subsidiary) and Letters of Credit)		$_____________

Exhibit A ‑ Page 5

Compliance Certificate

709152408 03173762

D.	Maximum permitted Indebtedness under Item VI.C (10% of the result of (a) Consolidated Net Worth less (b) the aggregate book value of consolidated intangible assets of the Company and its Subsidiaries)	$_____________
E.	Indebtedness of Williston Basin Interstate Pipeline Company	$_____________
F.	Maximum permitted Indebtedness under Item VI.E	$500,000,000
G	Other Subsidiary Indebtedness not permitted by Sections 7.12(i) through (vi) of the Credit Agreement	$_____________
H.	Maximum permitted Indebtedness under Item VI.G	$50,000,000

Exhibit A ‑ Page 6

Compliance Certificate

709152408 03173762

EXHIBIT B-1

[LETTERHEAD OF CENTENNIAL ENERGY HOLDINGS, INC.]

May 8, 2014

U.S. Bank National Association

as Administrative Agent,

and the Banks listed

on Schedule 1 attached hereto

Ladies and Gentlemen:

I am Counsel for Centennial Energy Holdings, Inc., a Delaware corporation (the “Company”),and in such capacity I am familiar with (a) the negotiation, preparation, execution and delivery of the Third Amended and Restated Credit Agreement dated as of May 8, 2014 (the “Agreement”) among the Company, various financial institutions (the “Banks”), U.S. Bank National Association, as Administrative Agent, JPMorgan Chase Bank, N.A., Wells Fargo Bank, National Association and Royal Bank of Canada, as Co-Documentation Agents, and The Bank of Tokyo-Mitsubishi UFJ, LTD., as Syndication Agent, and (b) the negotiation, preparation, execution and delivery of the other Loan Documents listed on Schedule 2 attached hereto (together with the Agreement, the “Loan Documents”). This opinion is furnished to you pursuant to Section 4.01(a)(7) of the Agreement and at the instruction of the Company. All capitalized terms used but not otherwise defined herein have the respective meanings assigned to them in the Agreement.

For the purpose of rendering the opinions contained herein, I have examined and reviewed the Agreement and the other Loan Documents. I have also examined the originals, or copies certified to my satisfaction, of the Certificate of Incorporation and By‑Laws of the Company, resolutions adopted by the Board of Directors of the Company authorizing the execution, delivery and performance by the Company of the Agreement and the other Loan Documents, and such other corporate records of the Company and agreements, instruments and other documents as I have deemed necessary as a basis for the opinions expressed below. In my examination, I have assumed the genuineness of all signatures, other than the signatures of the Company on the Loan Documents, the legal capacity of natural persons, the authenticity of all documents submitted to me as originals and the conformity with original documents of all documents submitted to me as certified or photostatic copies. I have also assumed, with your consent, the due execution and delivery, pursuant to due authorization, of the Agreement by all parties thereto other than the Company and the validity and binding effect of the Agreement upon such parties.

As to any facts that I did not independently establish or verify, I have relied without independent investigation upon statements, representations and certificates of officers of the

1190306.3 082503 1932C 03173762

709152408 03173762

Company and, as to the matters addressed therein, upon certificates or communications from public officials. As used herein, the phrase “to my knowledge” with respect to the existence or absence of facts is intended to signify that, while I have made no specific inquiry or other independent examination to determine the existence or absence of such facts, no factual information has come to my attention which causes me to believe that such facts are not accurate.

Based on and subject to the foregoing and upon such investigation as I have deemed necessary, and subject to the qualifications set forth below, it is my opinion that:

1.The Company is a corporation duly organized, validly existing and in good standing under the laws of the State of Delaware.

2.The Company has the corporate power and authority to execute, deliver and perform its obligations under the Agreement and the other Loan Documents, and has all requisite corporate power and authority, licenses and permits to own its assets and to carry on its business as currently conducted and as contemplated to be conducted by the Agreement.

3.The execution, delivery and performance by the Company of the Agreement and each of the other Loan Documents have been duly authorized by all necessary corporate action, and each of the Agreement and the other Loan Documents has been duly executed and delivered by the Company.

4.     The execution, delivery and performance by the Company of the Agreement and of the other Loan Documents do not and will not(a) breach or constitute a default under (i) its Certificate of Incorporation or Bylaws, each as amended to date, (ii) to my knowledge, any decree, injunction, order, writ, or other action of any Governmental Authority applicable to it or its assets, or (iii) to my knowledge, any other Contractual Obligation to which it is a party or by which any of its properties may be bound, (b) to my knowledge, result in or require the creation of any Lien (other than for the benefit of the Banks and the Issuers) upon or with respect to any of its assets, or (c) violate any Requirement of Law.

5.     No consent, approval, exemption, waiver, license, authorization or other action by or filing with any Governmental Authority is or will be required in connection with the due execution, delivery and performance by the Company of the Agreement or any of the other Loan Documents.

6.There is no pending or, to my knowledge, threatened or contemplated action, suit, claim, dispute or proceeding in arbitration or before any court or Governmental Authority against the Company or any of its assets, or with respect to any Plan, (a) which purports to affect or pertain to the Agreement or any other Loan Document, or any of the transactions contemplated thereby, or (b) if determined adversely to the Company, would reasonably be expected to have a Material Adverse Effect.

2

709152408 03173762

7. Neither the consent of the sole stockholder of the Company nor the consent of any holder of any Indebtedness of the Company is or will be required as a condition to the validity or enforceability of the Agreement or any other Loan Document or any of the transactions contemplated in the Agreement.

8. The choice of law provision set forth in the Agreement and the other Loan Documents wherein the parties agree that the laws of the State of New York shall govern and control the terms of the Agreement and the other Loan Documents is a valid, effective and enforceable choice of law under the laws of the State of North Dakota and would be upheld and enforced by courts of the State of North Dakota and by the federal courts sitting and applying the laws of the State of North Dakota, at least to the extent that New York law on the particular issue is not found to be contrary to North Dakota public policy.

9. If, notwithstanding the provisions of Section 10.15 of the Agreement, North Dakota law were held to be applicable to the Agreement and the other Loan Documents, each such document will constitute the legal, valid and binding obligation of the Company enforceable in accordance with its respective terms, subject to the effect of any applicable bankruptcy, insolvency, reorganization, moratorium or other similar laws affecting creditors’ rights generally and of general principles of equity (regardless of whether applied in a proceeding in equity or at law), except that I express no opinion as to (a) Section 10.10 of the Agreement, (b) the enforceability of rights to indemnity under federal or state securities laws, or (c) the enforceability of waivers by parties of their respective rights and remedies under law.

10. The Company is not subject to regulation under any state public utilities code or any other state statute or regulation limiting its ability to incur indebtedness.

The opinions expressed herein are limited to the laws of the State of North Dakota and the General Corporation Law of the State of Delaware. I express no opinion as to any law, rule, regulation, ordinance, code or similar provision of law of any county, municipality or similar political subdivision of the State of North Dakota or any agency or instrumentality thereof. I am a member of the North Dakota and Minnesota Bars and do not hold myself out as an expert on the laws of any other jurisdiction. Insofar as the opinions expressed herein relate to the laws of the State of New York, the General Corporation Law of the State of Delaware, or the federal laws of the United States of America, I have relied with your consent on the opinion, of even date herewith, of Cohen Tauber Spievack & Wagner P.C.

This opinion is intended solely for your use and the use of your counsel, and is rendered solely in connection with the Agreement and the other Loan Documents, and without my written consent may not be (a) relied upon by you for any other purpose, or (b) relied upon by any other person or entity for any purpose. The opinions expressed above are limited to the law and facts in effect on the date hereof. I disclaim any obligation to advise you of facts, circumstances, events or developments which hereafter may be brought to my attention and which might alter, affect or modify the opinions expressed herein.

3

709152408 03173762

I hereby consent to reliance by the Administrative Agent and the Banks now or hereafter parties to the Agreement on the opinions expressed herein.

Very truly yours,

Paul K. Sandness

General Counsel and Secretary

4

709152408 03173762

Schedule 1

• U.S. Bank National Association

• The Bank of Tokyo-Mitsubishi UFJ, Ltd.

• JPMorgan Chase Bank, N.A.

• Wells Fargo Bank, National Association

• Toronto Dominion (New York) LLC

• Royal Bank of Canada

• Canadian Imperial Bank of Commerce, New York Agency

• KeyBank, National Association

• SunTrust Bank

• PNC Bank, National Association

• The Bank of Nova Scotia

• Goldman Sachs Bank USA

5

709152408 03173762

Schedule 2

None

Exhibit B-1 - Page 6

Form of Opinion of Paul K. Sandness

709152408 03173762

EXHIBIT B‑2

LETTERHEAD OF Cohen Tauber Spievack & Wagner P.C.

May 8, 2014

U.S. Bank National Association,

as Administrative Agent, and the Banks

listed on Schedule 1 attached hereto

Ladies and Gentlemen:

We have acted as special counsel for Centennial Energy Holdings, Inc., a Delaware corporation (the “Company”), in connection with (a) the negotiation, preparation, execution and delivery of the Third Amended and Restated Credit Agreement dated as of May 8, 2014 the “Agreement”) among the Company, various financial institutions (the “Banks”), U.S. Bank National Association, as Administrative Agent, JPMorgan Chase Bank, N.A., Wells Fargo Bank, National Association and Royal Bank of Canada, as Co-Documentation Agents, and The Bank of Tokyo-Mitsubishi UFJ, Ltd., as Syndication Agent, and (b) the negotiation, preparation, execution and delivery of the other Loan Documents listed on Schedule 2 attached hereto (together with the Agreement, the “Loan Documents”). This opinion is furnished to you pursuant to Section 4.01(a)(7) of the Agreement and at the instruction of the Company. All capitalized terms used but not otherwise defined herein have the meanings assigned to them in the Agreement.

For the purpose of rendering the opinions contained herein, we have examined and reviewed the Agreement and the other Loan Documents. We have also examined the originals, or copies certified to our satisfaction, of the Certificate of Incorporation and By‑Laws of the Company, resolutions adopted by the Board of Directors of the Company authorizing the execution, delivery and performance by the Company of the Agreement and the Loan Documents, and such other corporate records of the Company and agreements, instruments and other documents as we have deemed necessary as a basis for the opinions expressed below. In our examination, we have assumed the genuineness of all signatures, the legal capacity of natural persons, the authenticity of all documents submitted to us as originals and the conformity with original documents of all documents submitted to us as certified or photostatic copies. We have also assumed, with your consent, the due execution and delivery, pursuant to due authorization, of the Agreement by all parties thereto other than the Company and the validity and binding effect of the Agreement upon such parties. As to any facts that we did not independently establish or verify, we have relied without independent investigation upon statements, representations, and certificates of officers of the Company and as to the matters addressed therein, upon certificates or communications from public officials.

Further, for the purposes of rendering the opinion expressed in numbered paragraph 9 below, we have relied on the representations and warranties of the Company contained in

{00219286.DOC; 3}

420 Lexington Avenue | New York, New York 10170 | Phone: 212.586.5800 | Fax: 212.586.5095 | www.ctswlaw.com

709152408 03173762

Section 5.08 of the Agreement and have assumed compliance by the Company with the covenants of the Company contained in Sections 6.11 and 7.06 of the Agreement.

Based on and subject to the foregoing and upon such investigation as we have deemed necessary, and subject to the qualifications set forth below, it is our opinion that:

1.The Company is a corporation duly organized, validly existing and in good standing under the laws of the State of Delaware.

2.The Company has the corporate power and authority to execute, deliver and perform its obligations under the Agreement and the other Loan Documents.

3.The execution, delivery and performance by the Company of the Agreement and each of the other Loan Documents have been duly authorized by all necessary corporate action, and each of the Agreement and the other Loan Documents has been duly executed and delivered by the Company.

4.The execution, delivery and performance by the Company of the Agreement and of the other Loan Documents do not and will not (a) breach or constitute a default under its Certificate of Incorporation or Bylaws, each as amended to date, or (b) violate any Requirement of Law.

5.No consent, approval, exemption, waiver, license, authorization or other action by or filing with any Governmental Authority is or will be required in connection with the due execution, delivery and performance by the Company of the Agreement or any other Loan Document.

6.Each of the Agreement and each of the other Loan Documents constitutes a legal, valid and binding obligation of the Company enforceable in accordance with its respective terms, subject to the effect of any applicable bankruptcy, insolvency, reorganization, moratorium or other similar laws affecting creditors’ rights generally and of general principles of equity (regardless of whether applied in a proceeding in equity or at law), except that we express no opinion as to (a) Section 10.10 of the Agreement, (b) the enforceability of rights to indemnity under federal or state securities laws, or (c) the enforceability of waivers by parties of their respective rights and remedies under law.

7.The consent of the sole stockholder of the Company is not, nor will it be, required as a condition to the validity or enforceability of the Agreement or any other Loan Document or any of the transactions contemplated in the Agreement.

8.The transaction contemplated by the Agreement and the other Loan Documents is not usurious under applicable law.

9.The consummation of the transactions contemplated by the Agreement and the other Loan Documents will not violate Regulation T, U or X of the Board of Governors of the Federal Reserve System.

709152408 03173762

10.The choice of law provision set forth in the Agreement and the other Loan Documents wherein the parties agree that the laws of the State of New York shall govern and control the terms of the Agreement and the other Loan Documents is a valid, effective and enforceable choice of law under the laws of the State of New York and would be upheld and enforced by courts of the State of New York and by the federal courts sitting and applying the laws of the State of New York.

11.The Company is not an “investment company” or a company “controlled” by an “investment company” within the meaning of the Investment Company Act of 1940, as amended. The Company is not subject to regulation under the Federal Power Act, the Interstate Commerce Act or any other federal statute or regulation limiting its ability to incur indebtedness.

This opinion is limited to the laws of the State of New York, the General Corporation Law of the State of Delaware and the federal laws of the United States of America. We express no opinion as to the laws of any other jurisdiction.

This opinion is intended solely for your use and the use of your counsel, and is rendered solely in connection with the Agreement and the other Loan Documents, and without our written consent may not be (a) relied upon by you for any other purpose, or (b) relied upon by any other person or entity for any purpose, except that Paul K. Sandness may rely on the opinions expressed herein in rendering to you his opinion of even date herewith.

The opinions expressed above are limited to the law and facts in effect on the date hereof. We disclaim any obligation to advise you of facts, circumstances, events, or developments which hereafter may be brought to our attention and which might alter, affect, or modify the opinions expressed herein.

We hereby consent to reliance by the Administrative Agent and the Banks now or hereafter parties to the Agreement on the opinions expressed herein.

Very truly yours,

Cohen Tauber Spievack

& Wagner P.C.

709152408 03173762

Schedule 1

• U.S. Bank National Association

• The Bank of Tokyo-Mitsubishi UFJ, Ltd.,

• JPMorgan Chase Bank, N.A.

• Wells Fargo Bank, National Association

• Toronto Dominion (New York) LLC

• Royal Bank of Canada

• Canadian Imperial Bank of Commerce, New York Agency

• KeyBank, National Association

• SunTrust Bank

• PNC Bank, National Association

• Goldman Sachs Bank USA

• The Bank of Nova Scotia

Exhibit B-1 - Page 4

Form of Opinion of Cohen Tauber Spievack & Wagner P.C.

709152408 03173762

Schedule 2

None

Exhibit B-2 - Page 5

Form of Opinion of Cohen Tauber Spievack & Wagner P.C.

709152408 03173762

EXHIBIT C

FORM OF NOTE

_________________, 20__

Centennial Energy Holdings, Inc., a Delaware corporation (the “Company”), promises to pay, on the Termination Date (as defined in the Agreement referred to below), to the order of _________(the “Bank”) in immediately available funds at the main office of U.S. Bank National Association, as Administrative Agent, the aggregate unpaid principal amount of all Loans made by the Bank to the Company pursuant to the Agreement referred to below, together with interest on the unpaid principal amount hereof at the rates and on the dates set forth in the Agreement.

The Bank shall, and is hereby authorized to, record on the schedule attached hereto, or to otherwise record in accordance with its usual practice, the date and amount of each Loan and the date and amount of each principal payment hereunder.

This Note is one of the Notes issued pursuant to, and is entitled to the benefits of, the Third Amended and Restated Credit Agreement dated as of May 8, 2014 among the Company, the financial institutions party thereto, U.S. Bank National Association, individually and as Administrative Agent, JPMorgan Chase Bank, N.A., Wells Fargo Bank, National Association and Royal Bank of Canada, as Co-Documentation Agents, and The Bank of Tokyo-Mitsubishi UFJ, Ltd., as Syndication Agent (as amended or otherwise modified from time to time, the “Agreement”). Reference is hereby made to the Agreement for a statement of the terms and conditions under which this Note may be prepaid or its maturity date accelerated. Capitalized terms used but not otherwise defined herein have the respective meanings attributed to them in the Agreement.

CENTENNIAL ENERGY HOLDINGS, INC.

By

Name:

Title:

Exhibit C - Page 1

Note

709152408 03173762

SCHEDULE OF LOANS AND PAYMENTS OF PRINCIPAL

TO

NOTE

CENTENNIAL ENERGY HOLDINGS, INC.,

DATED _____________________, 20__

Date Principal Amount of Loan Maturity of Interest  Period Principal Amount Paid Unpaid Balance

Exhibit C ‑ Page 2

Note

709152408 03173762

EXHIBIT D

FORM OF MONEY TRANSFER INSTRUCTIONS

To: U.S. Bank National Association, as Administrative Agent

(the “Administrative Agent”) under the Credit Agreement

described below.

Re: Third Amended and Restated Credit Agreement dated as of May 8, 2014 (as amended, modified, renewed or extended from time to time, the “Credit Agreement”) among Centennial Energy Holdings, Inc. (the “Company”), the Banks party thereto and the Administrative Agent. Capitalized terms used herein and not otherwise defined herein shall have the meanings assigned thereto in the Credit Agreement.

The Administrative Agent is specifically authorized and directed to act upon the following standing money transfer instructions with respect to the proceeds of Advances or other extensions of credit from time to time until receipt by the Administrative Agent of a specific written revocation of such instructions by the Company; provided, however, that the Administrative Agent may otherwise transfer funds as hereafter directed in writing by the Company in accordance with Section 10.02 of the Credit Agreement or based on any telephonic notice made in accordance with Section 2.10 of the Credit Agreement.

Customer/Account Name				Centennial Energy Holdings, Inc.
Transfer Funds To		U.S. Bank National Association
For Account No.	XXXXXXXXXXXX
Reference/Attention To			Doug Mahowald
Responsible Officer (Customer Representative)					Date
Doug Mahowald
(Please Print)					Signature
Bank Officer Name					Date
(Please Print)					Signature

(Deliver Completed Form to Credit Support Staff For Immediate Processing)

Exhibit D ‑ Page 1

Money Transfer Instructions

709152408 03173762

EXHIBIT E-1

FORM OF U.S. TAX COMPLIANCE CERTIFICATE

(For Foreign Banks That Are Not Partnerships For U.S. Federal Income Tax Purposes)

Reference is hereby made to the Third Amended and Restated Credit Agreement dated as of May 8, 2014 (as amended, modified, renewed or extended from time to time, the “Credit Agreement”) among Centennial Energy Holdings, Inc. (the “Company”), the financial institutions party thereto and U.S. Bank National Association, as Administrative Agent.

Pursuant to the provisions of Section 3.06 of the Credit Agreement, the undersigned hereby certifies that (i) it is the sole record and beneficial owner of the Loans (as well as any Note evidencing such Loans) in respect of which it is providing this certificate, (ii) it is not a bank within the meaning of Section 881(c)(3)(A) of the Code, (iii) it is not a ten percent shareholder of the Company within the meaning of Section 871(h)(3)(B) of the Code and (iv) it is not a controlled foreign corporation related to the Company as described in Section 881(c)(3)(C) of the Code.

The undersigned has furnished the Administrative Agent and the Company with a certificate of its non-U.S. Person status on IRS Form W-8BEN. By executing this certificate, the undersigned agrees that (1) if the information provided on this certificate changes, the undersigned shall promptly so inform the Company and the Administrative Agent, and (2) the undersigned shall have at all times furnished the Company and the Administrative Agent with a properly completed and currently effective certificate in either the calendar year in which each payment is to be made to the undersigned, or in either of the two calendar years preceding such payments.

Unless otherwise defined herein, terms defined in the Credit Agreement and used herein shall have the meanings given to them in the Credit Agreement.

[NAME OF BANK]
By:
	Name:
	Title:

Date: ________ __, 20[ ]

Exhibit E ‑ Page 1

Form of Audit Letter

709152408 03173762

EXHIBIT E-2

FORM OF U.S. TAX COMPLIANCE CERTIFICATE

(For Foreign Participants That Are Not Partnerships For U.S. Federal Income Tax Purposes)

Reference is hereby made to the Third Amended and Restated Credit Agreement dated as of May 8, 2014 (as amended, modified, renewed or extended from time to time, the “Credit Agreement”) among Centennial Energy Holdings, Inc. (the “Company”), the financial institutions party thereto and U.S. Bank National Association, as Administrative Agent.

Pursuant to the provisions of Section 3.06 of the Credit Agreement, the undersigned hereby certifies that (i) it is the sole record and beneficial owner of the participation in respect of which it is providing this certificate, (ii) it is not a bank within the meaning of Section 881(c)(3)(A) of the Code, (iii) it is not a ten percent shareholder of the Company within the meaning of Section 871(h)(3)(B) of the Code, and (iv) it is not a controlled foreign corporation related to the Company as described in Section 881(c)(3)(C) of the Code.

The undersigned has furnished its participating Bank with a certificate of its non-U.S. Person status on IRS Form W-8BEN. By executing this certificate, the undersigned agrees that (1) if the information provided on this certificate changes, the undersigned shall promptly so inform such Bank in writing, and (2) the undersigned shall have at all times furnished such Bank with a properly completed and currently effective certificate in either the calendar year in which each payment is to be made to the undersigned, or in either of the two calendar years preceding such payments.

Unless otherwise defined herein, terms defined in the Credit Agreement and used herein shall have the meanings given to them in the Credit Agreement.

[NAME OF PARTICIPANT]
By:
	Name:
	Title:

Date: ________ __, 20[ ]

Exhibit E ‑ Page 2

Form of U.S Tax Compliance Certificate

709152408 03173762

EXHIBIT E-3

FORM OF U.S. TAX COMPLIANCE CERTIFICATE

(For Foreign Participants That Are Partnerships For U.S. Federal Income Tax Purposes)

Reference is hereby made to the Third Amended and Restated Credit Agreement dated as of May 8, 2014 (as amended, modified, renewed or extended from time to time, the “Credit Agreement”) among Centennial Energy Holdings, Inc. (the “Company”), the financial institutions party thereto and U.S. Bank National Association, as Administrative Agent.

Pursuant to the provisions of Section 3.06 of the Credit Agreement, the undersigned hereby certifies that (i) it is the sole record owner of the participation in respect of which it is providing this certificate, (ii) its direct or indirect partners/members are the sole beneficial owners of such participation, (iii) with respect such participation, neither the undersigned nor any of its direct or indirect partners/members is a bank extending credit pursuant to a loan agreement entered into in the ordinary course of its trade or business within the meaning of Section 881(c)(3)(A) of the Code, (iv) none of its direct or indirect partners/members is a ten percent shareholder of the Company within the meaning of Section 871(h)(3)(B) of the Code and (v) none of its direct or indirect partners/members is a controlled foreign corporation related to the Company as described in Section 881(c)(3)(C) of the Code.

The undersigned has furnished its participating Bank with IRS Form W-8IMY accompanied by one of the following forms from each of its partners/members that is claiming the portfolio interest exemption: (i) an IRS Form W-8BEN or (ii) an IRS Form W-8IMY accompanied by an IRS Form W-8BEN from each of such partner’s/member’s beneficial owners that is claiming the portfolio interest exemption. By executing this certificate, the undersigned agrees that (1) if the information provided on this certificate changes, the undersigned shall promptly so inform such Bank and (2) the undersigned shall have at all times furnished such Bank with a properly completed and currently effective certificate in either the calendar year in which each payment is to be made to the undersigned, or in either of the two calendar years preceding such payments.

Unless otherwise defined herein, terms defined in the Credit Agreement and used herein shall have the meanings given to them in the Credit Agreement.

[NAME OF PARTICIPANT]
By:
	Name:

Exhibit E ‑ Page 3

Form of U.S Tax Compliance Certificate

709152408 03173762

Title:

Date: ________ __, 20[ ]

Exhibit E ‑ Page 4

Form of U.S Tax Compliance Certificate

709152408 03173762

EXHIBIT E-4

FORM OF U.S. TAX COMPLIANCE CERTIFICATE

(For Foreign Banks That Are Partnerships For U.S. Federal Income Tax Purposes)

Reference is hereby made to the Third Amended and Restated Credit Agreement dated as of May 8, 2014 (as amended, modified, renewed or extended from time to time, the “Credit Agreement”) among Centennial Energy Holdings, Inc. (the “Company”), the financial institutions party thereto and U.S. Bank National Association, as Administrative Agent.

Pursuant to the provisions of Section 3.06 of the Credit Agreement, the undersigned hereby certifies that (i) it is the sole record owner of the Loans (as well as any Note evidencing such Loans) in respect of which it is providing this certificate, (ii) its direct or indirect partners/members are the sole beneficial owners of such Loans (as well as any Note evidencing such Loan(s)), (iii) with respect to the extension of credit pursuant to this Credit Agreement or any other Loan Document, neither the undersigned nor any of its direct or indirect partners/members is a bank extending credit pursuant to a loan agreement entered into in the ordinary course of its trade or business within the meaning of Section 881(c)(3)(A) of the Code, (iv) none of its direct or indirect partners/members is a ten percent shareholder of the Company within the meaning of Section 871(h)(3)(B) of the Code and (v) none of its direct or indirect partners/members is a controlled foreign corporation related to the Company as described in Section 881(c)(3)(C) of the Code.

The undersigned has furnished the Administrative Agent and the Company with IRS Form W-8IMY accompanied by one of the following forms from each of its partners/members that is claiming the portfolio interest exemption: (i) an IRS Form W-8BEN or (ii) an IRS Form W-8IMY accompanied by an IRS Form W-8BEN from each of such partner’s/member’s beneficial owners that is claiming the portfolio interest exemption. By executing this certificate, the undersigned agrees that (1) if the information provided on this certificate changes, the undersigned shall promptly so inform the Company and the Administrative Agent, and (2) the undersigned shall have at all times furnished the Company and the Administrative Agent with a properly completed and currently effective certificate in either the calendar year in which each payment is to be made to the undersigned, or in either of the two calendar years preceding such payments.

Unless otherwise defined herein, terms defined in the Credit Agreement and used herein shall have the meanings given to them in the Credit Agreement.

[NAME OF BANK]
By:
	Name:
	Title:

Date: ________ __, 20[ ]

Exhibit E ‑ Page 5

Form of U.S Tax Compliance Certificate

709152408 03173762

Exhibit E ‑ Page 6

Form of U.S Tax Compliance Certificate

709152408 03173762

EXHIBIT F

FORM OF ASSIGNMENT AGREEMENT

This Assignment Agreement (this “Assignment”) is dated as of the Effective Date set forth below and is entered into by and between [Insert name of Assignor] (the “Assignor”) and [Insert name of Assignee] (the “Assignee”). Capitalized terms used but not defined herein shall have the respective meanings given to them in the Third Amended and Restated Credit Agreement identified below (as amended, the “Credit Agreement”), receipt of a copy of which is hereby acknowledged by the Assignee. The Standard Terms and Conditions set forth in Annex 1 attached hereto are hereby agreed to and incorporated herein by reference and made a part of this Assignment as if set forth herein in full.

For an agreed consideration, the Assignor hereby irrevocably sells and assigns to the Assignee, and the Assignee hereby irrevocably purchases and assumes from the Assignor, subject to and in accordance with the Standard Terms and Conditions and the Credit Agreement, as of the Effective Date inserted by the Administrative Agent as contemplated below:  (i) all of the Assignor’s rights and obligations in its capacity as a Bank under the Credit Agreement and any other documents or instruments delivered pursuant thereto to the extent related to the amount and percentage interest identified below of all of such outstanding rights and obligations of the Assignor under the respective facilities identified below (including without limitation any letters of credit, bankers’ acceptances and guarantees included in such facilities); and (ii) to the extent permitted to be assigned under applicable law, all claims, suits, causes of action and any other right of the Assignor (in its capacity as a Bank) against any Person, whether known or unknown, arising under or in connection with the Credit Agreement, any other document or instrument delivered pursuant thereto or the loan transactions governed thereby or in any way based on or related to any of the foregoing, including, but not limited to, contract claims, tort claims, malpractice claims, statutory claims and all other claims at law or in equity related to the rights and obligations sold and assigned pursuant to clause (i) above (the rights and obligations sold and assigned pursuant to clauses (i) and (ii) above being referred to herein collectively as the “Assigned Interest”). Such sale and assignment is without recourse to the Assignor and, except as expressly provided in this Assignment, without representation or warranty by the Assignor.

1.	Assignor:
2.	Assignee:
		[and is an Affiliate/Approved Fund of [identify Bank] ]
3.	Borrower:	Centennial Energy Holdings, Inc.
4.	Administrative Agent:	U.S. Bank National Association, as administrative agent under the Credit Agreement
5.	Credit Agreement:	The Third Amended and Restated Credit Agreement dated as of May 8, 2014 among Centennial Energy Holdings, Inc., the Banks

Exhibit F ‑ Page 1

Assignment Agreement

709152408 03173762

		parties thereto and U.S. Bank National Association, as Administrative Agent
6.	Assigned Interest:

Aggregate Amount of Commitment/Loans for all Banks	Amount of Commitment/Loans Assigned	Percentage Assigned of Commitment/Loans
$	$	%
$	$	%
$	$	%

7.	Effective Date: _____________ ___, 20___ [TO BE INSERTED BY
ADMINISTRATIVE AGENT AND WHICH SHALL BE THE EFFECTIVE DATE OF RECORDATION OF TRANSFER IN THE REGISTER THEREFOR.]

Exhibit F ‑ Page 2

Assignment Agreement

709152408 03173762

The terms set forth in this Assignment are hereby agreed to:

ASSIGNOR

[NAME OF ASSIGNOR]

By:

Title:

ASSIGNEE

[NAME OF ASSIGNEE]

By:

Title:

[Consented to and] Accepted:

U.S. BANK NATIONAL ASSOCIATION, as Administrative Agent

By

Title:

[Consented to:]

CENTENNIAL ENERGY HOLDINGS, INC.

By

Title:

Exhibit F ‑ Page 3

Assignment Agreement

709152408 03173762

ANNEX 1

STANDARD TERMS AND CONDITIONS FOR

ASSIGNMENT AGREEMENT

1.Representations and Warranties.

1.1Assignor. The Assignor (a) represents and warrants that (i) it is the legal and beneficial owner of the Assigned Interest, (ii) the Assigned Interest is free and clear of any lien, encumbrance or other adverse claim, (iii) it has full power and authority, and has taken all action necessary, to execute and deliver this Assignment and to consummate the transactions contemplated hereby and (iv) it is [not] a Defaulting Bank; and (b) assumes no responsibility with respect to (i) any statements, warranties or representations made in or in connection with the Credit Agreement or any other Loan Document, (ii) the execution, legality, validity, enforceability, genuineness, sufficiency or value of the Loan Documents or any collateral thereunder, (iii) the financial condition of the Borrower, any of its Subsidiaries or Affiliates or any other Person obligated in respect of any Loan Document, or (iv) the performance or observance by the Borrower, any of its Subsidiaries or Affiliates or any other Person of any of their respective obligations under any Loan Document.

1.2.Assignee. The Assignee (a) represents and warrants that (i) it has full power and authority, and has taken all action necessary, to execute and deliver this Assignment and to consummate the transactions contemplated hereby and to become a Bank under the Credit Agreement, (ii) it meets all requirements of an Eligible Assignee under the Credit Agreement (subject to such consents, if any, as may be required under the Credit Agreement), (iii) from and after the Effective Date, it shall be bound by the provisions of the Credit Agreement as a Bank thereunder and, to the extent of the Assigned Interest, shall have the obligations of a Bank thereunder, (iv) it is sophisticated with respect to decisions to acquire assets of the type represented by the Assigned Interest and either it, or the Person exercising discretion in making its decision to acquire the Assigned Interest, is experienced in acquiring assets of such type, (v) it has received a copy of the Credit Agreement, and has received or has been accorded the opportunity to receive copies of the most recent financial statements delivered pursuant to Section 6.01 thereof, as applicable, and such other documents and information as it deems appropriate to make its own credit analysis and decision to enter into this Assignment and to purchase the Assigned Interest, (vi) it has, independently and without reliance upon the Administrative Agent or any other Bank and based on such documents and information as it has deemed appropriate, made its own credit analysis and decision to enter into this Assignment and to purchase the Assigned Interest, and (vii) attached to the Assignment is any documentation required to be delivered by it pursuant to the terms of the Credit Agreement, duly completed and executed by the Assignee; and (b) agrees that (i) it will, independently and without reliance on the Administrative Agent, the Assignor or any other Bank, and based on such documents and information as it shall deem appropriate at the time, continue to make its own credit decisions in taking or not taking action under the Loan Documents, and (ii) it will perform in accordance with their terms all of the obligations which by the terms of the Loan Documents are required to be performed by it as a Bank.

Exhibit F ‑ Page 4

Assignment Agreement

709152408 03173762

2.Payments. From and after the Effective Date, the Administrative Agent shall make all payments in respect of the Assigned Interest (including payments of principal, interest, fees and other amounts) to the Assignor for amounts which have accrued to but excluding the Effective Date and to the Assignee for amounts which have accrued from and after the Effective Date. Notwithstanding the foregoing, the Administrative Agent shall make all payments of interest, fees or other amounts paid or payable in kind from and after the Effective Date to the Assignee.

3.General Provisions. This Assignment shall be binding upon, and inure to the benefit of, the parties hereto and their respective successors and permitted assigns. This Assignment may be executed in any number of counterparts, which together shall constitute one instrument. Delivery of an executed counterpart of a signature page of this Assignment by telecopy shall be effective as delivery of a manually executed counterpart of this Assignment. This Assignment shall be governed by, and construed in accordance with, the law of the State of New York.

Exhibit F ‑ Page 5

Assignment Agreement

709152408 03173762

EXHIBIT G

FORM OF

INCREASE REQUEST

_________________________, 20___

U.S. Bank National Association, as Administrative Agent

under the Credit Agreement referred to below

Ladies/Gentlemen:

Please refer to the Third Amended and Restated Credit Agreement dated as of May 8, 2014 among Centennial Energy Holdings, Inc. (the “Company”), various financial institutions and U.S. Bank National Association, as Administrative Agent (as amended, modified, extended or restated from time to time, the “Credit Agreement”). Capitalized terms used but not defined herein have the respective meanings set forth in the Credit Agreement.

In accordance with Section 2.04(b)(B) of the Credit Agreement, the Company hereby requests an increase in the Aggregate Commitment from $__________ to $__________. Such increase shall be made by [increasing the Commitment of ____________ from $________ to $________] [adding _____________ as a Bank under the Credit Agreement with a Commitment of $____________] as set forth in the letter attached hereto. Such increase shall be effective three Business Days after the date that the Administrative Agent accepts the letter attached hereto or such other date as is agreed among the Company, the Administrative Agent and the [increasing] [new] Bank.

Very truly yours,

CENTENNIAL ENERGY HOLDINGS, INC.

By:

Name:

Title:

Exhibit G ‑ Page 1

Increase Request

709152408 03173762

ANNEX I TO EXHIBIT G

[Date]

U.S. Bank National Association, as Administrative Agent

under the Credit Agreement referred to below

Ladies/Gentlemen:

Please refer to the letter dated __________, 20__ from Centennial Energy Holdings, Inc. (the “Company”) requesting an increase in the Aggregate Commitment from $__________ to $__________ pursuant to Section 2.04(b)(B) of the Third Amended and Restated Credit Agreement dated as of May 8, 2014 among the Company, various financial institutions and U.S. Bank National Association, as Administrative Agent (as amended, modified, extended or restated from time to time, the “Credit Agreement”). Capitalized terms used but not defined herein have the respective meanings set forth in the Credit Agreement.

The undersigned hereby confirms that it has agreed to increase its Commitment under the Credit Agreement from $__________ to $__________ effective on the date which is three Business Days after the acceptance hereof by the Administrative Agent or on such other date as may be agreed among the Company, the Administrative Agent and the undersigned.

Very truly yours,

[NAME OF INCREASING BANK]

By:

Title:

Accepted as of

_________, ____

U.S. BANK NATIONAL ASSOCIATION, as Administrative Agent

By:

Name:

Title:

Exhibit G ‑ Page 2

Increase Request

709152408 03173762

ANNEX II TO EXHIBIT G

[Date]

U.S. Bank National Association, as Administrative Agent

under the Credit Agreement referred to below

Ladies/Gentlemen:

Please refer to the letter dated __________, 20___ from Centennial Energy Holdings, Inc. (the “Company”) requesting an increase in the Aggregate Commitment from $__________ to $__________ pursuant to Section 2.04(b)(B) of the Third Amended and Restated Credit Agreement dated as of May 8, 2014 among the Company, various financial institutions and U.S. Bank National Association, as Administrative Agent (as amended, modified, extended or restated from time to time, the “Credit Agreement”). Capitalized terms used but not defined herein have the respective meanings set forth in the Credit Agreement.

The undersigned hereby confirms that it has agreed to become a Bank under the Credit Agreement with a Commitment of $__________ effective on the date which is three Business Days after the acceptance hereof, and consent hereto, by the Administrative Agent or on such other date as may be agreed among the Company, the Administrative Agent and the undersigned.

The undersigned (a) acknowledges that it has received a copy of the Credit Agreement and the Schedules and Exhibits thereto, together with copies of the most recent financial statements delivered by the Company pursuant to the Credit Agreement, and such other documents and information as it has deemed appropriate to make its own credit and legal analysis and decision to become a Bank under the Credit Agreement; and (b) agrees that it will, independently and without reliance upon the Administrative Agent or any other Bank and based on such documents and information as it shall deem appropriate at the time, continue to make its own credit and legal decisions in taking or not taking action under the Credit Agreement.

The undersigned represents and warrants that (i) it is duly organized and existing and it has full power and authority to take, and has taken, all action necessary to execute and deliver this letter and to become a Bank under the Credit Agreement; and (ii) no notices to, or consents, authorizations or approvals of, any Person are required (other than any already given or obtained) for its due execution and delivery of this letter and the performance of its obligations as a Bank under the Credit Agreement.

The undersigned agrees to execute and deliver such other instruments, and take such other actions, as the Administrative Agent may reasonably request in connection with the transactions contemplated by this letter.

The following administrative details apply to the undersigned:

(A)Notice Address:

Legal name: __________________________

Exhibit G ‑ Page 3

Increase Request

709152408 03173762

Address: _______________________________

_______________________________

_______________________________

Attention: _____________________________

Telephone: (___) _______________________

Facsimile: (___) ______________________

(B)Payment Instructions:

Account No.: ___________________________

At: ___________________________

___________________________

___________________________

Reference: ___________________________

Attention: ___________________________

The undersigned acknowledges and agrees that, on the date on which the undersigned becomes a Bank under the Credit Agreement as set forth in the second paragraph hereof, the undersigned will be bound by the terms of the Credit Agreement as fully and to the same extent as if the undersigned were an original Bank under the Credit Agreement.

Very truly yours,

[NAME OF NEW BANK]

By:

Title:

Exhibit G ‑ Page 4

Increase Request

709152408 03173762

Accepted and consented to as of

______________, 20___

U.S. BANK NATIONAL ASSOCIATION,

as Administrative Agent

By:

Name:

Title:

Exhibit G ‑ Page 5

Increase Request

709152408 03173762

EXHIBIT H

FORM OF BORROWING NOTICE

__________, 20___

To:U.S. Bank National Association, as

Administrative Agent

Re: Third Amended and Restated Credit Agreement dated as of May 8, 2014 (as amended or otherwise modified from time to time, the “Agreement”; capitalized terms used but not otherwise defined herein have the respective meanings assigned to them in the Agreement) among Centennial Energy Holdings, Inc. (the “Company”), various financial instutions and U.S. Bank National Association, as Administrative Agent

Pursuant to Section 2.02(c) of the Agreement, the Company gives you irrevocable notice of the Advance specified below:

(i)    the Borrowing Date of such Advance shall be _________, 20__;

(ii)    the aggregate amount of such Advance shall equal $___________;

(iii)    such Advance shall be a [Base Rate][Eurodollar Rate] Advance; and

(iv)    the Interest Period with respect to such Advance shall be [_____] months.

The Company certifies that the following statements are true on the date hereof, and will be true on the date of the proposed Advance, before and after giving effect thereto and to the application of the proceeds therefrom:

(a)the representations and warranties of the Company contained in Article V of the Agreement are true and correct in all material respects as though made on and as of the date of such Advance (except to the extent such representations and warranties expressly refer to an earlier date, in which case they are true and correct as of such earlier date);

(b)no Default or Event of Default exists or would result from such Advance; and

(c) the sum of (i) the aggregate stated amount of Letters of Credit issued jointly for the account of the Company and Centennial International plus (ii) the aggregate amount of intercompany loans and other advances made by the Company or any Subsidiary (other than any International Subsidiary) to the International Subsidiaries does not exceed $100,000,000.

Exhibit H ‑ Page 6

Borrowing Notice

709152408 03173762

Exhibit H ‑ Page 7

Borrowing Notice

709152408 03173762

CENTENNIAL ENERGY HOLDINGS, INC.

By:

Name:

Title:

Exhibit H ‑ Page 8

Borrowing Notice

709152408 03173762

EX-10.(A)

INSTRUMENT OF AMENDMENT TO THE

MDU RESOURCES GROUP, INC.

401(k) RETIREMENT PLAN

The MDU Resources Group, Inc. 401(k) Retirement Plan (as amended and restated March 1, 2011) (the “K-Plan”), is hereby further amended, effective January 1, 2014, unless otherwise indicated as follows:

1. By replacing the table in Section D-1-2 Eligibility to Share in the Profit Sharing Feature of Supplement D-1, Provisions Relating to the Profit Sharing Feature for certain Participating Affiliates, in its entirety, with the following:

Participating Affiliate	Current Effective Date (Original Effective Date)2
Anchorage Sand & Gravel Company, Inc. (excluding President)	January 1, 1999
Baldwin Contracting Company, Inc.	January 1, 1999
Capital Electric Line Builders, Inc.1	January 1, 2014
Cascade Natural Gas Corporation	January 1, 2011 (July 2, 2007)
Concrete, Inc.	January 1, 2001
Connolly-Pacific Co.	January 1, 2007
DSS Company	January 1, 2004 (July 8, 1999)
E.S.I., Inc.	January 1, 2008 (January 1, 2003)
Fairbanks Materials, Inc.	May 1, 2008
Granite City Ready Mix, Inc.	June 1, 2002
Great Plains Natural Gas Co.	January 1, 2008

1

Participating Affiliate	Current Effective Date (Original Effective Date)2
Hawaiian Cement (non-union employees hired after December 31, 2005)	January 1, 2009
Intermountain Gas Company	January 1, 2011
Jebro Incorporated	November 1, 2005
Kent’s Oil Service4	January 1, 2007
Knife River Corporation - Northwest (the Central Oregon Division, f/k/a HTS)	January 1, 2010 (January 1, 1999)
Knife River Corporation - Northwest (the Southern Idaho Division)	January 1, 2010 (January 1, 2006)
Knife River Corporation - Northwest (the Southern Oregon Division)	January 1, 2012
Knife River Corporation - Northwest (the Spokane Division)	January 1, 2010 (January 1, 2006)
Knife River Corporation - Northwest (the Western Oregon Division)	January 1, 2012
Knife River Corporation - South (f/k/a Young Contractors, Inc.)	January 1, 2008 (January 1, 2007)
LTM, Incorporated	January 1, 2003
Montana-Dakota Utilities Co. (including union employees)	January 1, 2008
Oregon Electric Construction, Inc.3	March 7, 2011
Wagner Industrial Electric, Inc.	January 1, 2008
Wagner Smith Equipment Co.	January 1, 2008 (July 1, 2000)

2

Participating Affiliate	Current Effective Date (Original Effective Date)2
WBI Energy, Inc.1/3	May 1, 2012
WBI Energy Midstream, LLC1/3	July 1, 2012 (January 1, 2001)
WBI Energy Transmission, Inc.1/3	July 1, 2012 (January 1, 2009)
WHC, Ltd.	September 1, 2001

^1/Eligible employees participating in a management incentive compensation plan or an executive incentive compensation plan are not eligible for a Profit Sharing Contribution. Employees of the WBI Energy Corrosion Services division of WBI Energy Midstream, LLC are excluded from this feature.

²/In the event a Participating Affiliate adopts a Profit Sharing Feature on a date other than January 1, effective as of the date of participation in the Plan, the amount of any such contribution allocated to a Supplement D‑1 Participant shall be based upon Compensation, received while in the employ of the Participating Affiliate after the date of acquisition by the Company or any Affiliate.

³/Requirement to be an Active Employee on the last day of the Plan Year does not apply.

⁴/The following participants of Kent’s Oil Service are granted vesting service for prior years of service with Spirit Road Oils: Isaias Jaimes, Hideo Lewis, Christopher Niffenegger, Jose Padilla, George Velador, and Anthony Willis.

Explanation: This amendment adds Capital Electric Line Builders, Inc. (CEL) as a Participating Affiliate in Supplement D-1 (Profit Sharing Feature) of the K-Plan as of January 1, 2014 due to its desire to participate in the Profit Sharing Feature, excluding those who participate in the management incentive compensation plan.

IN WITNESS WHEREOF, MDU Resources Group, Inc., as Sponsoring Employer of the Plan, has caused this amendment to be duly executed by a member of the MDU Resources Group, Inc. Employee Benefits Committee (“Committee”) on this 5th day of June, 2014.

MDU RESOURCES GROUP, INC.
EMPLOYEE BENEFITS COMMITTEE
	/s/ Doran N. Schwartz
By:
	Doran N. Schwartz, Chairman

3

EX-10.(B)

MDU RESOURCES GROUP, INC.

DIRECTOR COMPENSATION POLICY

Each Director who is not a full-time employee of the Company shall receive compensation made up of annual cash retainers and common stock. Each Director is also eligible for awards under the Non-Employee Director Long-Term Incentive Compensation Plan.

Director Compensation
Annual Cash Retainers
Base Retainer	$65,000*
Additional Retainers:
Non-Executive Chairman of the Board	90,000
Lead Director, if any	33,000
Chairman of Audit Committee	15,000
Chairman of Compensation Committee	10,000
Chairman of Nominating and Governance Committee	10,000

___________                

*    Effective June 1, 2014.

Such cash retainers shall be paid in monthly installments.

The MDU Resources Group, Inc. Deferred Compensation Plan for Directors (as amended and restated effective May 15, 2008) permits a Director to defer all or any portion of the annual cash retainers. The amount deferred is recorded in each participant's deferred compensation account and credited with income in the manner prescribed in the Plan. For further details, reference is made to the Plan, a copy of which is attached.

Common Stock

Each person who is a Director of the Company at any time during the calendar year shall receive a $110,000 stock payment on or about the Wednesday following the Board of Directors’ regularly-scheduled November meeting, pursuant to the Non-Employee Director Stock Compensation Plan. The stock payment shall be equal to the number of whole shares of Common Stock determined (i) if the shares are original issue or treasury stock, by dividing $110,000 by the closing price of the Common Stock on the New York Stock Exchange on the grant date and (ii) if the shares are purchased on the open market, by dividing $110,000 by the weighted average price paid to purchase shares for the Directors for that stock payment, excluding any related brokerage commissions or other service fees. Any fractional shares shall be paid in cash. The stock payment shall be

prorated for any Director who does not serve the entire calendar year by multiplying $110,000 by a fraction, the numerator of which is the number of actual or expected months (with a partial month counted as a full month) of service on the Board during the calendar year and the denominator of which is twelve.

By written election a Director may reduce his or her annual cash retainers and have that amount applied to the purchase of additional shares pursuant to the Non-Employee Director Stock Compensation Plan. The election must be made on a form provided by the administrative committee and returned to the committee by the last business day of the year prior to the year in which the election is to be effective. The election remains in effect until changed or revoked. No election may be changed or revoked for the current year, but may be changed for a subsequent year. For further details, reference is made to the Non-Employee Director Stock Compensation Plan, a copy of which is attached.

Travel Expense Reimbursement

All Directors will be reimbursed for reasonable travel expenses incurred while serving as a Director, including spouse’s expenses, in connection with attendance at meetings of the Company’s Board of Directors and its committees. If the travel expense is related to the reimbursement of commercial airfare, such reimbursement will not exceed full-coach rate. If the travel expense is related to reimbursement of non-commercial airfare, such reimbursement will not exceed the rate for comparable travel by means of commercial airline at the first-class rate. Spousal travel expenses paid by the Company are treated as taxable income to the Director. See the paragraph below entitled "Code Section 409A" for further rules relating to travel expense reimbursements.

Directors' Liability

Article Seventeenth of the Company's Restated Certificate of Incorporation provides that no Director of the Company shall be liable to the Company or its stockholders for breach of fiduciary duty as a Director, with certain exceptions stated below. Section 7.07 of the Company's Bylaws requires the Company to indemnify fully a Director against expenses, attorneys fees, judgments, fines and amounts paid in settlement of any suit, action or proceeding, whether civil or criminal, arising from an action of a Director by reason of the fact that the Director was a Director of MDU Resources Group, Inc.

There are exceptions to the protections under Article Seventeenth of the Company’s Restated Certificate of Incorporation: breaches of the Directors' duty of loyalty to the Company or its stockholders, acts or omissions not in good faith or which involve intentional misconduct or a knowing violation of the law, violation of Section 174 of the Delaware General Corporation Law (relating to unlawful declaration of dividends

2

and unlawful purchase of the company's stock), and transactions from which the Director derived an improper personal benefit (including short-swing profits under Section 16(b) of the Securities Exchange Act of 1934).

Additional protection is provided through individual indemnification agreements with each Director.

The Company has and does maintain Directors' and Officers' liability insurance coverage with a $125 million limit.

Insurance Coverages

The Company maintains the following insurance for protection of its Directors as they carry out the business of MDU Resources Group, Inc., which shall be provided while serving as a Director:

1. General liability and automobile liability insurance:

If driving a personal vehicle, the Directors are afforded automobile liability coverage excess of their own personal automobile insurance under a combination of policies with program limits to $100 million after a self-insured retention of $500,000. If driving a vehicle owned by the Company, personal automobile insurance does not apply.

For general liability, coverage is provided to Directors under a combination of policies with program limits to $100 million after a self-insured retention of $500,000.

2. Fiduciary and crime insurance:

The Directors are afforded coverage under the fiduciary and crime liability insurance policies. The fiduciary policy has a limit of $35 million and the crime policy has a limit of $10 million.

3. Aircraft liability insurance:

The Company's existing aircraft liability insurance extends coverage while a hired, non-owned* aircraft is used by a Director in traveling to and from Director or Board committee meetings. This insurance coverage is excess of any underlying policy that may exist and provides limits of $200 million.

*Non-owned aircraft is defined as: 1) any aircraft registered under a “standard”

3

airworthiness certificate issued by the FAA; 2) aircraft with a seating capacity not exceeding 40 seats; 3) aircraft that are not owned by MDU Resources Group, Inc. or any of its subsidiaries; 4) aircraft that are not partly or wholly owned by or registered in the Director’s name or the name of any Director’s household member.

4. Business travel accident insurance:

All Directors are protected by a group insurance policy with coverage of $250,000 that provides 24-hour accident protection while traveling on Company business.

Coverage in all instances begins at the actual start of a business trip and ends when the Director returns to his/her home or regular place of employment.

The beneficiary of the insurance will be that beneficiary recorded on a beneficiary designation provided by the Company.

5. Group life insurance:

All outside Directors are protected by a non-contributory group life insurance policy with coverage of $100,000.

The coverage begins the day the Director is elected to the Board of Directors and terminates when the Director ceases to be an outside Director.

A Certificate of Insurance shall be provided to the Director. The beneficiary of the insurance will be the beneficiary recorded on a beneficiary designation provided by the Company.

This protection is considered taxable compensation under current tax laws. Consequently, the Company will provide each Director annually on Form 1099 the amount of taxable income related to this coverage.

Hedging Stock Ownership

Directors are not permitted to hedge their ownership of Company common stock. Hedging strategies include but are not limited to zero-cost collars, equity swaps, straddles, prepaid variable forward contracts, security futures contracts, exchange

4

funds, forward sale contracts and other financial transactions that allow the Director to benefit from devaluation of the Company's stock. Hedging strategies may allow Directors to own stock technically but without the full benefits and risks of such ownership. Therefore, Directors are prohibited from engaging in any such transactions.

Policy Regarding Margin Accounts and Pledging of Company Stock

Effective December 21, 2012, Directors and related persons are prohibited from holding company common stock in a margin account or pledging company securities as collateral for a loan, with certain exceptions. Company common stock may be held in a margin brokerage account only if the stock is explicitly excluded from any margin, pledge or security provisions of the customer agreement. Company common stock may be held in a cash account, which is a brokerage account that does not allow any extension of credit on securities. “Related person” means a director’s spouse, minor child and any person (other than a tenant or domestic employee) sharing the household of a director, as well as any entities over which a director exercises control.

Code Section 409A

To the extent any reimbursements or in-kind benefits provided to a Director pursuant to this policy constitute “deferred compensation” under Internal Revenue Code Section 409A, any such reimbursement or in-kind benefit shall be paid in a manner consistent with Treasury Regulation Section 1.409A-3(i)(1)(iv), including the requirements that the amount of reimbursable expenses or in-kind benefits provided during a year may not affect the expenses eligible for reimbursement or in-kind benefits provided in any other year and that any reimbursement be made on or before the last day of the calendar year following the calendar year in which the expense was incurred.

5

EX-10.(C)

MDU Resources Group, Inc. Section 16 Officers and Directors

with Indemnification Agreements Chart

Section 16 Officers

Name	Title	Date of Agreement
David L. Goodin	President and Chief Executive Officer, MDU Resources Group, Inc.	August 12, 2010, as amended May 15, 2014
Steven L. Bietz	President and Chief Executive Officer, WBI Holdings, Inc.	August 12, 2010, as amended May 15, 2014
William R. Connors	Vice President - Renewable Resources, MDU Resources Group, Inc.	August 12, 2010, as amended May 15, 2014
Mark A. Del Vecchio	Vice President - Human Resources, MDU Resources Group, Inc.	August 12, 2010, as amended May 15, 2014
Cynthia J. Norland	Vice President - Administration, MDU Resources Group, Inc.	August 12, 2010, as amended May 15, 2014
Paul K. Sandness	General Counsel and Secretary, MDU Resources Group, Inc.	August 12, 2010, as amended May 15, 2014
Doran N. Schwartz	Vice President and Chief Financial Officer, MDU Resources Group, Inc.	August 12, 2010, as amended May 15, 2014
Douglass A. Mahowald	Treasurer and Assistant Secretary, MDU Resources Group, Inc.	August 12, 2010, as amended May 15, 2014
J. Kent Wells	Vice Chairman, MDU Resources Group, Inc.; and Chief Executive Officer, Fidelity Exploration & Production Company	May 2, 2011, as amended May 15, 2014
K. Frank Morehouse	President and Chief Executive Officer, Montana-Dakota Utilities Co., Great Plains Natural Gas Co., Cascade Natural Gas Corporation, and Intermountain Gas Company	January 4, 2013, as amended May 15, 2014
David C. Barney	President and Chief Executive Officer, Knife River Corporation	May 16, 2013, as amended May 15, 2014
Jeffrey S. Thiede	President and Chief Executive Officer, MDU Construction Services Group, Inc.	May 16, 2013, as amended May 15, 2014
Dennis L. Haider	Executive Vice President - Business Development, MDU Resources Group, Inc.	June 1, 2013, as amended May 15, 2014
Nathan W. Ring	Vice President, Controller and Chief Accounting Officer, MDU Resources Group, Inc. effective January 3, 2014	January 3, 2014, as amended May 15, 2014

Directors

Name	Title	Date of Agreement
Harry J. Pearce	Chairman of the Board of Directors	August 12, 2010
David L. Goodin	Director	August 12, 2010
Thomas Everist	Director	August 12, 2010
Karen B. Fagg	Director	August 12, 2010
Mark A. Hellerstein	Director	August 1, 2013
A. Bart Holaday	Director	August 12, 2010
Dennis W. Johnson	Director	August 12, 2010
William E. McCracken	Director	August 1, 2013
Patricia L. Moss	Director	August 12, 2010
J. Kent Wells	Director	May 2, 2011
John K. Wilson	Director	August 12, 2010

EX-12

MDU RESOURCES GROUP, INC.

COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES

AND COMBINED FIXED CHARGES AND PREFERRED STOCK DIVIDENDS

	Twelve Months Ended June 30, 2014				Year Ended December 31, 2013
	(In thousands of dollars)
Earnings Available for Fixed Charges:
Net Income (a)		$	285,899			$	281,163
Income Taxes		138,802				136,736
		424,701				417,899
Rents (b)		17,026				16,035
Interest (c)		92,617				92,481
Total Earnings Available for Fixed Charges		$	534,344			$	526,415
Preferred Dividend Requirements		$	685			$	685
Ratio of Income Before Income Taxes to Net Income		149		%		149		%
Preferred Dividend Factor on Pretax Basis		1,021				1,021
Fixed Charges (d)		110,585				107,892
Combined Fixed Charges and Preferred Stock Dividends		$	111,606			$	108,913
Ratio of Earnings to Fixed Charges		4.8x				4.9x
Ratio of Earnings to Combined Fixed Charges and Preferred Stock Dividends		4.8x				4.8x

(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).

EX-31.(A)

CERTIFICATION

I, David L. Goodin, certify that:

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.

Date:  August 8, 2014

/s/ David L. Goodin

David L. Goodin

President and Chief Executive Officer

EX-31.(B)

CERTIFICATION

I, Doran N. Schwartz, certify that:

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.

Date:  August 8, 2014

/s/ Doran N. Schwartz

Doran N. Schwartz

Vice President and Chief Financial Officer

EX-32

CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 906

OF THE SARBANES-OXLEY ACT OF 2002

Each of the undersigned, David L. Goodin, the President and Chief Executive Officer, and Doran N. Schwartz, the Vice President and Chief Financial Officer of MDU Resources Group, Inc. (the "Company"), DOES HEREBY CERTIFY that:

1.  The Company's Quarterly Report on Form 10-Q for the quarter ended June 30, 2014 (the "Report"), fully complies with the requirements of Section 13(a) of the Securities Exchange Act of 1934; and

2.  Information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

IN WITNESS WHERE OF, each of the undersigned has executed this statement this 8th day of August, 2014.

/s/ David L. Goodin

David L. Goodin

President and Chief Executive Officer

/s/ Doran N. Schwartz

Doran N. Schwartz

Vice President and Chief Financial Officer

A signed original of this written statement required by Section 906 has been provided to MDU Resources Group, Inc. and will be retained by MDU Resources Group, Inc. and furnished to the Securities and Exchange Commission or its staff upon request.

EX-95

MDU RESOURCES GROUP, INC.

MINE SAFETY INFORMATION

The Dodd-Frank Wall Street Reform and Consumer Protection Act (Dodd-Frank Act) requires issuers to include in periodic reports filed with the SEC certain information relating to citations or orders for violations of standards under the Federal Mine Safety and Health Act of 1977 (Mine Act), as amended by the Mine Improvement and New Emergency Response Act of 2006 (Mine Safety Act). The Dodd-Frank Act requires reporting of the following types of citations or orders:

1. Citations issued under Section 104 of the Mine Safety Act for violations that could significantly and substantially contribute to the cause and effect of a coal or other mine safety or health hazard.

2. Orders issued under Section 104(b) of the Mine Safety Act. Orders are issued under this section when citations issued under Section 104 have not been totally abated within the time period allowed by the citation or subsequent extensions.

3. Citations or orders issued under Section 104(d) of the Mine Safety Act. Citations or orders are issued under this section when it has been determined that the violation is caused by an unwarrantable failure of the mine operator to comply with the standards. An unwarrantable failure occurs when the mine operator is deemed to have engaged in aggravated conduct constituting more than ordinary negligence.

4. Citations issued under Section 110(b)(2) of the Mine Safety Act for flagrant violations. Violations are considered flagrant for repeat or reckless failures to make reasonable efforts to eliminate a known violation of a mandatory health and safety standard that substantially and proximately caused, or reasonably could have been expected to cause, death or serious bodily injury.

5. Imminent danger orders issued under Section 107(a) of the Mine Safety Act. An imminent danger is defined as the existence of any condition or practice in a coal or other mine which could reasonably be expected to cause death or serious physical harm before such condition or practice can be abated.

6. Notice received under Section 104(e) of the Mine Safety Act of a pattern of violations or the potential to have such a pattern of violations that could significantly and substantially contribute to the cause and effect of mine health and safety standards.

During the three months ended June 30, 2014, none of the Company's operating subsidiaries received citations or orders under the following sections of the Mine Safety Act: 104(b), 104(d), 110(b)(2) or 104(e). During the three months ended June 30, 2014, one of the Company's operating subsidiaries received an order under section 107(a) of the Mine Safety Act. In addition, the Company did not have any mining-related fatalities during this period.

1

MSHA Identification Number	Section 104 S&S Citations (#)	Section 107(a) Orders (#)	Total Dollar Value of MSHA Assessments Proposed ($)		Legal Actions Pending as of Last Day of Period (#)	Legal Actions Initiated During Period (#)	Legal Actions Resolved During Period (#)
04-00081	—	—	$	—	4	—	—
04-01698	—	—	100		1	—	—
04-05459	—	—	—		2	—	—
21-03248	—	—	—		1	—	—
24-00478	1	—	408		1	1	—
24-02022	1	—	627		—	—	—
32-00776	1	—	—		—	—	—
32-00950	—	—	100		2	—	—
35-00463	—	—	300		—	—	—
35-00495	—	—	100		—	—	—
35-00512	—	—	400		—	—	—
35-02968	—	—	100		—	—	—
35-03022	—	—	300		—	—	—
35-03321	1	—	—		—	—	—
35-03404	—	—	200		2	2	—
35-03496	—	—	300		—	—	—
35-03527	1	—	525		—	—	—
35-03581	—	—	100		—	—	—
35-03595	1	—	725		—	—	—
35-03642	—	—	217		—	—	—
35-03667	—	—	317		—	—	—
41-02639	—	—	200		—	—	—
48-01670	—	—	100		—	—	—
50-01196	—	—	100		—	—	—
51-00036	—	—	1,140		4	—	1
51-00192	1	1	100		—	—	—
	7	1	6,459		17	3	1

Legal actions pending before the Federal Mine Safety and Health Review Commission (the Commission) may involve, among other questions, challenges by operators to citations, orders and penalties they have received from the Federal Mine Safety and Health Administration (MSHA) or complaints of discrimination by miners under section 105 of the Mine Act. The following is a brief description of the types of legal actions that may be brought before the Commission.

• Contests of Citations and Orders - A contest proceeding may be filed with the Commission by operators, miners or miners' representatives to challenge the issuance of a citation or order issued by MSHA.

• Contests of Proposed Penalties (Petitions for Assessment of Penalties) - A contest of a proposed penalty is an administrative proceeding before the Commission challenging a civil penalty that MSHA has proposed for the alleged violation contained in a citation or order.

• Complaints for Compensation - A complaint for compensation may be filed with the Commission by miners entitled to compensation when a mine is closed by certain withdrawal orders issued by MSHA. The purpose of the proceeding is to determine the amount of compensation, if any, due miners idled by the orders.

• Complaints of Discharge, Discrimination or Interference - A discrimination proceeding is a case that involves a miner's allegation that he or she has suffered a wrong by the operator because he or she engaged in some type of activity protected under the Mine Act, such as making a safety complaint.

• Applications for Temporary Relief - Applications for temporary relief from any modification or termination of any order or from any order issued under section 104 of the Mine Act.

2

• Appeals of Judges' Decisions or Orders to the Commission - A filing with the Commission for discretionary review of a judge's decision or order by a person who has been adversely affected or aggrieved by such decision or order.

The following table reflects the types of legal actions pending before the Commission as of June 30, 2014:

MSHA Identification Number	Contests of Citations and Orders	Contests of Proposed Penalties	Complaints for Compensation	Complaints of Discharge, Discrimination or Interference	Applications for Temporary Relief	Appeals of Judges' Decisions or Orders to the Commission
04-00081	—	—	—	—	—	4
04-01698	1	—	—	—	—	—
04-05459	2	—	—	—	—	—
21-03248	1	—	—	—	—	—
24-00478	1	—	—	—	—	—
32-00950	2	—	—	—	—	—
35-03404	—	2	—	—	—	—
51-00036	—	4	—	—	—	—
	7	6	—	—	—	4

3

XML

Employee benefit plans (Tables)

6 Months Ended

Jun. 30, 2014

Defined Benefit Plans and Other Postretirement Benefit Plans Disclosures [Abstract]

Schedule of net benefit costs

Components of net periodic benefit cost for the Company's pension and other postretirement benefit plans were as follows:

							Other
							Postretirement
	Pension Benefits						Benefits
Three Months Ended June 30,	2014			2013			2014			2013
	(In thousands)
Components of net periodic benefit cost:
Service cost	$	31		$	37		$	380		$	334
Interest cost	4,405			4,106			924			667
Expected return on assets	(5,484		)	(4,875		)	(1,242		)	(1,065		)
Amortization of prior service cost (credit)	18			18			(348		)	(364		)
Amortization of net actuarial loss	1,121			1,716			6			407
Net periodic benefit cost, including amount capitalized	91			1,002			(280		)	(21		)
Less amount capitalized	73			158			(19		)	61
Net periodic benefit cost (credit)	$	18		$	844		$	(261	)	$	(82	)

							Other
							Postretirement
	Pension Benefits						Benefits
Six Months Ended June 30,	2014			2013			2014			2013
	(In thousands)
Components of net periodic benefit cost:
Service cost	$	64		$	77		$	759		$	838
Interest cost	8,845			8,124			1,782			1,607
Expected return on assets	(10,609		)	(9,958		)	(2,309		)	(2,172		)
Amortization of prior service cost (credit)	36			36			(696		)	(728		)
Amortization of net actuarial loss	2,434			3,580			324			1,078
Net periodic benefit cost, including amount capitalized	770			1,859			(140		)	623
Less amount capitalized	168			268			10			90
Net periodic benefit cost (credit)	$	602		$	1,591		$	(150	)	$	533

XML

Derivative instruments (Details 3) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2013
Derivatives, Fair Value [Line Items]
Derivative asset, fair value, gross asset	$ 260	$ 1,950	$ 11,244
Derivative liability fair value gross liability	17,449	7,483	1,388
Not designated as hedging instrument [Member] | Commodity contract [Member] | Commodity derivative instruments - current assets [Member]
Derivatives, Fair Value [Line Items]
Other derivatives not designated as hedging instruments assets at fair value	129	1,447	9,797
Not designated as hedging instrument [Member] | Commodity contract [Member] | Other assets noncurrent [Member]
Derivatives, Fair Value [Line Items]
Other derivatives not designated as hedging instruments assets at fair value	131	503	1,447
Not designated as hedging instrument [Member] | Commodity contract [Member] | Commodity derivative instruments - current liabilities [Member]
Derivatives, Fair Value [Line Items]
Other derivatives not designated as hedging instruments liabilities at fair value	$ 17,449	$ 7,483	$ 1,388

XML

Acquisition (Details) (USD $) In Millions, unless otherwise specified	0 Months Ended
	Mar. 06, 2014
Business Combinations [Abstract]
Business acquisition, cost of acquired entity, purchase price	$ 206.3

XML

Subject to master netting agreements (Details 4) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2013
Derivative instruments [Line Items]
Derivative asset, fair value, gross asset	$ 260	$ 1,950	$ 11,244
Derivative liability fair value gross liability	17,449	7,483	1,388
Commodity derivatives [Member]
Derivative instruments [Line Items]
Derivative asset, fair value, gross asset	260	1,950	11,244
Gross amount not offset	(260)	(1,950)	(1,388)
Derivative asset, fair value, net	0	0	9,856
Total assets [Member]
Derivative instruments [Line Items]
Derivative asset, fair value, gross asset	260	1,950	11,244
Gross amount not offset	(260)	(1,950)	(1,388)
Derivative asset, fair value, net	0	0	9,856
Commodity derivatives - liabilities [Member]
Derivative instruments [Line Items]
Derivative liability fair value gross liability	17,449	7,483	1,388
Gross amount not offset	(260)	(1,950)	(1,388)
Derivative liability, fair value, net	17,189	5,533	0
Total liabilities [Member]
Derivative instruments [Line Items]
Derivative liability fair value gross liability	17,449	7,483	1,388
Gross amount not offset	(260)	(1,950)	(1,388)
Derivative liability, fair value, net	$ 17,189	$ 5,533	$ 0

XML

Comprehensive income (loss) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Accumulated other comprehensive income (loss) [Roll Forward]
Balance	$ (37,538)	$ (56,615)	$ (38,205)	$ (48,721)
Other comprehensive income (loss) before reclassifications	50	(278)	98	(6,083)
Amounts reclassified from accumulated other comprehensive loss	290	72	909	(2,017)
Net current-period other comprehensive income (loss)	340	(206)	1,007	(8,100)
Balance	(37,198)	(56,821)	(37,198)	(56,821)
Net unrealized gain (loss) on derivative instruments qualifying as hedges
Accumulated other comprehensive income (loss) [Roll Forward]
Balance	(3,421)	(2,603)	(3,765)	6,018
Other comprehensive income (loss) before reclassifications	0	254	0	(5,594)
Amounts reclassified from accumulated other comprehensive loss	13	(395)	357	(3,168)
Net current-period other comprehensive income (loss)	13	(141)	357	(8,762)
Balance	(3,408)	(2,744)	(3,408)	(2,744)
Postretirement liability adjustment
Accumulated other comprehensive income (loss) [Roll Forward]
Balance	(33,532)	(53,699)	(33,807)	(54,347)
Other comprehensive income (loss) before reclassifications	0	0	0	0
Amounts reclassified from accumulated other comprehensive loss	245	424	520	1,072
Net current-period other comprehensive income (loss)	245	424	520	1,072
Balance	(33,287)	(53,275)	(33,287)	(53,275)
Foreign currency translation adjustment
Accumulated other comprehensive income (loss) [Roll Forward]
Balance	(621)	(423)	(667)	(511)
Other comprehensive income (loss) before reclassifications	42	(390)	88	(302)
Amounts reclassified from accumulated other comprehensive loss	0	0	0	0
Net current-period other comprehensive income (loss)	42	(390)	88	(302)
Balance	(579)	(813)	(579)	(813)
Net unrealized gain (loss) on available-for-sale investments
Accumulated other comprehensive income (loss) [Roll Forward]
Balance	36	110	34	119
Other comprehensive income (loss) before reclassifications	8	(142)	10	(187)
Amounts reclassified from accumulated other comprehensive loss	32	43	32	79
Net current-period other comprehensive income (loss)	40	(99)	42	(108)
Balance	$ 76	$ 11	$ 76	$ 11

XML

Comprehensive income (loss) (Tables)

6 Months Ended

Jun. 30, 2014

Comprehensive income (loss) [Abstract]

Comprehensive income (loss)

The after-tax changes in the components of accumulated other comprehensive loss were as follows:

Three Months Ended June 30, 2014	Net Unrealized Gain (Loss) on Derivative  Instruments  Qualifying as Hedges			Postretirement  Liability Adjustment			Foreign Currency Translation Adjustment			Net Unrealized Gain (Loss) on Available-for-sale Investments		Total Accumulated  Other Comprehensive  Loss
	(In thousands)
Balance at beginning of period	$	(3,421	)	$	(33,532	)	$	(621	)	$	36	$	(37,538	)
Other comprehensive income (loss) before reclassifications	—			—			42			8		50
Amounts reclassified from accumulated other comprehensive loss	13			245			—			32		290
Net current-period other comprehensive income	13			245			42			40		340
Balance at end of period	$	(3,408	)	$	(33,287	)	$	(579	)	$	76	$	(37,198	)

Three Months Ended June 30, 2013	Net Unrealized Gain (Loss) on Derivative  Instruments  Qualifying as Hedges			Postretirement  Liability Adjustment			Foreign Currency Translation Adjustment			Net Unrealized Gain (Loss) on Available-for-sale Investments			Total Accumulated  Other Comprehensive  Loss
	(In thousands)
Balance at beginning of period	$	(2,603	)	$	(53,699	)	$	(423	)	$	110		$	(56,615	)
Other comprehensive income (loss) before reclassifications	254			—			(390		)	(142		)	(278		)
Amounts reclassified from accumulated other comprehensive loss	(395		)	424			—			43			72
Net current-period other comprehensive income (loss)	(141		)	424			(390		)	(99		)	(206		)
Balance at end of period	$	(2,744	)	$	(53,275	)	$	(813	)	$	11		$	(56,821	)

Six Months Ended June 30, 2014	Net Unrealized Gain (Loss) on Derivative  Instruments  Qualifying as Hedges			Postretirement  Liability Adjustment			Foreign Currency Translation Adjustment			Net Unrealized Gain (Loss) on Available-for-sale Investments		Total Accumulated  Other Comprehensive  Loss
	(In thousands)
Balance at beginning of period	$	(3,765	)	$	(33,807	)	$	(667	)	$	34	$	(38,205	)
Other comprehensive income (loss) before reclassifications	—			—			88			10		98
Amounts reclassified from accumulated other comprehensive loss	357			520			—			32		909
Net current-period other comprehensive income	357			520			88			42		1,007
Balance at end of period	$	(3,408	)	$	(33,287	)	$	(579	)	$	76	$	(37,198	)

Six Months Ended June 30, 2013	Net Unrealized Gain (Loss) on Derivative  Instruments  Qualifying as Hedges			Postretirement  Liability Adjustment			Foreign Currency Translation Adjustment			Net Unrealized Gain (Loss) on Available-for-sale Investments			Total Accumulated  Other Comprehensive  Loss
	(In thousands)
Balance at beginning of period	$	6,018		$	(54,347	)	$	(511	)	$	119		$	(48,721	)
Other comprehensive income (loss) before reclassifications	(5,594		)	—			(302		)	(187		)	(6,083		)
Amounts reclassified from accumulated other comprehensive loss	(3,168		)	1,072			—			79			(2,017		)
Net current-period other comprehensive income (loss)	(8,762		)	1,072			(302		)	(108		)	(8,100		)
Balance at end of period	$	(2,744	)	$	(53,275	)	$	(813	)	$	11		$	(56,821	)

Reclassification out of accumulated other comprehensive income

Reclassifications out of accumulated other comprehensive loss were as follows:

	Three Months Ended						Six Months Ended						Location on Consolidated Statements of Income
	June 30,						June 30,
	2014			2013			2014			2013
	(In thousands)
Reclassification adjustment for gain (loss) on derivative instruments included in net income:
Commodity derivative instruments	$	137		$	1,381		$	(250	)	$	5,896		Operating revenues
Interest rate derivative instruments	(160		)	(664		)	(320		)	(780		)	Interest expense
	(23		)	717			(570		)	5,116
	10			(322		)	213			(1,948		)	Income taxes
	(13		)	395			(357		)	3,168
Amortization of postretirement liability losses included in net periodic benefit cost	(395		)	(967		)	(838		)	(1,934		)	(a)
	150			543			318			862			Income taxes
	(245		)	(424		)	(520		)	(1,072		)
Reclassification adjustment for loss on available-for-sale investments included in net income	(49		)	(66		)	(49		)	(121		)	Other income
	17			23			17			42			Income taxes
	(32		)	(43		)	(32		)	(79		)
Total reclassifications	$	(290	)	$	(72	)	$	(909	)	$	2,017

(a) Included in net periodic benefit cost (credit). For more information, see Note 19.

XML

Fair value measurements (Details 2) (USD $)	Jun. 30, 2014		Dec. 31, 2013		Jun. 30, 2013
Concentration risks, percentage [Abstract]
Percentage investment in common stock of mid-cap companies	21.00%		29.00%		28.00%
Percentage investment in common stock of small-cap companies	18.00%		28.00%		28.00%
Percentage investment in common stock of large-cap companies	29.00%		28.00%		28.00%
Percentage in fixed-income and other investments	31.00%		15.00%		16.00%
Percentage investment in cash and cash equivalents	1.00%
Assets, Fair Value Disclosure, Nonrecurring					$ 9,700,000
Fair value, measurements, recurring [Member]
Fair value measurements [Line Items]
Assets, fair value disclosure	94,870,000		93,657,000		105,157,000
Liabilities, fair value disclosure	17,449,000		7,483,000		1,388,000
Fair value, measurements, recurring [Member] | Commodity derivative instruments [Member]
Fair value measurements [Line Items]
Liabilities, fair value disclosure	17,449,000		7,483,000		1,388,000
Fair value, measurements, recurring [Member] | Money market funds [Member]
Fair value measurements [Line Items]
Assets, fair value disclosure	19,990,000		19,227,000		29,902,000
Fair value, measurements, recurring [Member] | Insurance contract [Member]
Fair value measurements [Line Items]
Assets, fair value disclosure	64,449,000	[1]	62,370,000	[2]	54,039,000	[3]
Fair value, measurements, recurring [Member] | Mortgage backed securities [Member]
Fair value measurements [Line Items]
Assets, fair value disclosure	8,075,000		8,193,000		8,052,000
Fair value, measurements, recurring [Member] | US Treasury securities [Member]
Fair value measurements [Line Items]
Assets, fair value disclosure	2,096,000		1,917,000		1,920,000
Fair value, measurements, recurring [Member] | Commodity derivative instruments , assets [Member]
Fair value measurements [Line Items]
Assets, fair value disclosure	260,000		1,950,000		11,244,000
Fair value, measurements, recurring [Member] | Fair value, inputs, level 1 [Member]
Fair value measurements [Line Items]
Assets, fair value disclosure	0		0		0
Liabilities, fair value disclosure	0		0		0
Fair value, measurements, recurring [Member] | Fair value, inputs, level 1 [Member] | Commodity derivative instruments [Member]
Fair value measurements [Line Items]
Liabilities, fair value disclosure	0		0		0
Fair value, measurements, recurring [Member] | Fair value, inputs, level 1 [Member] | Money market funds [Member]
Fair value measurements [Line Items]
Assets, fair value disclosure	0		0		0
Fair value, measurements, recurring [Member] | Fair value, inputs, level 1 [Member] | Insurance contract [Member]
Fair value measurements [Line Items]
Assets, fair value disclosure	0	[1]	0	[2]	0	[3]
Fair value, measurements, recurring [Member] | Fair value, inputs, level 1 [Member] | Mortgage backed securities [Member]
Fair value measurements [Line Items]
Assets, fair value disclosure	0		0		0
Fair value, measurements, recurring [Member] | Fair value, inputs, level 1 [Member] | US Treasury securities [Member]
Fair value measurements [Line Items]
Assets, fair value disclosure	0		0		0
Fair value, measurements, recurring [Member] | Fair value, inputs, level 1 [Member] | Commodity derivative instruments , assets [Member]
Fair value measurements [Line Items]
Assets, fair value disclosure	0		0		0
Fair value, measurements, recurring [Member] | Fair value, inputs, level 2 [Member]
Fair value measurements [Line Items]
Assets, fair value disclosure	94,870,000		93,657,000		105,157,000
Liabilities, fair value disclosure	17,449,000		7,483,000		1,388,000
Fair value, measurements, recurring [Member] | Fair value, inputs, level 2 [Member] | Commodity derivative instruments [Member]
Fair value measurements [Line Items]
Liabilities, fair value disclosure	17,449,000		7,483,000		1,388,000
Fair value, measurements, recurring [Member] | Fair value, inputs, level 2 [Member] | Money market funds [Member]
Fair value measurements [Line Items]
Assets, fair value disclosure	19,990,000		19,227,000		29,902,000
Fair value, measurements, recurring [Member] | Fair value, inputs, level 2 [Member] | Insurance contract [Member]
Fair value measurements [Line Items]
Assets, fair value disclosure	64,449,000	[1]	62,370,000	[2]	54,039,000	[3]
Fair value, measurements, recurring [Member] | Fair value, inputs, level 2 [Member] | Mortgage backed securities [Member]
Fair value measurements [Line Items]
Assets, fair value disclosure	8,075,000		8,193,000		8,052,000
Fair value, measurements, recurring [Member] | Fair value, inputs, level 2 [Member] | US Treasury securities [Member]
Fair value measurements [Line Items]
Assets, fair value disclosure	2,096,000		1,917,000		1,920,000
Fair value, measurements, recurring [Member] | Fair value, inputs, level 2 [Member] | Commodity derivative instruments , assets [Member]
Fair value measurements [Line Items]
Assets, fair value disclosure	260,000		1,950,000		11,244,000
Fair value, measurements, recurring [Member] | Fair value, inputs, level 3 [Member]
Fair value measurements [Line Items]
Assets, fair value disclosure	0		0		0
Liabilities, fair value disclosure	0		0		0
Fair value, measurements, recurring [Member] | Fair value, inputs, level 3 [Member] | Commodity derivative instruments [Member]
Fair value measurements [Line Items]
Liabilities, fair value disclosure	0		0		0
Fair value, measurements, recurring [Member] | Fair value, inputs, level 3 [Member] | Money market funds [Member]
Fair value measurements [Line Items]
Assets, fair value disclosure	0		0		0
Fair value, measurements, recurring [Member] | Fair value, inputs, level 3 [Member] | Insurance contract [Member]
Fair value measurements [Line Items]
Assets, fair value disclosure	0	[1]	0	[2]	0	[3]
Fair value, measurements, recurring [Member] | Fair value, inputs, level 3 [Member] | Mortgage backed securities [Member]
Fair value measurements [Line Items]
Assets, fair value disclosure	0		0		0
Fair value, measurements, recurring [Member] | Fair value, inputs, level 3 [Member] | US Treasury securities [Member]
Fair value measurements [Line Items]
Assets, fair value disclosure	0		0		0
Fair value, measurements, recurring [Member] | Fair value, inputs, level 3 [Member] | Commodity derivative instruments , assets [Member]
Fair value measurements [Line Items]
Assets, fair value disclosure	$ 0		$ 0		$ 0

[1] The insurance contract invests approximately 21 percent in common stock of mid-cap companies, 18 percent in common stock of small-cap companies, 29 percent in common stock of large-cap companies, 31 percent in fixed-income investments and 1 percent in cash equivalents.

[2] The insurance contract invests approximately 29 percent in common stock of mid-cap companies, 28 percent in common stock of small-cap companies, 28 percent in common stock of large-cap companies and 15 percent in fixed-income investments.

[3] The insurance contract invests approximately 28 percent in common stock of mid-cap companies, 28 percent in common stock of small-cap companies, 28 percent in common stock of large-cap companies and 16 percent in fixed-income investments.

XML

Business segment data

6 Months Ended

Jun. 30, 2014

Segment Reporting [Abstract]

Business segment data

Business segment data

The Company's reportable segments are those that are based on the Company's method of internal reporting, which generally segregates the strategic business units due to differences in products, services and regulation. The internal reporting of these operating segments is defined based on the reporting and review process used by the Company's chief executive officer. The vast majority of the Company's operations are located within the United States. The Company also has an investment in a foreign country, which consists of Centennial Resources' investment in ECTE.

The electric segment generates, transmits and distributes electricity in Montana, North Dakota, South Dakota and Wyoming. The natural gas distribution segment distributes natural gas in those states as well as in Idaho, Minnesota, Oregon and Washington. These operations also supply related value-added services.

The pipeline and energy services segment provides natural gas transportation, underground storage, processing and gathering services, as well as oil gathering, through regulated and nonregulated pipeline systems and processing facilities primarily in the Rocky Mountain and northern Great Plains regions of the United States. This segment is constructing the Dakota Prairie Refinery in conjunction with Calumet to refine crude oil and also provides cathodic protection and other energy-related services.

The exploration and production segment is engaged in oil and natural gas acquisition, exploration, development and production activities in the Rocky Mountain and Mid-Continent/Gulf States regions of the United States.

The construction materials and contracting segment mines aggregates and markets crushed stone, sand, gravel and related construction materials, including ready-mixed concrete, cement, asphalt, liquid asphalt and other value-added products. It also performs integrated contracting services. This segment operates in the central, southern and western United States and Alaska and Hawaii.

The construction services segment specializes in constructing and maintaining electric and communication lines, gas pipelines, fire suppression systems, and external lighting and traffic signalization equipment. This segment also provides utility excavation services and inside electrical wiring, cabling and mechanical services, sells and distributes electrical materials, and manufactures and distributes specialty equipment.

The Other category includes the activities of Centennial Capital, which insures various types of risks as a captive insurer for certain of the Company's subsidiaries. The function of the captive insurer is to fund the deductible layers of the insured companies' general liability, automobile liability and pollution liability coverages. Centennial Capital also owns certain real and personal property. The Other category also includes Centennial Resources' investment in ECTE.

The information below follows the same accounting policies as described in Note 1 of the Company's Notes to Consolidated Financial Statements in the 2013 Annual Report. Information on the Company's businesses was as follows:

Three Months Ended June 30, 2014	External Operating Revenues		Inter- segment Operating Revenues			Earnings on Common Stock
	(In thousands)
Electric	$	65,149	$	—		$	7,823
Natural gas distribution	146,077		—			(4,494		)
Pipeline and energy services	43,463		7,888			5,789
	254,689		7,888			9,118
Exploration and production	129,309		10,271			19,180
Construction materials and contracting	434,452		8,106			10,554
Construction services	275,109		7,273			14,307
Other	487		1,744			1,608
	839,357		27,394			45,649
Intersegment eliminations	—		(35,282		)	(832		)
Total	$	1,094,046	$	—		$	53,935

Three Months Ended June 30, 2013	External Operating Revenues		Inter- segment Operating Revenues			Earnings on Common Stock
	(In thousands)
Electric	$	56,981	$	—		$	4,410
Natural gas distribution	127,584		—			(5,893		)
Pipeline and energy services	42,877		7,999			(6,395		)
	227,442		7,999			(7,878		)
Exploration and production	137,053		12,556			32,995
Construction materials and contracting	418,345		12,958			10,025
Construction services	277,259		2,340			12,915
Other	496		1,839			340
	833,153		29,693			56,275
Intersegment eliminations	—		(37,692		)	(2,056		)
Total	$	1,060,595	$	—		$	46,341

Six Months Ended June 30, 2014	External Operating Revenues		Inter- segment Operating Revenues			Earnings on Common Stock
	(In thousands)
Electric	$	138,796	$	—		$	18,856
Natural gas distribution	520,311		—			22,768
Pipeline and energy services	87,124		26,164			10,138
	746,231		26,164			51,762
Exploration and production	245,976		31,139			40,120
Construction materials and contracting	598,875		12,123			(13,019		)
Construction services	545,002		11,010			30,875
Other	815		3,468			1,872
	1,390,668		57,740			59,848
Intersegment eliminations	—		(83,904		)	(1,184		)
Total	$	2,136,899	$	—		$	110,426

Six Months Ended June 30, 2013	External Operating Revenues		Inter- segment Operating Revenues			Earnings on Common Stock
	(In thousands)
Electric	$	121,635	$	—		$	14,235
Natural gas distribution	459,337		—			26,624
Pipeline and energy services	70,593		26,717			(4,064		)
	651,565		26,717			36,795
Exploration and production	252,415		22,369			53,279
Construction materials and contracting	580,323		17,251			(10,557		)
Construction services	507,065		3,914			24,579
Other	830		3,657			645
	1,340,633		47,191			67,946
Intersegment eliminations	—		(73,908		)	(2,056		)
Total	$	1,992,198	$	—		$	102,685

Earnings from electric, natural gas distribution and pipeline and energy services are substantially all from regulated operations. Earnings from exploration and production, construction materials and contracting, construction services and other are all from nonregulated operations.

XML

Goodwill rollforward (Details) (USD $)	6 Months Ended				12 Months Ended
	Jun. 30, 2014		Jun. 30, 2013		Dec. 31, 2013
Goodwill [Roll Forward]
Balance as of beginning of period	$ 636,039,000	[1]	$ 636,039,000	[1]	$ 636,039,000	[1]
Goodwill acquired during the year	0		0		0
Balance as of end of period	636,039,000	[1]	636,039,000	[1]	636,039,000	[1]
Natural gas distribution [Member]
Goodwill [Roll Forward]
Balance as of beginning of period	345,736,000		345,736,000		345,736,000
Goodwill acquired during the year	0		0		0
Balance as of end of period	345,736,000		345,736,000		345,736,000
Pipeline and energy services [Member]
Goodwill [Line Items]
Goodwill, impaired, accumulated impairment loss	12,300,000		12,300,000		12,300,000
Goodwill [Roll Forward]
Balance as of beginning of period	9,737,000	[1]	9,737,000	[1]	9,737,000	[1]
Goodwill acquired during the year	0		0		0
Balance as of end of period	9,737,000	[1]	9,737,000	[1]	9,737,000	[1]
Construction materials and contracting [Member]
Goodwill [Roll Forward]
Balance as of beginning of period	176,290,000		176,290,000		176,290,000
Goodwill acquired during the year	0		0		0
Balance as of end of period	176,290,000		176,290,000		176,290,000
Construction services [Member]
Goodwill [Roll Forward]
Balance as of beginning of period	104,276,000		104,276,000		104,276,000
Goodwill acquired during the year	0		0		0
Balance as of end of period	$ 104,276,000		$ 104,276,000		$ 104,276,000

[1] Balance is presented net of accumulated impairment of $12.3 million at the pipeline and energy services segment, which occurred in prior periods.

XML

Inventories and natural gas in storage (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2013
Inventory Disclosure [Abstract]
Aggregates held for resale	$ 112,129,000	$ 101,568,000	$ 103,503,000
Asphalt oil	76,525,000	38,099,000	91,837,000
Materials and supplies	70,938,000	69,808,000	74,648,000
Merchandise for resale	25,507,000	21,720,000	27,330,000
Natural gas in storage (current)	10,903,000	16,417,000	14,287,000
Other	35,420,000	34,779,000	34,280,000
Total	331,422,000	282,391,000	345,885,000
Natural gas in storage noncurrent	$ 47,400,000	$ 48,300,000	$ 48,600,000

XML

Equity (Tables)

6 Months Ended

Jun. 30, 2014

Equity [Abstract]

Summary of changes in equity

A summary of the changes in equity was as follows:

Six Months Ended June 30, 2014	Total Stockholders' Equity			Noncontrolling Interest			Total Equity
	(In thousands)
Balance at December 31, 2013	$	2,823,164		$	32,738		$	2,855,902
Net income (loss)	110,768			(1,302		)	109,466
Other comprehensive income	1,007			—			1,007
Dividends declared on preferred stocks	(342		)	—			(342		)
Dividends declared on common stock	(68,025		)	—			(68,025		)
Stock-based compensation	2,796			—			2,796
Issuance of common stock upon vesting of performance shares, net of shares used for tax withholdings	(5,564		)	—			(5,564		)
Net tax benefit on stock-based compensation	4,729			—			4,729
Issuance of common stock	131,973			—			131,973
Contribution from noncontrolling interest	—			32,500			32,500
Balance at June 30, 2014	$	3,000,506		$	63,936		$	3,064,442

Six Months Ended June 30, 2013	Total Stockholders' Equity			Noncontrolling Interest			Total Equity
	(In thousands)
Balance at December 31, 2012	$	2,648,248		$	—		$	2,648,248
Net income (loss)	103,027			(179		)	102,848
Other comprehensive loss	(8,100		)	—			(8,100		)
Dividends declared on preferred stocks	(342		)	—			(342		)
Dividends declared on common stock	(65,147		)	—			(65,147		)
Stock-based compensation	2,453			—			2,453
Net tax deficit on stock-based compensation	(1,419		)	—			(1,419		)
Contribution from noncontrolling interest	—			16,101			16,101
Balance at June 30, 2013	$	2,678,720		$	15,922		$	2,694,642

XML

Derivative instruments (Details) (USD $)	6 Months Ended
	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2013	Mar. 31, 2013
Derivative instruments [Line Items]
Amount of unrealized gain (loss) on hedge at de-designation date to be reclassified into AOCI				$ 1,800,000
Amount of time remaining to transfer accumulated other comprehensive income to earnings	6 months
Cash flow hedge gain (loss) to be reclassified within twelve months from AOCI into earnings	(535,000)
Derivatives with credit-risk-related contingent feature in net liability position, aggregate fair value	17,400,000	7,500,000	1,400,000
Assets needed for immediate settlement aggregate fair value for cash flow hedging instruments	$ 17,400,000	$ 7,500,000	$ 1,400,000
Oil swap and\or collar [Member]
Derivative instruments [Line Items]
Derivative, nonmonetary notional amount	2,500,000	2,900,000	3,100,000
Natural gas swap and\or collar [Member]
Derivative instruments [Line Items]
Derivative, nonmonetary notional amount	11,000,000	18,300,000	21,400,000

XML

Commitment and contingencies variable interest entities (Details 4) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2013
Dakota Prairie Refining, LLC [Member]
Variable Interest Entities [Line Items]
Percent of ownership	50.00%
Total project costs	$ 300,000,000
Portion of capital commitment	150,000,000
Partner portion of capital commitment	75,000,000
Excess capital commitments	300,000,000
Project cost estimate	350,000,000
Term loan for project debt financing	75,000,000
Dakota Prairie Refining, LLC [Member] | Cash and Cash Equivalents [Member]
Variable Interest Entities [Line Items]
Limited liability entity, consolidated, carrying amount, assets	32,283,000	4,774,000	63,089,000
Dakota Prairie Refining, LLC [Member] | Accounts Receivable [Member]
Variable Interest Entities [Line Items]
Limited liability entity, consolidated, carrying amount, assets	0	0	5,000
Dakota Prairie Refining, LLC [Member] | Other current assets [Member]
Variable Interest Entities [Line Items]
Limited liability entity, consolidated, carrying amount, assets	2,136,000	26,000	0
Dakota Prairie Refining, LLC [Member] | Total current assets [Member]
Variable Interest Entities [Line Items]
Limited liability entity, consolidated, carrying amount, assets	34,419,000	4,800,000	63,094,000
Dakota Prairie Refining, LLC [Member] | Net property, plant and equipment [Member]
Variable Interest Entities [Line Items]
Limited liability entity, consolidated, carrying amount, assets	254,079,000	172,073,000	75,216,000
Dakota Prairie Refining, LLC [Member] | Total assets [Member]
Variable Interest Entities [Line Items]
Limited liability entity, consolidated, carrying amount, assets	288,498,000	176,873,000	138,310,000
Dakota Prairie Refining, LLC [Member] | Long-term debt due within one year [Member]
Variable Interest Entities [Line Items]
Limited liability entity, consolidated, carrying amount, liabilities	3,000,000	3,000,000	3,000,000
Dakota Prairie Refining, LLC [Member] | Accounts payable [Member]
Variable Interest Entities [Line Items]
Limited liability entity, consolidated, carrying amount, liabilities	28,150,000	8,904,000	21,057,000
Dakota Prairie Refining, LLC [Member] | Taxes Payable [Member]
Variable Interest Entities [Line Items]
Limited liability entity, consolidated, carrying amount, liabilities	225,000	5,000	0
Dakota Prairie Refining, LLC [Member] | Accrued Compensation [Member]
Variable Interest Entities [Line Items]
Limited liability entity, consolidated, carrying amount, liabilities	256,000	26,000	0
Dakota Prairie Refining, LLC [Member] | Other accrued liabilities [Member]
Variable Interest Entities [Line Items]
Limited liability entity, consolidated, carrying amount, liabilities	494,000	461,000	300,000
Dakota Prairie Refining, LLC [Member] | Total current liabilities [Member]
Variable Interest Entities [Line Items]
Limited liability entity, consolidated, carrying amount, liabilities	32,125,000	12,396,000	24,357,000
Dakota Prairie Refining, LLC [Member] | Long-term debt [Member]
Variable Interest Entities [Line Items]
Limited liability entity, consolidated, carrying amount, liabilities	69,000,000	72,000,000	72,000,000
Dakota Prairie Refining, LLC [Member] | Total liabilities [Member]
Variable Interest Entities [Line Items]
Limited liability entity, consolidated, carrying amount, liabilities	101,125,000	84,396,000	96,357,000
Fuel contract [Member]
Variable Interest Entities [Line Items]
Variable interest entity, reporting entity involvement, maximum loss exposure, amount	$ 9,700,000

XML

Business segment data (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Segment Reporting Information [Line Items]
Revenues	$ 1,094,046	$ 1,060,595	$ 2,136,899	$ 1,992,198
Intersegment operating revenues	0	0	0	0
Earnings on common stock	53,935	46,341	110,426	102,685
Regulated Operation [Member]
Segment Reporting Information [Line Items]
Revenues	254,689	227,442	746,231	651,565
Intersegment operating revenues	7,888	7,999	26,164	26,717
Earnings on common stock	9,118	(7,878)	51,762	36,795
Unregulated Operation [Member]
Segment Reporting Information [Line Items]
Revenues	839,357	833,153	1,390,668	1,340,633
Intersegment operating revenues	27,394	29,693	57,740	47,191
Earnings on common stock	45,649	56,275	59,848	67,946
Electric [Member] | Regulated Operation [Member]
Segment Reporting Information [Line Items]
Revenues	65,149	56,981	138,796	121,635
Intersegment operating revenues	0	0	0	0
Earnings on common stock	7,823	4,410	18,856	14,235
Natural gas distribution [Member] | Regulated Operation [Member]
Segment Reporting Information [Line Items]
Revenues	146,077	127,584	520,311	459,337
Intersegment operating revenues	0	0	0	0
Earnings on common stock	(4,494)	(5,893)	22,768	26,624
Pipeline and energy services [Member] | Regulated Operation [Member]
Segment Reporting Information [Line Items]
Revenues	43,463	42,877	87,124	70,593
Intersegment operating revenues	7,888	7,999	26,164	26,717
Earnings on common stock	5,789	(6,395)	10,138	(4,064)
Exploration and production [Member] | Unregulated Operation [Member]
Segment Reporting Information [Line Items]
Revenues	129,309	137,053	245,976	252,415
Intersegment operating revenues	10,271	12,556	31,139	22,369
Earnings on common stock	19,180	32,995	40,120	53,279
Construction materials and contracting [Member] | Unregulated Operation [Member]
Segment Reporting Information [Line Items]
Revenues	434,452	418,345	598,875	580,323
Intersegment operating revenues	8,106	12,958	12,123	17,251
Earnings on common stock	10,554	10,025	(13,019)	(10,557)
Construction services [Member] | Unregulated Operation [Member]
Segment Reporting Information [Line Items]
Revenues	275,109	277,259	545,002	507,065
Intersegment operating revenues	7,273	2,340	11,010	3,914
Earnings on common stock	14,307	12,915	30,875	24,579
Other [Member] | Unregulated Operation [Member]
Segment Reporting Information [Line Items]
Revenues	487	496	815	830
Intersegment operating revenues	1,744	1,839	3,468	3,657
Earnings on common stock	1,608	340	1,872	645
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenues	0	0	0	0
Intersegment operating revenues	(35,282)	(37,692)	(83,904)	(73,908)
Earnings on common stock	$ (832)	$ (2,056)	$ (1,184)	$ (2,056)

XML

Reclassification out of accumulated other comprehensive income (loss) (Details 2) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Reclassification adjustment out of accumulated other comprehensive income [Line Items]
Revenues	$ 1,094,046	$ 1,060,595	$ 2,136,899	$ 1,992,198
Interest expense	(21,516)	(21,427)	(42,487)	(42,300)
Other income	2,777	1,436	4,908	2,677
Income before income taxes	79,898	71,380	164,014	155,967
Income taxes	27,118	24,988	55,050	52,983
Net income (loss)	53,327	46,333	109,466	102,848
Reclassification adjustment for gain (loss) on derivative instruments included in net income
Reclassification adjustment out of accumulated other comprehensive income [Line Items]
Income before income taxes	(23)	717	(570)	5,116
Income taxes	10	(322)	213	(1,948)
Net income (loss)	(13)	395	(357)	3,168
Amortization of postretirement liability losses included in net periodic benefit cost
Reclassification adjustment out of accumulated other comprehensive income [Line Items]
Net periodic benefit cost	(395)	(967)	(838)	(1,934)
Income taxes	150	543	318	862
Net income (loss)	(245)	(424)	(520)	(1,072)
Reclassification adjustment for loss on available-for-sale investments included in net income
Reclassification adjustment out of accumulated other comprehensive income [Line Items]
Other income	(49)	(66)	(49)	(121)
Income taxes	17	23	17	42
Net income (loss)	(32)	(43)	(32)	(79)
Total reclassifications
Reclassification adjustment out of accumulated other comprehensive income [Line Items]
Net income (loss)	(290)	(72)	(909)	2,017
Commodity derivative instruments [Member] | Reclassification adjustment for gain (loss) on derivative instruments included in net income
Reclassification adjustment out of accumulated other comprehensive income [Line Items]
Revenues	137	1,381	(250)	5,896
Interest rate derivative instruments [Member] | Reclassification adjustment for gain (loss) on derivative instruments included in net income
Reclassification adjustment out of accumulated other comprehensive income [Line Items]
Interest expense	$ (160)	$ (664)	$ (320)	$ (780)

XML

Seasonality of operations

6 Months Ended

Jun. 30, 2014

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Seasonality of operations

Seasonality of operations

Some of the Company's operations are highly seasonal and revenues from, and certain expenses for, such operations may fluctuate significantly among quarterly periods. Accordingly, the interim results for particular businesses, and for the Company as a whole, may not be indicative of results for the full fiscal year.

XML

Employee benefit plans (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Pension benefits [Member]
Defined benefit plan disclosure, net periodic benefit cost [Line Items]
Service cost	$ 31	$ 37	$ 64	$ 77
Interest cost	4,405	4,106	8,845	8,124
Expected return on assets	(5,484)	(4,875)	(10,609)	(9,958)
Amortization of prior service cost (credit)	18	18	36	36
Amortization of net actuarial loss	1,121	1,716	2,434	3,580
Net periodic benefit cost, including amount capitalized	91	1,002	770	1,859
Less amount capitalized	73	158	168	268
Net periodic benefit cost (credit)	18	844	602	1,591
Other postretirement benefits [Member]
Defined benefit plan disclosure, net periodic benefit cost [Line Items]
Service cost	380	334	759	838
Interest cost	924	667	1,782	1,607
Expected return on assets	(1,242)	(1,065)	(2,309)	(2,172)
Amortization of prior service cost (credit)	(348)	(364)	(696)	(728)
Amortization of net actuarial loss	6	407	324	1,078
Net periodic benefit cost, including amount capitalized	(280)	(21)	(140)	623
Less amount capitalized	(19)	61	10	90
Net periodic benefit cost (credit)	(261)	(82)	(150)	533
Supplemental employee retirement plans [Member]
Defined benefit plan disclosure, net periodic benefit cost [Line Items]
Net periodic benefit cost (credit)	$ 1,600	$ 1,800	$ 3,300	$ 3,600

XML

Impairment of long-lived assets (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Jun. 30, 2013
Asset Impairment Charges [Abstract]
Asset impairment charges	$ 14.5
Asset impairment charges (after tax)	$ 9.0

XML

Subsequent event

6 Months Ended

Jun. 30, 2014

Subsequent Events [Abstract]

Subsequent events [Text Block]

Subsequent Events

The Company entered into a $150.0 million note purchase agreement on January 28, 2014. On April 15, 2014, the Company issued $50.0 million of Senior Notes with a due date of April 15, 2044, at an interest rate of 5.2 percent. The remaining $100.0 million of Senior Notes was issued on July 15, 2014, with due dates ranging from July 15, 2024 to July 15, 2026, at a weighted average interest rate of 4.3 percent.

Fidelity entered into a purchase and sale agreement on July 17, 2014, to sell certain oil and natural gas properties in Mountrail County, North Dakota for a sale price of approximately $200.0 million, subject to accounting and purchase price adjustments customary with dispositions of this type. The effective date of the disposition is May 1, 2014, with the expected closing date to occur on or before September 30, 2014, conditioned upon the buyer completing a due diligence process, including environmental reviews, and both parties satisfying other standard closing conditions.

XML

Contingencies

6 Months Ended

Jun. 30, 2014

Commitments and Contingencies Disclosure [Abstract]

Contingencies

Contingencies

The Company is party to claims and lawsuits arising out of its business and that of its consolidated subsidiaries. The Company accrues a liability for those contingencies when the incurrence of a loss is probable and the amount can be reasonably estimated. If a range of amounts can be reasonably estimated and no amount within the range is a better estimate than any other amount, then the minimum of the range is accrued. The Company does not accrue liabilities when the likelihood that the liability has been incurred is probable but the amount cannot be reasonably estimated or when the liability is believed to be only reasonably possible or remote. For contingencies where an unfavorable outcome is probable or reasonably possible and which are material, the Company discloses the nature of the contingency and, in some circumstances, an estimate of the possible loss. The Company had accrued liabilities of $32.1 million, $32.9 million and $29.5 million for contingencies, including litigation, production taxes, royalty claims and environmental matters, at June 30, 2014 and 2013, and December 31, 2013, respectively, which include amounts that may have been accrued for matters discussed in Litigation and Environmental matters within this note.

Litigation

Guarantee Obligation Under a Construction Contract Centennial guaranteed CEM's obligations under a construction contract with LPP for a 550-MW combined-cycle electric generating facility near Hobbs, New Mexico. Centennial Resources sold CEM in July 2007 to Bicent. In February 2009, Centennial received a Notice and Demand from LPP under the guarantee agreement alleging that CEM did not meet certain of its obligations under the construction contract and demanding that Centennial indemnify LPP against all losses, damages, claims, costs, charges and expenses arising from CEM's alleged failures. In December 2009, LPP submitted a demand for arbitration of its dispute with CEM to the American Arbitration Association seeking compensatory damages of $149.7 million. An arbitration award was issued January 13, 2012, awarding LPP $22.0 million. Centennial subsequently received a demand from LPP for payment of the arbitration award plus interest and attorneys' fees. An accrual related to the guarantee as a result of the arbitration award was recorded in discontinued operations on the Consolidated Statement of Income in the fourth quarter of 2011. CEM filed a petition with the New York Supreme Court to vacate the arbitration award in favor of LPP. The New York Supreme Court granted CEM's petition to vacate the arbitration award on November 20, 2012, and entered an order and judgment to that effect on June 5, 2013. LPP appealed the order and judgment and on February 20, 2014, the New York Supreme Court Appellate Division ruled the arbitration award was properly vacated. LPP filed a motion with the New York Court of Appeals for leave to appeal the decision of the New York Supreme Court Appellate Division. The motion was denied on June 10, 2014. Due to the vacation of the arbitration award, the accrual that was previously recorded in 2011 was reversed in the fourth quarter of 2012. The effect of this was recorded in discontinued operations on the Consolidated Statement of Income. For more information regarding discontinued operations, see Note 11.

Construction MaterialsUntil the fall of 2011 when it discontinued active mining operations at the pit, JTL operated the Target Range Gravel Pit in Missoula County, Montana under a 1975 reclamation contract pursuant to the Montana Opencut Mining Act. In September 2009, the Montana DEQ sent a letter asserting JTL was in violation of the Montana Opencut Mining Act by conducting mining operations outside a permitted area. JTL filed a complaint in Montana First Judicial District Court in June 2010, seeking a declaratory order that the reclamation contract is a valid permit under the Montana Opencut Mining Act. The Montana DEQ filed an answer and counterclaim to the complaint in August 2011, alleging JTL was in violation of the Montana Opencut Mining Act and requesting imposition of penalties of not more than $3.7 million plus not more than $5,000 per day from the date of the counterclaim. The Company believes the operation of the Target Range Gravel Pit was conducted under a valid permit; however, the imposition of civil penalties is reasonably possible. The Company filed an application for amendment of its opencut mining permit and intends to resolve this matter through settlement or continuation of the Montana First Judicial District Court litigation.

Former Employee Litigation On August 6, 2012, a former employee and his spouse filed actions against Connolly-Pacific and others in California Superior Court alleging the former employee contracted acute myelogenous leukemia from exposure to substances while employed as a seaman by the defendants. The plaintiffs request compensatory damages of approximately $23.8 million plus punitive damages, costs and interest. Connolly-Pacific is contesting the claims and believes it has meritorious defenses to them. Connolly-Pacific will seek insurance coverage for defense costs and any liability incurred in the litigation.

Natural Gas Gathering Operations In January 2010, SourceGas filed an application with the Colorado State District Court to compel WBI Energy Midstream to arbitrate a dispute regarding operating pressures under a natural gas gathering contract on one of WBI Energy Midstream's pipeline gathering systems in Montana. WBI Energy Midstream resisted the application and sought a declaratory order interpreting the gathering contract. In May 2010, the Colorado State District Court granted the application and ordered WBI Energy Midstream into arbitration. In October 2010, the arbitration panel issued an award in favor of SourceGas for approximately $26.6 million. The Colorado Court of Appeals issued a decision on May 24, 2012, reversing the Colorado State District Court order compelling arbitration, vacating the final award and remanding the case to the Colorado State District Court to determine SourceGas's claims and WBI Energy Midstream's counterclaims. On remand of the matter to the Colorado State District Court, SourceGas may assert claims similar to those asserted in the arbitration proceeding.

In a related matter, Omimex filed a complaint against WBI Energy Midstream in Montana Seventeenth Judicial District Court in July 2010 alleging WBI Energy Midstream breached a separate gathering contract with Omimex as a result of the increased operating pressures demanded by SourceGas on the same natural gas gathering system. In December 2011, Omimex filed an amended complaint alleging WBI Energy Midstream breached obligations to operate its gathering system as a common carrier under United States and Montana law. WBI Energy Midstream removed the action to the United States District Court for the District of Montana. The parties subsequently settled the breach of contract claim and, subject to final determination on liability, stipulated to the damages on the common carrier claim, for amounts that are not material. A trial on the common carrier claim was held during July 2013, but a decision has not been issued.

Exploration and Production During the ordinary course of its business, Fidelity is subject to audit for various production related taxes by certain state and federal tax authorities for varying periods as well as claims for royalty obligations under lease agreements for oil and gas production. Disputes may exist regarding facts and questions of law relating to the tax and royalty obligations.

On May 15, 2013, Austin Holdings, LLC filed an action against Fidelity in Wyoming State District Court alleging Fidelity violated the Wyoming Royalty Payment Act and implied lease covenants by deducting production costs from and by failing to properly report and pay royalties for coalbed methane gas production in Wyoming. The plaintiff, in addition to declaratory and injunctive relief, seeks class certification for similarly situated persons and an unspecified amount of monetary damages on behalf of the class for unpaid royalties, interest, reporting violations and attorney fees. Fidelity believes it has meritorious defenses against class certification and the claims.

The Company also is subject to other litigation, and actual and potential claims in the ordinary course of its business which may include, but are not limited to, matters involving property damage, personal injury, and environmental, contractual, statutory and regulatory obligations. Accruals are based on the best information available but actual losses in future periods are affected by various factors making them uncertain. After taking into account liabilities accrued for the foregoing matters, management believes that the outcomes with respect to the above issues and other probable and reasonably possible losses in excess of the amounts accrued, while uncertain, will not have a material effect upon the Company's financial position, results of operations or cash flows.

Environmental matters

Portland Harbor Site In December 2000, Knife River - Northwest was named by the EPA as a PRP in connection with the cleanup of a riverbed site adjacent to a commercial property site acquired by Knife River - Northwest from Georgia-Pacific West, Inc. in 1999. The riverbed site is part of the Portland, Oregon, Harbor Superfund Site. The EPA wants responsible parties to share in the cleanup of sediment contamination in the Willamette River. To date, costs of the overall remedial investigation and feasibility study of the harbor site are being recorded, and initially paid, through an administrative consent order by the LWG, a group of several entities, which does not include Knife River - Northwest or Georgia-Pacific West, Inc. Investigative costs are indicated to be in excess of $70 million. It is not possible to estimate the cost of a corrective action plan until the remedial investigation and feasibility study have been completed, the EPA has decided on a strategy and a ROD has been published. Corrective action will be taken after the development of a proposed plan and ROD on the harbor site is issued. Knife River - Northwest also received notice in January 2008 that the Portland Harbor Natural Resource Trustee Council intends to perform an injury assessment to natural resources resulting from the release of hazardous substances at the Harbor Superfund Site. The Portland Harbor Natural Resource Trustee Council indicates the injury determination is appropriate to facilitate early settlement of damages and restoration for natural resource injuries. It is not possible to estimate the costs of natural resource damages until an assessment is completed and allocations are undertaken.

Based upon a review of the Portland Harbor sediment contamination evaluation by the Oregon DEQ and other information available, Knife River - Northwest does not believe it is a Responsible Party. In addition, Knife River - Northwest has notified Georgia-Pacific West, Inc., that it intends to seek indemnity for liabilities incurred in relation to the above matters pursuant to the terms of their sale agreement. Knife River - Northwest has entered into an agreement tolling the statute of limitations in connection with the LWG's potential claim for contribution to the costs of the remedial investigation and feasibility study. By letter in March 2009, LWG stated its intent to file suit against Knife River - Northwest and others to recover LWG's investigation costs to the extent Knife River - Northwest cannot demonstrate its non-liability for the contamination or is unwilling to participate in an alternative dispute resolution process that has been established to address the matter. At this time, Knife River - Northwest has agreed to participate in the alternative dispute resolution process.

The Company believes it is not probable that it will incur any material environmental remediation costs or damages in relation to the above referenced administrative action.

Manufactured Gas Plant Sites There are three claims against Cascade for cleanup of environmental contamination at manufactured gas plant sites operated by Cascade's predecessors.

The first claim is for contamination at a site in Eugene, Oregon which was received in 1995. There are PRPs in addition to Cascade that may be liable for cleanup of the contamination. Some of these PRPs have shared in the investigation costs. It is expected that these and other PRPs will share in the cleanup costs. Several alternatives for cleanup have been identified, with preliminary cost estimates ranging from approximately $500,000 to $11.0 million. The Oregon DEQ is preparing a staff report which will recommend a cleanup alternative for the site. It is not known at this time what share of the cleanup costs will actually be borne by Cascade; however, Cascade anticipates its proportional share could be approximately 50 percent. Cascade has accrued $1.7 million for remediation of this site. In January 2013, the OPUC approved Cascade's application to defer environmental remediation costs at the Eugene site for a period of 12 months starting November 30, 2012. Cascade received an order reauthorizing the deferred accounting for the 12 months starting November 30, 2013.

The second claim is for contamination at a site in Bremerton, Washington which was received in 1997. A preliminary investigation has found soil and groundwater at the site contain contaminants requiring further investigation and cleanup. EPA conducted a Targeted Brownfields Assessment of the site and released a report summarizing the results of that assessment in August 2009. The assessment confirms that contaminants have affected soil and groundwater at the site, as well as sediments in the adjacent Port Washington Narrows. Alternative remediation options have been identified with preliminary cost estimates ranging from $340,000 to $6.4 million. Data developed through the assessment and previous investigations indicates the contamination likely derived from multiple, different sources and multiple current and former owners of properties and businesses in the vicinity of the site may be responsible for the contamination. In April 2010, the Washington Department of Ecology issued notice it considered Cascade a PRP for hazardous substances at the site. In May 2012, the EPA added the site to the National Priorities List of Superfund sites. Cascade has entered into an administrative settlement agreement and consent order with the EPA regarding the scope and schedule for a remedial investigation and feasibility study for the site. Cascade has accrued $12.6 million for the remedial investigation, feasibility study and remediation of this site. In April 2010, Cascade filed a petition with the WUTC for authority to defer the costs, which are included in other noncurrent assets, incurred in relation to the environmental remediation of this site until the next general rate case. The WUTC approved the petition in September 2010, subject to conditions set forth in the order.

The third claim is for contamination at a site in Bellingham, Washington. Cascade received notice from a party in May 2008 that Cascade may be a PRP, along with other parties, for contamination from a manufactured gas plant owned by Cascade and its predecessor from about 1946 to 1962. The notice indicates that current estimates to complete investigation and cleanup of the site exceed $8.0 million. Other PRPs have reached an agreed order and work plan with the Washington Department of Ecology for completion of a remedial investigation and feasibility study for the site. A report documenting the initial phase of the remedial investigation was completed in June 2011. There is currently not enough information available to estimate the potential liability to Cascade associated with this claim although Cascade believes its proportional share of any liability will be relatively small in comparison to other PRPs. The plant manufactured gas from coal between approximately 1890 and 1946. In 1946, shortly after Cascade's predecessor acquired the plant, it converted the plant to a propane-air gas facility. There are no documented wastes or by-products resulting from the mixing or distribution of propane-air gas.

Cascade has received notices from and entered into agreement with certain of its insurance carriers that they will participate in defense of Cascade for these contamination claims subject to full and complete reservations of rights and defenses to insurance coverage. To the extent these claims are not covered by insurance, Cascade will seek recovery through the OPUC and WUTC of remediation costs in its natural gas rates charged to customers. The accruals related to these matters are reflected in regulatory assets.

Guarantees

Centennial guaranteed CEM's obligations under a construction contract. For more information, see Litigation in this note.

In connection with the sale of the Brazilian Transmission Lines, as discussed in Note 12, Centennial has agreed to guarantee payment of any indemnity obligations of certain of the Company's indirect wholly owned subsidiaries who are the sellers in three purchase and sale agreements for periods ranging up to 10 years from the date of sale. The guarantees were required by the buyers as a condition to the sale of the Brazilian Transmission Lines.

WBI Holdings has guaranteed certain of Fidelity's oil and natural gas swap agreement obligations. There is no fixed maximum amount guaranteed in relation to the oil and natural gas swap agreements as the amount of the obligation is dependent upon oil and natural gas commodity prices. The amount of derivative activity entered into by the subsidiary is limited by corporate policy. The guarantees of the oil and natural gas swap agreements at June 30, 2014, expire in the years ranging from 2014 to 2015; however, Fidelity continues to enter into additional derivative instruments and, as a result, WBI Holdings from time to time may issue additional guarantees on these derivative instruments. The amount outstanding by Fidelity was $14.5 million and was reflected on the Consolidated Balance Sheet at June 30, 2014. In the event Fidelity defaults under its obligations, WBI Holdings would be required to make payments under its guarantees.

Certain subsidiaries of the Company have outstanding guarantees to third parties that guarantee the performance of other subsidiaries of the Company. These guarantees are related to construction contracts, natural gas transportation and sales agreements, gathering contracts and certain other guarantees. At June 30, 2014, the fixed maximum amounts guaranteed under these agreements aggregated $76.7 million. The amounts of scheduled expiration of the maximum amounts guaranteed under these agreements aggregate $21.2 million in 2014; $35.7 million in 2015; $700,000 in 2016; $600,000 in 2017; $500,000 in 2018; $500,000 in 2019; $13.5 million, which is subject to expiration on a specified number of days after the receipt of written notice; and $4.0 million, which has no scheduled maturity date. The amount outstanding by subsidiaries of the Company under the above guarantees was $200,000 and was reflected on the Consolidated Balance Sheet at June 30, 2014. In the event of default under these guarantee obligations, the subsidiary issuing the guarantee for that particular obligation would be required to make payments under its guarantee.

Certain subsidiaries have outstanding letters of credit to third parties related to insurance policies and other agreements, some of which are guaranteed by other subsidiaries of the Company. At June 30, 2014, the fixed maximum amounts guaranteed under these letters of credit, aggregated $36.3 million. In 2014 and 2015, $7.0 million and $29.3 million, respectively, of letters of credit are scheduled to expire. There were no amounts outstanding under the above letters of credit at June 30, 2014.

WBI Holdings has an outstanding guarantee to WBI Energy Transmission. This guarantee is related to a natural gas transportation and storage agreement that guarantees the performance of Prairielands. At June 30, 2014, the fixed maximum amount guaranteed under this agreement was $4.0 million and is scheduled to expire in 2016. In the event of Prairielands' default in its payment obligations, WBI Holdings would be required to make payment under its guarantee. The amount outstanding by Prairielands under the above guarantee was $1.1 million. The amount outstanding under this guarantee was not reflected on the Consolidated Balance Sheet at June 30, 2014, because this intercompany transaction was eliminated in consolidation.

In addition, Centennial, Knife River and MDU Construction Services have issued guarantees to third parties related to the routine purchase of maintenance items, materials and lease obligations for which no fixed maximum amounts have been specified. These guarantees have no scheduled maturity date. In the event a subsidiary of the Company defaults under these obligations, Centennial, Knife River and MDU Construction Services would be required to make payments under these guarantees. Any amounts outstanding by subsidiaries of the Company for these guarantees were reflected on the Consolidated Balance Sheet at June 30, 2014.

In the normal course of business, Centennial has surety bonds related to construction contracts and reclamation obligations of its subsidiaries. In the event a subsidiary of Centennial does not fulfill a bonded obligation, Centennial would be responsible to the surety bond company for completion of the bonded contract or obligation. A large portion of the surety bonds is expected to expire within the next 12 months; however, Centennial will likely continue to enter into surety bonds for its subsidiaries in the future. At June 30, 2014, approximately $666.9 million of surety bonds were outstanding, which were not reflected on the Consolidated Balance Sheet.

Variable interest entities

The Company evaluates its arrangements and contracts with other entities to determine if they are VIEs and if so, if the Company is the primary beneficiary.

Dakota Prairie Refining, LLCOn February 7, 2013, WBI Energy and Calumet formed a limited liability company, Dakota Prairie Refining, and entered into an operating agreement to develop, build and operate Dakota Prairie Refinery in southwestern North Dakota. WBI Energy and Calumet each have a 50 percent ownership interest in Dakota Prairie Refining. WBI Energy's and Calumet's capital commitments, based on a total project cost of $300.0 million, under the agreement are $150.0 million and $75.0 million, respectively. Capital commitments in excess of $300.0 million are expected to be shared equally between WBI Energy and Calumet. The total project cost is currently estimated at $350 million. Dakota Prairie Refining entered into a term loan for project debt financing of $75.0 million on April 22, 2013. The operating agreement provides for allocation of profits and losses consistent with ownership interests; however, deductions attributable to project financing debt will be allocated to Calumet. Calumet's future cash distributions from Dakota Prairie Refining will be decreased by the principal and interest to be paid on the project debt, while the cash distributions to WBI Energy will not be decreased. Pursuant to the operating agreement, Centennial agreed to guarantee Dakota Prairie Refining's obligation under the term loan.

Dakota Prairie Refining has been determined to be a VIE, and the Company has determined that it is the primary beneficiary as it has an obligation to absorb losses that could be potentially significant to the VIE through WBI Energy's equity investment and Centennial's guarantee of the third-party term loan. Accordingly, the Company consolidates Dakota Prairie Refining in its financial statements and records a noncontrolling interest for Calumet's ownership interest.

Construction of Dakota Prairie Refinery began in early 2013 and the plant is not yet operational. Therefore, the results of operations of Dakota Prairie Refining did not have a material effect on the Company's Consolidated Statements of Income. The assets of Dakota Prairie Refining shall be used solely for the benefit of Dakota Prairie Refining. The total assets and liabilities of Dakota Prairie Refining reflected on the Company's Consolidated Balance Sheets were as follows:

	June 30, 2014		June 30, 2013		December 31, 2013
	(In thousands)
ASSETS
Current assets:
Cash and cash equivalents	$	32,283	$	63,089	$	4,774
Accounts receivable	—		5		—
Other current assets	2,136		—		26
Total current assets	34,419		63,094		4,800
Net property, plant and equipment	254,079		75,216		172,073
Total assets	$	288,498	$	138,310	$	176,873
LIABILITIES
Current liabilities:
Long-term debt due within one year	$	3,000	$	3,000	$	3,000
Accounts payable	28,150		21,057		8,904
Taxes payable	225		—		5
Accrued compensation	256		—		26
Other accrued liabilities	494		300		461
Total current liabilities	32,125		24,357		12,396
Long-term debt	69,000		72,000		72,000
Total liabilities	$	101,125	$	96,357	$	84,396

Fuel Contract On October 10, 2012, the Coyote Station entered into a new coal supply agreement with Coyote Creek that will replace a coal supply agreement expiring in May 2016. The new agreement provides for the purchase of coal necessary to supply the coal requirements of the Coyote Station for the period May 2016 through December 2040.

The new coal supply agreement creates a variable interest in Coyote Creek due to the transfer of all operating and economic risk to the Coyote Station owners, as the agreement is structured so the price of the coal will cover all costs of operations as well as future reclamation costs. The Coyote Station owners are also providing a guarantee of the value of the assets of Coyote Creek as they would be required to buy the assets at book value should they terminate the contract prior to the end of the contract term and are providing a guarantee of the value of the equity of Coyote Creek in that they are required to buy the entity at the end of the contract term at equity value. Although the Company has determined that Coyote Creek is a VIE, the Company has concluded that it is not the primary beneficiary of Coyote Creek because the authority to direct the activities of the entity is shared by the four unrelated owners of the Coyote Station, with no primary beneficiary existing. As a result, Coyote Creek is not required to be consolidated in the Company's financial statements.

At June 30, 2014, Coyote Creek was not yet operational. The assets and liabilities of Coyote Creek and exposure to loss as a result of the Company's involvement with the VIE, based on the Company's ownership percentage, at June 30, 2014, was $9.7 million.

XML

Available-for-sale securities (Details) (USD $)	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Available-for-sale securities [Line Items]
Investments used to satisfy obligations under nonqualified benefit plans	$ 64,400,000	$ 54,000,000	$ 64,400,000	$ 54,000,000	$ 62,400,000
Net unrealized gain (loss) of investments used to satify obligations under nonqualified benefit plans	1,100,000	700,000	2,000,000	5,100,000
Available-for-sale securities [Abstract]
Cost	10,055,000	9,955,000	10,055,000	9,955,000	10,057,000
Gross unrealized gains			121,000	73,000	84,000
Gross unrealized losses			(5,000)	(56,000)	(31,000)
Fair value	10,171,000	9,972,000	10,171,000	9,972,000	10,110,000
Mortgage backed securities [Member]
Available-for-sale securities [Abstract]
Cost	7,989,000	8,035,000	7,989,000	8,035,000	8,151,000
Gross unrealized gains			91,000	58,000	69,000
Gross unrealized losses			(5,000)	(41,000)	(27,000)
Fair value	8,075,000	8,052,000	8,075,000	8,052,000	8,193,000
US Treasury securities [Member]
Available-for-sale securities [Abstract]
Cost	2,066,000	1,920,000	2,066,000	1,920,000	1,906,000
Gross unrealized gains			30,000	15,000	15,000
Gross unrealized losses			0	(15,000)	(4,000)
Fair value	$ 2,096,000	$ 1,920,000	$ 2,096,000	$ 1,920,000	$ 1,917,000

XML

Earnings per common share (Details) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Earnings Per Share [Abstract]
Weighted average common shares outstanding - basic	192,060	188,831	190,946	188,831
Effect of dilutive performance share awards	599	632	597	629
Weighted average common shares outstanding - diluted	192,659	189,463	191,543	189,460
Shares excluded from the calculation of diluted earnings per share	0	0	0	0

XML

Inventories and natural gas in storage (Tables)

6 Months Ended

Jun. 30, 2014

Inventory Disclosure [Abstract]

Inventories

Inventories consisted of:

	June 30, 2014		June 30, 2013		December 31, 2013
	(In thousands)
Aggregates held for resale	$	112,129	$	103,503	$	101,568
Asphalt oil	76,525		91,837		38,099
Materials and supplies	70,938		74,648		69,808
Merchandise for resale	25,507		27,330		21,720
Natural gas in storage (current)	10,903		14,287		16,417
Other	35,420		34,280		34,779
Total	$	331,422	$	345,885	$	282,391

XML

Earnings per common share (Tables)

6 Months Ended

Jun. 30, 2014

Earnings Per Share [Abstract]

Weighted average common shares outstanding

A reconciliation of the weighted average common shares outstanding used in the basic and diluted earnings per share calculations was as follows:

	Three Months Ended		Six Months Ended
	June 30,		June 30,
	2014	2013	2014	2013
	(In thousands)
Weighted average common shares outstanding - basic	192,060	188,831	190,946	188,831
Effect of dilutive performance share awards	599	632	597	629
Weighted average common shares outstanding - diluted	192,659	189,463	191,543	189,460
Shares excluded from the calculation of diluted earnings per share	—	—	—	—

XML

Basis of presentation

6 Months Ended

Jun. 30, 2014

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of presentation

Basis of presentation

The accompanying consolidated interim financial statements were prepared in conformity with the basis of presentation reflected in the consolidated financial statements included in the Company's 2013 Annual Report, and the standards of accounting measurement set forth in the interim reporting guidance in the ASC and any amendments thereto adopted by the FASB. Interim financial statements do not include all disclosures provided in annual financial statements and, accordingly, these financial statements should be read in conjunction with those appearing in the 2013 Annual Report. The information is unaudited but includes all adjustments that are, in the opinion of management, necessary for a fair presentation of the accompanying consolidated interim financial statements and are of a normal recurring nature. Depreciation, depletion and amortization expense is reported separately on the Consolidated Statements of Income and therefore is excluded from the other line items within operating expenses. Management has also evaluated the impact of events occurring after June 30, 2014, up to the date of issuance of these consolidated interim financial statements.

XML

Cash flow information (Tables)

6 Months Ended

Jun. 30, 2014

Supplemental Cash Flow Information [Abstract]

Supplemental cash flow information

Cash expenditures for interest and income taxes were as follows:

	Six Months Ended
	June 30,
	2014		2013
	(In thousands)
Interest, net of amount capitalized	$	39,441	$	41,440
Income taxes paid (refunded), net	$	39,984	$	(2,649	)

Noncash investing transactions were as follows:

	June 30,
	2014		2013
	(In thousands)
Property, plant and equipment additions in accounts payable	$	95,833	$	77,073

XML

Contingencies Commitment and Contingencies Disclosure (Tables)

6 Months Ended

Jun. 30, 2014

Commitments and Contingencies Disclosure [Abstract]

Limited liability project reflected on consolidated balance sheet

The total assets and liabilities of Dakota Prairie Refining reflected on the Company's Consolidated Balance Sheets were as follows:

	June 30, 2014		June 30, 2013		December 31, 2013
	(In thousands)
ASSETS
Current assets:
Cash and cash equivalents	$	32,283	$	63,089	$	4,774
Accounts receivable	—		5		—
Other current assets	2,136		—		26
Total current assets	34,419		63,094		4,800
Net property, plant and equipment	254,079		75,216		172,073
Total assets	$	288,498	$	138,310	$	176,873
LIABILITIES
Current liabilities:
Long-term debt due within one year	$	3,000	$	3,000	$	3,000
Accounts payable	28,150		21,057		8,904
Taxes payable	225		—		5
Accrued compensation	256		—		26
Other accrued liabilities	494		300		461
Total current liabilities	32,125		24,357		12,396
Long-term debt	69,000		72,000		72,000
Total liabilities	$	101,125	$	96,357	$	84,396

XML

Gains and losses on derivative instruments (Details 2) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Derivative instruments [Line Items]
Amount of gain (loss) recognized in accumulated other comprehensive loss (effective portion), net of tax	$ 0	$ 254	$ 0	$ (5,594)
Amount of (gain) loss reclassified from accumulated other comprehensive loss (effective portion), net of tax	13	(395)	357	(3,168)
Commodity derivatives designated as cash flow hedges [Member]
Derivative instruments [Line Items]
Amount of gain (loss) recognized in accumulated other comprehensive loss (effective portion), net of tax	0	0	0	(6,154)
Amount of (gain) loss reclassified from accumulated other comprehensive loss (effective portion), net of tax	(86)	(871)	158	(3,714)
Amount of gain (loss) recognized in income statement (ineffective portion), before tax	0	0	0	(1,422)
Interest rate derivatives designated as cash flow hedges [Member]
Derivative instruments [Line Items]
Amount of gain (loss) recognized in accumulated other comprehensive loss (effective portion), net of tax	0	254	0	560
Amount of (gain) loss reclassified from accumulated other comprehensive loss (effective portion), net of tax	99	475	199	546
Amount of gain (loss) recognized in income statement (ineffective portion), before tax	0	(610)	0	(769)
Commodity derivatives not designated as hedging instruments:
Derivative instruments [Line Items]
Amount of gain (loss) recognized in operating revenues, before tax	$ (5,196)	$ 13,047	$ (11,908)	$ 8,637

XML

Consolidated Statements of Income (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Operating revenues:
Electric, natural gas distribution and pipeline and energy services	$ 254,689	$ 227,442	$ 746,231	$ 651,565
Exploration and production, construction materials and contracting, construction services and other	839,357	833,153	1,390,668	1,340,633
Total operating revenues	1,094,046	1,060,595	2,136,899	1,992,198
Operating expenses:
Fuel and purchased power	21,046	18,169	47,590	39,777
Purchased natural gas sold	84,415	70,255	329,307	269,442
Operation and maintenance:
Electric, natural gas distribution and pipeline and energy services	61,764	76,627	129,047	142,730
Exploration and production, construction materials and contracting, construction services and other	675,330	661,495	1,121,282	1,055,511
Depreciation, depletion and amortization	103,126	95,289	202,683	188,850
Taxes, other than income	49,431	47,382	105,152	99,979
Total operating expenses	995,112	969,217	1,935,061	1,796,289
Operating income	98,934	91,378	201,838	195,909
Loss from equity method investments	(297)	(7)	(245)	(319)
Other income	2,777	1,436	4,908	2,677
Interest expense	21,516	21,427	42,487	42,300
Income before income taxes	79,898	71,380	164,014	155,967
Income taxes	27,118	24,988	55,050	52,983
Income from continuing operations	52,780	46,392	108,964	102,984
Income (loss) from discontinued operations, net of tax (Note 11)	547	(59)	502	(136)
Net income	53,327	46,333	109,466	102,848
Net loss attributable to noncontrolling interest	(779)	(179)	(1,302)	(179)
Dividends declared on preferred stocks	171	171	342	342
Earnings on common stock	$ 53,935	$ 46,341	$ 110,426	$ 102,685
Earnings per common share - basic:
Earnings before discontinued operations	$ 0.28	$ 0.25	$ 0.58	$ 0.54
Discontinued operations, net of tax	$ 0.00	$ 0.00	$ 0.00	$ 0.00
Earnings per common share - basic	$ 0.28	$ 0.25	$ 0.58	$ 0.54
Earnings per common share - diluted:
Earnings before discontinued operations	$ 0.28	$ 0.24	$ 0.58	$ 0.54
Discontinued operations, net of tax	$ 0.00	$ 0.00	$ 0.00	$ 0.00
Earnings per common share - diluted	$ 0.28	$ 0.24	$ 0.58	$ 0.54
Dividends declared per common share	$ 0.1775	$ 0.1725	$ 0.3550	$ 0.3450
Weighted average common shares outstanding - basic	192,060	188,831	190,946	188,831
Weighted average common shares outstanding - diluted	192,659	189,463	191,543	189,460

XML

Cash flow information (Details) (USD $) In Thousands, unless otherwise specified	6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013
Supplemental Cash Flow Information [Abstract]
Interest, net of amount capitalized	$ 39,441	$ 41,440
Income taxes paid (refunded), net	39,984	(2,649)
Property, plant and equipment additions in accounts payable	$ 95,833	$ 77,073

XML

Consolidated Balance Sheets (Parenthetical) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2013
Stockholders' equity:
Common stock, shares authorized	500,000,000	500,000,000	500,000,000
Common stock, par value	$ 1.00	$ 1.00	$ 1.00
Common stock, shares issued	194,138,654	189,868,780	189,369,450
Treasury shares	538,921	538,921	538,921

XML

Long-term debt (Details) (USD $) In Millions, unless otherwise specified						0 Months Ended
	Jun. 30, 2014	Dec. 31, 2013	May 08, 2014 The Company [Member]	Apr. 15, 2014 The Company [Member]	Jan. 28, 2014 The Company [Member]	Apr. 02, 2014 Centennial Energy Holdings, Inc [Member]	Mar. 31, 2014 Centennial Energy Holdings, Inc [Member]	May 08, 2014 Centennial Energy Holdings, Inc [Member]	Jul. 15, 2014 Subsequent event [Member] The Company [Member]
Line of Credit Facility [Line Items]
Note purchase agreement					$ 150.0
Senior notes issued				50.0					100.0
Senior notes weighted average interest rate				5.20%					4.30%
Facility, maximum borrowing capacity			175.0					650.0
Ratio of total debt to total capitalization as specified in debt convenants						65.00%	65.00%	65.00%
Debt instrument, term						2 years	2 years
Term loan agreement						125.0	125.0
Long-term commercial paper	$ 268.0	$ 153.9

XML

Derivative instruments (Tables)

6 Months Ended

Jun. 30, 2014

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of derivative instruments, gain (losses)

The gains and losses on derivative instruments were as follows:

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2014			2013			2014			2013
	(In thousands)
Commodity derivatives designated as cash flow hedges:
Amount of loss recognized in accumulated other comprehensive loss (effective portion), net of tax	$	—		$	—		$	—		$	(6,154	)
Amount of (gain) loss reclassified from accumulated other comprehensive loss into operating revenues (effective portion), net of tax	(86		)	(871		)	158			(3,714		)
Amount of loss recognized in operating revenues (ineffective portion), before tax	—			—			—			(1,422		)
Interest rate derivatives designated as cash flow hedges:
Amount of gain recognized in accumulated other comprehensive loss (effective portion), net of tax	—			254			—			560
Amount of loss reclassified from accumulated other comprehensive loss into interest expense (effective portion), net of tax	99			475			199			546
Amount of loss recognized in interest expense (ineffective portion), before tax	—			(610		)	—			(769		)
Commodity derivatives not designated as hedging instruments:
Amount of gain (loss) recognized in operating revenues, before tax	(5,196		)	13,047			(11,908		)	8,637

Derivative instruments

The location and fair value of the gross amount of the Company's derivative instruments on the Consolidated Balance Sheets were as follows:

Asset Derivatives	Location on Consolidated Balance Sheets	Fair Value at June 30, 2014		Fair Value at June 30, 2013		Fair Value at December 31, 2013
		(In thousands)
Not designated as hedges:
Commodity derivatives	Commodity derivative instruments	$	129	$	9,797	$	1,447
	Other assets - noncurrent	131		1,447		503
Total asset derivatives		$	260	$	11,244	$	1,950

Liability Derivatives	Location on Consolidated Balance Sheets	Fair Value at June 30, 2014		Fair Value at June 30, 2013		Fair Value at December 31, 2013
		(In thousands)
Not designated as hedges:
Commodity derivatives	Commodity derivative instruments	$	17,449	$	1,388	$	7,483
Total liability derivatives		$	17,449	$	1,388	$	7,483

Offsetting assets and liabilities master netting

The gross derivative assets and liabilities (excluding settlement receivables and payables that may be subject to the same master netting agreements) presented on the Consolidated Balance Sheets and the amount eligible for offset under the master netting agreements is presented in the following table:

June 30, 2014	Gross Amounts Recognized on the Consolidated Balance Sheets		Gross Amounts Not Offset on the Consolidated Balance Sheets			Net
	(In thousands)
Assets:
Commodity derivatives	$	260	$	(260	)	$	—
Total assets	$	260	$	(260	)	$	—
Liabilities:
Commodity derivatives	$	17,449	$	(260	)	$	17,189
Total liabilities	$	17,449	$	(260	)	$	17,189

June 30, 2013	Gross Amounts Recognized on the Consolidated Balance Sheets		Gross Amounts Not Offset on the Consolidated Balance Sheets			Net
	(In thousands)
Assets:
Commodity derivatives	$	11,244	$	(1,388	)	$	9,856
Total assets	$	11,244	$	(1,388	)	$	9,856
Liabilities:
Commodity derivatives	$	1,388	$	(1,388	)	$	—
Total liabilities	$	1,388	$	(1,388	)	$	—

December 31, 2013	Gross Amounts Recognized on the Consolidated Balance Sheets		Gross Amounts Not Offset on the Consolidated Balance Sheets			Net
	(In thousands)
Assets:
Commodity derivatives	$	1,950	$	(1,950	)	$	—
Total assets	$	1,950	$	(1,950	)	$	—
Liabilities:
Commodity derivatives	$	7,483	$	(1,950	)	$	5,533
Total liabilities	$	7,483	$	(1,950	)	$	5,533

XML

Enviromental matters (Details 2) (USD $)	6 Months Ended
	Jun. 30, 2014
Portland Harbor Site [Member]
Site Contingency [Line Items]
Environmental matters investigative costs	$ 70,000,000
Eugene,OR Manufactured Gas Plant Site [Member]
Site Contingency [Line Items]
Site contingency, low estimate, loss exposure	500,000
Site contingency, high estimate, loss exposure	11,000,000
Estimated proportional share of cleanup liability	50.00%
Accrual for environmental loss contingencies	1,700,000
Bremerton, WA Manufactured Gas Plant Site [Member]
Site Contingency [Line Items]
Site contingency, low estimate, loss exposure	340,000
Site contingency, high estimate, loss exposure	6,400,000
Accrual for environmental loss contingencies	12,600,000
Bellingham, WA Manufactured Gas Plant Site [Member]
Site Contingency [Line Items]
Site contingency, loss exposure not accrued, best estimate	$ 8,000,000

XML

Fair value measurements

6 Months Ended

Jun. 30, 2014

Fair Value Disclosures [Abstract]

Fair value measurements

Fair value measurements

The Company measures its investments in certain fixed-income and equity securities at fair value with changes in fair value recognized in income. The Company anticipates using these investments, which consist of an insurance contract, 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, which totaled $64.4 million, $54.0 million and $62.4 million, at June 30, 2014 and 2013, and December 31, 2013, respectively, are classified as Investments on the Consolidated Balance Sheets. The net unrealized gains on these investments were $1.1 million and $2.0 million for the three and six months ended June 30, 2014, respectively. The net unrealized gains on these investments were $700,000 and $5.1 million for the three and six months ended June 30, 2013, respectively. The change in fair value, which is considered part of the cost of the plan, is classified in operation and maintenance expense on the Consolidated Statements of Income.

The Company did not elect the fair value option, which records gains and losses in income, for its available-for-sale securities, which include mortgage-backed securities and U.S. Treasury securities. These available-for-sale securities are recorded at fair value and are classified as Investments on the Consolidated Balance Sheets. Unrealized gains or losses are recorded in accumulated other comprehensive income (loss). Details of available-for-sale securities were as follows:

June 30, 2014	Cost		Gross Unrealized Gains		Gross Unrealized Losses			Fair Value
	(In thousands)
Mortgage-backed securities	$	7,989	$	91	$	(5	)	$	8,075
U.S. Treasury securities	2,066		30		—			2,096
Total	$	10,055	$	121	$	(5	)	$	10,171

June 30, 2013	Cost		Gross Unrealized Gains		Gross Unrealized Losses			Fair Value
	(In thousands)
Mortgage-backed securities	$	8,035	$	58	$	(41	)	$	8,052
U.S. Treasury securities	1,920		15		(15		)	1,920
Total	$	9,955	$	73	$	(56	)	$	9,972

December 31, 2013	Cost		Gross Unrealized Gains		Gross Unrealized Losses			Fair Value
	(In thousands)
Mortgage-backed securities	$	8,151	$	69	$	(27	)	$	8,193
U.S. Treasury securities	1,906		15		(4		)	1,917
Total	$	10,057	$	84	$	(31	)	$	10,110

The fair value of the Company's money market funds approximates cost.

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability (an exit price) in an orderly transaction between market participants at the measurement date. The ASC establishes a hierarchy for grouping assets and liabilities, based on the significance of inputs.

The estimated fair values of the Company's assets and liabilities measured on a recurring basis are determined using the market approach.

The Company's Level 2 money market funds consist of investments in short-term unsecured promissory notes and the value is based on comparable market transactions taking into consideration the credit quality of the issuer. The estimated fair value of the Company's Level 2 mortgage-backed securities and U.S. Treasury securities are based on comparable market transactions, other observable inputs or other sources, including pricing from outside sources.

The estimated fair value of the Company's Level 2 insurance contract is based on contractual cash surrender values that are determined primarily by investments in managed separate accounts of the insurer. These amounts approximate fair value. The managed separate accounts are valued based on other observable inputs or corroborated market data.

The estimated fair value of the Company's Level 2 commodity derivative instruments is based upon futures prices, volatility and time to maturity, among other things. Counterparty statements are utilized to determine the value of the commodity derivative instruments and are reviewed and corroborated using various methodologies and significant observable inputs. The Company's and the counterparties' nonperformance risk is also evaluated.

The estimated fair value of the Company's Level 2 interest rate derivative instruments is measured using quoted market prices or pricing models using prevailing market interest rates as of the measurement date. Counterparty statements are utilized to determine the value of the interest rate derivative instruments and are reviewed and corroborated using various methodologies and significant observable inputs. The Company's and the counterparties' nonperformance risk is also evaluated.

Though the Company believes the methods used to estimate fair value are consistent with those used by other market participants, the use of other methods or assumptions could result in a different estimate of fair value. For the six months ended June 30, 2014 and 2013, there were no transfers between Levels 1 and 2.

The Company's assets and liabilities measured at fair value on a recurring basis were as follows:

	Fair Value Measurements at June 30, 2014, Using
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Balance at June 30, 2014
	(In thousands)
Assets:
Money market funds	$	—	$	19,990	$	—	$	19,990
Insurance contract*	—		64,449		—		64,449
Available-for-sale securities:
Mortgage-backed securities	—		8,075		—		8,075
U.S. Treasury securities	—		2,096		—		2,096
Commodity derivative instruments	—		260		—		260
Total assets measured at fair value	$	—	$	94,870	$	—	$	94,870
Liabilities:
Commodity derivative instruments	$	—	$	17,449	$	—	$	17,449
Total liabilities measured at fair value	$	—	$	17,449	$	—	$	17,449

*  The insurance contract invests approximately 21 percent in common stock of mid-cap companies, 18 percent in common stock of small-cap companies, 29 percent in common stock of large-cap companies, 31 percent in fixed-income investments and 1 percent in cash equivalents.

	Fair Value Measurements at June 30, 2013, Using
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Balance at June 30, 2013
	(In thousands)
Assets:
Money market funds	$	—	$	29,902	$	—	$	29,902
Insurance contract*	—		54,039		—		54,039
Available-for-sale securities:
Mortgage-backed securities	—		8,052		—		8,052
U.S. Treasury securities	—		1,920		—		1,920
Commodity derivative instruments	—		11,244		—		11,244
Total assets measured at fair value	$	—	$	105,157	$	—	$	105,157
Liabilities:
Commodity derivative instruments	$	—	$	1,388	$	—	$	1,388
Total liabilities measured at fair value	$	—	$	1,388	$	—	$	1,388

*  The insurance contract invests approximately 28 percent in common stock of mid-cap companies, 28 percent in common stock of small-cap companies, 28 percent in common stock of large-cap companies and 16 percent in fixed-income investments.

	Fair Value Measurements at December 31, 2013, Using
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs  (Level 3)		Balance at December 31, 2013
	(In thousands)
Assets:
Money market funds	$	—	$	19,227	$	—	$	19,227
Insurance contract*	—		62,370		—		62,370
Available-for-sale securities:
Mortgage-backed securities	—		8,193		—		8,193
U.S. Treasury securities	—		1,917		—		1,917
Commodity derivative instruments	—		1,950		—		1,950
Total assets measured at fair value	$	—	$	93,657	$	—	$	93,657
Liabilities:
Commodity derivative instruments	$	—	$	7,483	$	—	$	7,483
Total liabilities measured at fair value	$	—	$	7,483	$	—	$	7,483

* The insurance contract invests approximately 29 percent in common stock of mid-cap companies, 28 percent in common stock of small-cap companies, 28 percent in common stock of large-cap companies and 15 percent in fixed-income investments.

The Company applies the provisions of the fair value measurement standard to its nonrecurring, non-financial measurements, including long-lived asset impairments. These assets are not measured at fair value on an ongoing basis but are subject to fair value adjustments only in certain circumstances. The Company reviews the carrying value of its long-lived assets, excluding goodwill and oil and natural gas properties, whenever events or changes in circumstances indicate that such carrying amounts may not be recoverable. During the second quarter of 2013, coalbed natural gas gathering assets were reviewed for impairment and found to be impaired and were written down to their estimated fair value using the income approach. Under this approach, fair value is determined by using the present value of future estimated cash flows. The factors used to determine the estimated future cash flows include, but are not limited to, internal estimates of gathering revenue, future commodity prices and operating costs and equipment salvage values. The estimated cash flows are discounted using a rate that approximates the weighted average cost of capital of a market participant. These fair value inputs are not typically observable. At June 30, 2013, coalbed natural gas gathering assets were written down to the nonrecurring fair value measurement of $9.7 million. The fair value of these coalbed natural gas gathering assets have been categorized as Level 3 (Significant Unobservable Inputs) in the fair value hierarchy.

The Company's long-term debt is not measured at fair value on the Consolidated Balance Sheets and the fair value is being provided for disclosure purposes only. The fair value was based on discounted future cash flows using current market interest rates. The estimated fair value of the Company's Level 2 long-term debt was as follows:

	Carrying Amount		Fair Value
	(In thousands)
Long-term debt at June 30, 2014	$	2,187,094	$	2,283,351
Long-term debt at June 30, 2013	$	2,006,754	$	2,090,208
Long-term debt at December 31, 2013	$	1,854,563	$	1,912,590

The carrying amounts of the Company's remaining financial instruments included in current assets and current liabilities approximate their fair values.

XML

Fair value measurements (Tables)

6 Months Ended

Jun. 30, 2014

Fair Value Disclosures [Abstract]

Available-for-sale securities

Details of available-for-sale securities were as follows:

June 30, 2014	Cost		Gross Unrealized Gains		Gross Unrealized Losses			Fair Value
	(In thousands)
Mortgage-backed securities	$	7,989	$	91	$	(5	)	$	8,075
U.S. Treasury securities	2,066		30		—			2,096
Total	$	10,055	$	121	$	(5	)	$	10,171

June 30, 2013	Cost		Gross Unrealized Gains		Gross Unrealized Losses			Fair Value
	(In thousands)
Mortgage-backed securities	$	8,035	$	58	$	(41	)	$	8,052
U.S. Treasury securities	1,920		15		(15		)	1,920
Total	$	9,955	$	73	$	(56	)	$	9,972

December 31, 2013	Cost		Gross Unrealized Gains		Gross Unrealized Losses			Fair Value
	(In thousands)
Mortgage-backed securities	$	8,151	$	69	$	(27	)	$	8,193
U.S. Treasury securities	1,906		15		(4		)	1,917
Total	$	10,057	$	84	$	(31	)	$	10,110

Assets and liabilities measured at fair value on a recurring basis

The Company's assets and liabilities measured at fair value on a recurring basis were as follows:

	Fair Value Measurements at June 30, 2014, Using
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Balance at June 30, 2014
	(In thousands)
Assets:
Money market funds	$	—	$	19,990	$	—	$	19,990
Insurance contract*	—		64,449		—		64,449
Available-for-sale securities:
Mortgage-backed securities	—		8,075		—		8,075
U.S. Treasury securities	—		2,096		—		2,096
Commodity derivative instruments	—		260		—		260
Total assets measured at fair value	$	—	$	94,870	$	—	$	94,870
Liabilities:
Commodity derivative instruments	$	—	$	17,449	$	—	$	17,449
Total liabilities measured at fair value	$	—	$	17,449	$	—	$	17,449

*  The insurance contract invests approximately 21 percent in common stock of mid-cap companies, 18 percent in common stock of small-cap companies, 29 percent in common stock of large-cap companies, 31 percent in fixed-income investments and 1 percent in cash equivalents.

	Fair Value Measurements at June 30, 2013, Using
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Balance at June 30, 2013
	(In thousands)
Assets:
Money market funds	$	—	$	29,902	$	—	$	29,902
Insurance contract*	—		54,039		—		54,039
Available-for-sale securities:
Mortgage-backed securities	—		8,052		—		8,052
U.S. Treasury securities	—		1,920		—		1,920
Commodity derivative instruments	—		11,244		—		11,244
Total assets measured at fair value	$	—	$	105,157	$	—	$	105,157
Liabilities:
Commodity derivative instruments	$	—	$	1,388	$	—	$	1,388
Total liabilities measured at fair value	$	—	$	1,388	$	—	$	1,388

*  The insurance contract invests approximately 28 percent in common stock of mid-cap companies, 28 percent in common stock of small-cap companies, 28 percent in common stock of large-cap companies and 16 percent in fixed-income investments.

	Fair Value Measurements at December 31, 2013, Using
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs  (Level 3)		Balance at December 31, 2013
	(In thousands)
Assets:
Money market funds	$	—	$	19,227	$	—	$	19,227
Insurance contract*	—		62,370		—		62,370
Available-for-sale securities:
Mortgage-backed securities	—		8,193		—		8,193
U.S. Treasury securities	—		1,917		—		1,917
Commodity derivative instruments	—		1,950		—		1,950
Total assets measured at fair value	$	—	$	93,657	$	—	$	93,657
Liabilities:
Commodity derivative instruments	$	—	$	7,483	$	—	$	7,483
Total liabilities measured at fair value	$	—	$	7,483	$	—	$	7,483

* The insurance contract invests approximately 29 percent in common stock of mid-cap companies, 28 percent in common stock of small-cap companies, 28 percent in common stock of large-cap companies and 15 percent in fixed-income investments.

Fair value of long term debt outstanding

The estimated fair value of the Company's Level 2 long-term debt was as follows:

	Carrying Amount		Fair Value
	(In thousands)
Long-term debt at June 30, 2014	$	2,187,094	$	2,283,351
Long-term debt at June 30, 2013	$	2,006,754	$	2,090,208
Long-term debt at December 31, 2013	$	1,854,563	$	1,912,590

XML

Equity

6 Months Ended

Jun. 30, 2014

Equity [Abstract]

Equity

Equity

A summary of the changes in equity was as follows:

Six Months Ended June 30, 2014	Total Stockholders' Equity			Noncontrolling Interest			Total Equity
	(In thousands)
Balance at December 31, 2013	$	2,823,164		$	32,738		$	2,855,902
Net income (loss)	110,768			(1,302		)	109,466
Other comprehensive income	1,007			—			1,007
Dividends declared on preferred stocks	(342		)	—			(342		)
Dividends declared on common stock	(68,025		)	—			(68,025		)
Stock-based compensation	2,796			—			2,796
Issuance of common stock upon vesting of performance shares, net of shares used for tax withholdings	(5,564		)	—			(5,564		)
Net tax benefit on stock-based compensation	4,729			—			4,729
Issuance of common stock	131,973			—			131,973
Contribution from noncontrolling interest	—			32,500			32,500
Balance at June 30, 2014	$	3,000,506		$	63,936		$	3,064,442

Six Months Ended June 30, 2013	Total Stockholders' Equity			Noncontrolling Interest			Total Equity
	(In thousands)
Balance at December 31, 2012	$	2,648,248		$	—		$	2,648,248
Net income (loss)	103,027			(179		)	102,848
Other comprehensive loss	(8,100		)	—			(8,100		)
Dividends declared on preferred stocks	(342		)	—			(342		)
Dividends declared on common stock	(65,147		)	—			(65,147		)
Stock-based compensation	2,453			—			2,453
Net tax deficit on stock-based compensation	(1,419		)	—			(1,419		)
Contribution from noncontrolling interest	—			16,101			16,101
Balance at June 30, 2013	$	2,678,720		$	15,922		$	2,694,642

XML

Subsequent event (Details) (USD $) In Millions, unless otherwise specified	Apr. 15, 2014 The Company [Member]	Jan. 28, 2014 The Company [Member]	Jul. 17, 2014 Subsequent event [Member]	Jul. 15, 2014 Subsequent event [Member] The Company [Member]
Subsequent Event [Line Items]
Note purchase agreement		$ 150.0
Senior notes issued	50.0			100.0
Senior notes weighted average interest rate	5.20%			4.30%
Significant disposal, or sale proceeds			$ 200.0

XML

Consolidated Statements of Cash Flows (USD $) In Thousands, unless otherwise specified	6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013
Operating activities:
Net income	$ 109,466	$ 102,848
Income (loss) from discontinued operations, net of tax	502	(136)
Income from continuing operations	108,964	102,984
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	202,683	188,850
Loss, net of distributions, from equity method investments	245	1,491
Deferred income taxes	60,141	19,790
Unrealized (gain) loss on commodity derivatives	11,908	(7,215)
Excess tax benefit on stock-based compensation	(4,729)	0
Changes in current assets and liabilities, net of acquisitions:
Receivables	(8,501)	(65,637)
Inventories	(48,857)	(29,923)
Other current assets	(37,460)	(18,044)
Accounts payable	(23,277)	18,940
Other current liabilities	(36,447)	23,071
Other noncurrent changes	(13,638)	(741)
Net cash provided by continuing operations	211,032	233,566
Net cash provided by (used in) discontinued operations	(491)	360
Net cash provided by operating activities	210,541	233,926
Investing activities:
Capital expenditures	(390,126)	(431,439)
Acquisitions, net of cash acquired	(206,304)	0
Net proceeds from sale or disposition of property and other	11,917	20,884
Investments	(1,208)	16
Net cash used in continuing operations	(585,721)	(410,539)
Net cash provided by discontinued operations	0	0
Net cash used in investing activities	(585,721)	(410,539)
Financing activities:
Issuance of short-term borrowings	0	29,600
Repayment of short-term borrowings	(11,500)	0
Issuance of long-term debt	441,447	450,461
Repayment of long-term debt	(111,539)	(214,473)
Proceeds from issuance of common stock	132,268	0
Dividends paid	(67,717)	(32,915)
Excess tax benefit on stock-based compensation	4,729	0
Contribution from noncontrolling interest	32,500	10,000
Net cash provided by continuing operations	420,188	242,673
Net cash provided by discontinued operations	0	0
Net cash provided by financing activities	420,188	242,673
Effect of exchange rate changes on cash and cash equivalents	85	(131)
Increase in cash and cash equivalents	45,093	65,929
Cash and cash equivalents - beginning of year	45,225	49,042
Cash and cash equivalents - end of period	$ 90,318	$ 114,971

XML

Consolidated Statements of Comprehensive Income (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Consolidated Statements of Comprehensive Income [Abstract]
Net income	$ 53,327	$ 46,333	$ 109,466	$ 102,848
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 $0 and $52 for the three months ended and $0 and $(3,116) for the six months ended in 2014 and 2013, respectively	0	254	0	(5,594)
Reclassification adjustment for (gain) loss on derivative instruments included in net income, net of tax of $10 and $(322) for the three months ended and $213 and $(1,948) for the six months ended in 2014 and 2013, respectively	13	(395)	357	(3,168)
Net unrealized gain (loss) on derivative instruments qualifying as hedges	13	(141)	357	(8,762)
Amortization of postretirement liability losses included in net periodic benefit cost, net of tax of $150 and $543 for the three months ended and $318 and $862 for the six months ended in 2014 and 2013, respectively	245	424	520	1,072
Foreign currency translation adjustment recognized during the period, net of tax of $26 and $(234) for the three months ended and $54 and $(197) for the six months ended in 2014 and 2013, respectively	42	(390)	88	(302)
Net unrealized gain (loss) on available-for-sale investments:
Net unrealized gain (loss) on available-for-sale investments arising during the period, net of tax of $4 and $(77) for the three months ended and $5 and $(100) for the six months ended in 2014 and 2013, respectively	8	(142)	10	(187)
Reclassification adjustment for loss on available-for-sale investments included in net income, net of tax of $17 and $23 for the three months ended and $17 and $42 for the six months ended in 2014 and 2013, respectively	32	43	32	79
Net unrealized gain (loss) on available-for-sale investments	40	(99)	42	(108)
Other comprehensive income (loss)	340	(206)	1,007	(8,100)
Comprehensive income	53,667	46,127	110,473	94,748
Comprehensive loss attributable to noncontrolling interest	(779)	(179)	(1,302)	(179)
Comprehensive income attributable to common stockholders	$ 54,446	$ 46,306	$ 111,775	$ 94,927

XML

Acquisition

6 Months Ended

Jun. 30, 2014

Business Combinations [Abstract]

Acquisition

Acquisition

On February 10, 2014, the Company entered into agreements to purchase working interests and leasehold positions in oil and natural gas production assets in the southern Powder River Basin of Wyoming. The effective date of the acquisition was October 1, 2013, and the closing occurred on March 6, 2014. The purchase price was $206.3 million, including purchase price adjustments.

The acquisition was accounted for under the acquisition method of accounting and, accordingly, the acquired assets and liabilities assumed have been recorded at their respective fair values as of the date of acquisition. The results of operations of the acquired properties are included in the financial statements since the date of the acquisition. Pro forma financial amounts reflecting the effects of the acquisition are not presented, as such acquisition was not material to the Company's financial position or results of operations.

XML

Document And Entity Information	6 Months Ended
	Jun. 30, 2014	Aug. 01, 2014
Entity Information [Line Items]
Entity registrant name	MDU RESOURCES GROUP INC
Entity central index key	0000067716
Current fiscal year end date	--12-31
Entity filer category	Large Accelerated Filer
Entity common stock, shares outstanding		193,946,489
Document fiscal year focus	2014
Document fiscal period focus	Q2
Document type	10-Q
Amendment flag	false
Document period end date	Jun. 30, 2014

XML

Discontinued operations

6 Months Ended

Jun. 30, 2014

Discontinued Operations and Disposal Groups [Abstract]

Discontinued operations

Discontinued operations

In 2007, Centennial Resources sold CEM to Bicent. In connection with the sale, Centennial Resources agreed to indemnify Bicent and its affiliates from certain third party claims arising out of or in connection with Centennial Resources' ownership or operation of CEM prior to the sale. In addition, Centennial had previously guaranteed CEM's obligations under a construction contract. The Company incurs legal expenses and had a benefit related to the resolution of this matter in the second quarter of 2014, which are reflected in discontinued operations in the consolidated financial statements and accompanying notes. Discontinued operations are included in the Other category. For more information, see Note 21.

XML

Consolidated Statements of Comprehensive Income - Parenthetical (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Net unrealized gain (loss) on derivative instruments arising during the period, tax	$ 0	$ 52	$ 0	$ (3,116)
Reclassification adjustment for (gain) loss on derivative instruments included in net income, tax	10	(322)	213	(1,948)
Amortization of postretirement liability losses included in net periodic benefit cost, tax	150	543	318	862
Foreign currency translation adjustments arising during the period, tax	26	(234)	54	(197)
Net unrealized gain (loss) on available-for-sale investments arising during the period, tax	4	(77)	5	(100)
Reclassification adjustment for loss (gain) on available-for-sale investments included in net income, tax	$ 17	$ 23	$ 17	$ 42

XML

Impairment of long-lived assets

6 Months Ended

Jun. 30, 2014

Asset Impairment Charges [Abstract]

Impairment of long-lived assets

Impairment of long-lived assets

During the second quarter of 2013, the Company recognized an impairment of coalbed natural gas gathering assets at the pipeline and energy services segment of $14.5 million ($9.0 million after tax), which is recorded in operation and maintenance expense on the Consolidated Statements of Income. The impairment is related to coalbed natural gas gathering assets located in Wyoming and Montana where there has been a significant decline in natural gas development and production activity largely due to low natural gas prices. The coalbed natural gas gathering assets were written down to fair value that was determined using the income approach. For more information on this nonrecurring fair value measurement, see Note 15.

XML

Inventories and natural gas in storage

6 Months Ended

Jun. 30, 2014

Inventory Disclosure [Abstract]

Inventories and natural gas in storage

Inventories and natural gas in storage

Inventories, other than natural gas in storage for the Company's regulated operations, are stated at the lower of average cost or market value. Natural gas in storage for the Company's regulated operations is generally carried at average cost, or cost using the last-in, first-out method. The portion of the cost of natural gas in storage expected to be used within one year is included in inventories. Inventories consisted of:

	June 30, 2014		June 30, 2013		December 31, 2013
	(In thousands)
Aggregates held for resale	$	112,129	$	103,503	$	101,568
Asphalt oil	76,525		91,837		38,099
Materials and supplies	70,938		74,648		69,808
Merchandise for resale	25,507		27,330		21,720
Natural gas in storage (current)	10,903		14,287		16,417
Other	35,420		34,280		34,779
Total	$	331,422	$	345,885	$	282,391

The remainder of natural gas in storage, which largely represents the cost of gas required to maintain pressure levels for normal operating purposes, is included in other assets and was $47.4 million, $48.6 million and $48.3 million at June 30, 2014 and 2013, and December 31, 2013, respectively.

XML

Long-term debt

6 Months Ended

Jun. 30, 2014

Debt Disclosure [Abstract]

Long-term debt

Long-term debt

On May 8, 2014, the Company amended its revolving credit agreement to increase the borrowing limit to $175.0 million and extend the termination date to May 8, 2019.

The Company entered into a $150.0 million note purchase agreement on January 28, 2014, and issued $50.0 million of Senior Notes on April 15, 2014, with a due date of April 15, 2044, at an interest rate of 5.2 percent. The remaining $100.0 million of Senior Notes was issued on July 15, 2014, with due dates ranging from July 15, 2024 to July 15, 2026, at a weighted average interest rate of 4.3 percent.

On May 8, 2014, Centennial entered into an amended and restated revolving credit agreement which increased the borrowing limit to $650.0 million and extended the termination date to May 8, 2019. The credit agreement contains customary covenants and provisions, including a covenant of Centennial not to permit, as of the end of any fiscal quarter, the ratio of total consolidated debt to total consolidated capitalization to be greater than 65 percent. Other covenants include restrictions on the sale of certain assets, limitations on subsidiary indebtedness and the making of certain loans and investments.

Centennial's revolving credit agreement contains cross-default provisions. These provisions state that if Centennial or any subsidiary of Centennial fails to make any payment with respect to any indebtedness or contingent obligation, in excess of a specified amount, under any agreement that causes such indebtedness to be due prior to its stated maturity or the contingent obligation to become payable, then Centennial will be in default under the revolving credit agreement.

Centennial entered into two separate two year $125.0 million term loan agreements with variable interest rates on March 31, 2014 and April 2, 2014, respectively. These agreements contain customary covenants and default provisions, including covenants not to permit, as of the end of any fiscal quarter, the ratio of Centennial's total debt to total capitalization to be greater than 65 percent. The covenants also include certain limitations on subsidiary indebtedness and restrictions on the sale of certain assets and on the making of certain loans and investments.

In addition, borrowings outstanding that were classified as long-term debt under the Company’s and Centennial’s commercial paper programs totaled $268.0 million at June 30, 2014, compared to $153.9 million at December 31, 2013, respectively.

XML

Equity method investments

6 Months Ended

Jun. 30, 2014

Equity Method Investments and Joint Ventures [Abstract]

Equity method investments

Equity method investments

Investments in companies in which the Company has the ability to exercise significant influence over operating and financial policies are accounted for using the equity method. At June 30, 2014, the Company had no significant equity method investments.

In August 2006, MDU Brasil acquired ownership interests in the Brazilian Transmission Lines. The electric transmission lines are primarily in northeastern and southern Brazil. The transmission contracts provide for revenues denominated in the Brazilian Real, annual inflation adjustments and change in tax law adjustments. The functional currency for the Brazilian Transmission Lines is the Brazilian Real.

In 2009, multiple sales agreements were signed for the Company to sell its ownership interests in the Brazilian Transmission Lines. In November 2010, the Company completed the sale of its entire ownership interest in ENTE and ERTE and 59.96 percent of the Company's ownership interest in ECTE. The Company's remaining interest in ECTE is being sold over a four-year period. In August 2013 and 2012, and November 2011, the Company completed the sale of one-fourth of the remaining interest in each year. The Company recognized an immaterial gain in 2013. The Company's remaining ownership interest in ECTE is being accounted for under the cost method.

At June 30, 2013, the equity method investments had total assets of $114.8 million and long-term debt of $56.2 million. The Company's investment in its equity method investments was approximately $5.5 million, including undistributed earnings of $2.0 million, at June 30, 2013.

XML

New accounting standards

6 Months Ended

Jun. 30, 2014

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

New accounting standard

New Accounting Standard

Revenue from Contracts with Customers In May 2014, the FASB issued guidance on accounting for revenue from contracts with customers. The guidance provides for a single comprehensive model for entities to use in accounting for revenue arising from contracts with customers and supersedes most current revenue recognition guidance, including industry specific guidance. This guidance will be effective for the Company on January 1, 2017. Entities will have the option of using either a full retrospective or modified retrospective approach to adopting the guidance. Under the modified approach, an entity would recognize the cumulative effect of initially applying the guidance with an adjustment to the opening balance of retained earnings in the period of adoption. In addition, the modified approach will require additional disclosures. The Company is evaluating the effects the adoption of the new revenue guidance will have on its results of operations, financial position, cash flows and disclosures, as well as its method of adoption.

XML

Equity (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Balance
Total stockholders' equity			$ 2,823,164
Noncontrolling interest			32,738
Total equity			2,855,902	2,648,248
Net loss attributable to noncontrolling interest	(779)	(179)	(1,302)	(179)
Net income (loss)	53,327	46,333	109,466	102,848
Other comprehensive income	340	(206)	1,007	(8,100)
Dividends declared on preferred stocks			(342)	(342)
Dividends declared on common stock			(68,025)	(65,147)
Stock-based compensation			2,796	2,453
Issuance of common stock upon vesting of performance shares, net of shares used for tax withholdings			(5,564)
Net tax benefit on stock-based compensation			4,729	(1,419)
Issuance of common stock			131,973
Contribution from noncontrolling interest			32,500	16,101
Total stockholders' equity	3,000,506	2,678,720	3,000,506	2,678,720
Noncontrolling interest	63,936	15,922	63,936	15,922
Total equity	3,064,442	2,694,642	3,064,442	2,694,642
Total stockholders’ equity [Member]
Balance
Total stockholders' equity			2,823,164	2,648,248
Net income (loss) attributable to parent			110,768	103,027
Other comprehensive income			1,007	(8,100)
Dividends declared on preferred stocks			(342)	(342)
Dividends declared on common stock			(68,025)	(65,147)
Stock-based compensation			2,796	2,453
Issuance of common stock upon vesting of performance shares, net of shares used for tax withholdings			(5,564)
Net tax benefit on stock-based compensation			4,729	(1,419)
Issuance of common stock			131,973
Contribution from noncontrolling interest			0	0
Total stockholders' equity	3,000,506	2,678,720	3,000,506	2,678,720
Noncontrolling interest [Member]
Balance
Noncontrolling interest			32,738	0
Net loss attributable to noncontrolling interest			(1,302)	(179)
Other comprehensive income			0	0
Dividends declared on preferred stocks			0	0
Dividends declared on common stock			0	0
Stock-based compensation			0	0
Issuance of common stock upon vesting of performance shares, net of shares used for tax withholdings			0
Net tax benefit on stock-based compensation			0	0
Issuance of common stock			0
Contribution from noncontrolling interest			32,500	16,101
Noncontrolling interest	$ 63,936	$ 15,922	$ 63,936	$ 15,922

XML

Earnings per common share

6 Months Ended

Jun. 30, 2014

Earnings Per Share [Abstract]

Earnings per common share

Earnings per common share

Basic earnings per common share were computed by dividing earnings on common stock by the weighted average number of shares of common stock outstanding during the applicable period. Diluted earnings per common share were computed by dividing earnings on common stock by the total of the weighted average number of shares of common stock outstanding during the applicable period, plus the effect of outstanding performance share awards. Common stock outstanding includes issued shares less shares held in treasury. Net income was the same for both the basic and diluted earnings per share calculations. A reconciliation of the weighted average common shares outstanding used in the basic and diluted earnings per share calculations was as follows:

	Three Months Ended		Six Months Ended
	June 30,		June 30,
	2014	2013	2014	2013
	(In thousands)
Weighted average common shares outstanding - basic	192,060	188,831	190,946	188,831
Effect of dilutive performance share awards	599	632	597	629
Weighted average common shares outstanding - diluted	192,659	189,463	191,543	189,460
Shares excluded from the calculation of diluted earnings per share	—	—	—	—

XML

Cash flow information

6 Months Ended

Jun. 30, 2014

Supplemental Cash Flow Information [Abstract]

Cash flow information

Cash flow information

Cash expenditures for interest and income taxes were as follows:

	Six Months Ended
	June 30,
	2014		2013
	(In thousands)
Interest, net of amount capitalized	$	39,441	$	41,440
Income taxes paid (refunded), net	$	39,984	$	(2,649	)

Noncash investing transactions were as follows:

	June 30,
	2014		2013
	(In thousands)
Property, plant and equipment additions in accounts payable	$	95,833	$	77,073

XML

Comprehensive income (loss)

6 Months Ended

Jun. 30, 2014

Comprehensive income (loss) [Abstract]

Comprehensive income (loss)

Comprehensive income (loss)

The after-tax changes in the components of accumulated other comprehensive loss were as follows:

Three Months Ended June 30, 2014	Net Unrealized Gain (Loss) on Derivative  Instruments  Qualifying as Hedges			Postretirement  Liability Adjustment			Foreign Currency Translation Adjustment			Net Unrealized Gain (Loss) on Available-for-sale Investments		Total Accumulated  Other Comprehensive  Loss
	(In thousands)
Balance at beginning of period	$	(3,421	)	$	(33,532	)	$	(621	)	$	36	$	(37,538	)
Other comprehensive income (loss) before reclassifications	—			—			42			8		50
Amounts reclassified from accumulated other comprehensive loss	13			245			—			32		290
Net current-period other comprehensive income	13			245			42			40		340
Balance at end of period	$	(3,408	)	$	(33,287	)	$	(579	)	$	76	$	(37,198	)

Three Months Ended June 30, 2013	Net Unrealized Gain (Loss) on Derivative  Instruments  Qualifying as Hedges			Postretirement  Liability Adjustment			Foreign Currency Translation Adjustment			Net Unrealized Gain (Loss) on Available-for-sale Investments			Total Accumulated  Other Comprehensive  Loss
	(In thousands)
Balance at beginning of period	$	(2,603	)	$	(53,699	)	$	(423	)	$	110		$	(56,615	)
Other comprehensive income (loss) before reclassifications	254			—			(390		)	(142		)	(278		)
Amounts reclassified from accumulated other comprehensive loss	(395		)	424			—			43			72
Net current-period other comprehensive income (loss)	(141		)	424			(390		)	(99		)	(206		)
Balance at end of period	$	(2,744	)	$	(53,275	)	$	(813	)	$	11		$	(56,821	)

Six Months Ended June 30, 2014	Net Unrealized Gain (Loss) on Derivative  Instruments  Qualifying as Hedges			Postretirement  Liability Adjustment			Foreign Currency Translation Adjustment			Net Unrealized Gain (Loss) on Available-for-sale Investments		Total Accumulated  Other Comprehensive  Loss
	(In thousands)
Balance at beginning of period	$	(3,765	)	$	(33,807	)	$	(667	)	$	34	$	(38,205	)
Other comprehensive income (loss) before reclassifications	—			—			88			10		98
Amounts reclassified from accumulated other comprehensive loss	357			520			—			32		909
Net current-period other comprehensive income	357			520			88			42		1,007
Balance at end of period	$	(3,408	)	$	(33,287	)	$	(579	)	$	76	$	(37,198	)

Six Months Ended June 30, 2013	Net Unrealized Gain (Loss) on Derivative  Instruments  Qualifying as Hedges			Postretirement  Liability Adjustment			Foreign Currency Translation Adjustment			Net Unrealized Gain (Loss) on Available-for-sale Investments			Total Accumulated  Other Comprehensive  Loss
	(In thousands)
Balance at beginning of period	$	6,018		$	(54,347	)	$	(511	)	$	119		$	(48,721	)
Other comprehensive income (loss) before reclassifications	(5,594		)	—			(302		)	(187		)	(6,083		)
Amounts reclassified from accumulated other comprehensive loss	(3,168		)	1,072			—			79			(2,017		)
Net current-period other comprehensive income (loss)	(8,762		)	1,072			(302		)	(108		)	(8,100		)
Balance at end of period	$	(2,744	)	$	(53,275	)	$	(813	)	$	11		$	(56,821	)

Reclassifications out of accumulated other comprehensive loss were as follows:

	Three Months Ended						Six Months Ended						Location on Consolidated Statements of Income
	June 30,						June 30,
	2014			2013			2014			2013
	(In thousands)
Reclassification adjustment for gain (loss) on derivative instruments included in net income:
Commodity derivative instruments	$	137		$	1,381		$	(250	)	$	5,896		Operating revenues
Interest rate derivative instruments	(160		)	(664		)	(320		)	(780		)	Interest expense
	(23		)	717			(570		)	5,116
	10			(322		)	213			(1,948		)	Income taxes
	(13		)	395			(357		)	3,168
Amortization of postretirement liability losses included in net periodic benefit cost	(395		)	(967		)	(838		)	(1,934		)	(a)
	150			543			318			862			Income taxes
	(245		)	(424		)	(520		)	(1,072		)
Reclassification adjustment for loss on available-for-sale investments included in net income	(49		)	(66		)	(49		)	(121		)	Other income
	17			23			17			42			Income taxes
	(32		)	(43		)	(32		)	(79		)
Total reclassifications	$	(290	)	$	(72	)	$	(909	)	$	2,017

(a) Included in net periodic benefit cost (credit). For more information, see Note 19.

XML

Litigation (Details) (USD $)					0 Months Ended
	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2013	Aug. 31, 2011 Litigation related to construction materials [Member]	Aug. 06, 2012 Former employee litigation [Member]	Oct. 31, 2010 Natural gas gathering operations [Member]	Jan. 13, 2012 Guarantee obligation under construction contract [Member]	Dec. 31, 2009 Guarantee obligation under construction contract [Member]
Loss Contingencies [Line Items]
Potential liabilities related to litigation and environmental matters	$ 32,100,000	$ 29,500,000	$ 32,900,000
Amount of compensatory damages in LPP's notice of demand								149,700,000
Arbitration award						26,600,000	22,000,000
Loss contingency, estimate of possible loss				3,700,000
Additional amount per day of potential penalties				5,000
Plaintiffs request compensatory damages					$ 23,800,000

XML

Guarantees (Details 3) (USD $)	Jun. 30, 2014
Guarantor Obligations [Line Items]
Amount of hedging obligations guaranteed reflected on balance sheet	$ 14,500,000
Guarantor obligations, maximum exposure, undiscounted	76,700,000
Fixed maximum amounts guaranteed by year 2014	21,200,000
Fixed maximum amounts guaranteed by year 2015	35,700,000
Fixed maximum amounts guaranteed by year 2016	700,000
Fixed maximum amounts guaranteed by year 2017	600,000
Fixed maximum amounts guaranteed by year 2018	500,000
Fixed maximum amounts guaranteed by year 2019	500,000
Fixed maximum amounts guaranteed by year expires after certain number of days after written notice	13,500,000
No scheduled maturity date	4,000,000
Amount outstanding under guarantees that is reflected on balance sheet	200,000
Letters of credit	36,300,000
Letters of credit set to expire - 2014	7,000,000
Letters of credit set to expire - 2015	29,300,000
Outstanding letters of credit	0
Natural gas transportation and storage agreement fixed maximum amount of performance guarantee of a related party	4,000,000
Amount outstanding by a related party under the guarantee	1,100,000
Amount of surety bonds outstanding	$ 666,900,000

XML

Regulatory matters and revenues subject to refund (Details) (USD $) In Millions, unless otherwise specified	0 Months Ended
	Feb. 27, 2014 NDPSC [Member]	Nov. 17, 2013 NDPSC [Member]	Sep. 18, 2013 NDPSC [Member]	Oct. 31, 2013 FERC [Member]	Jul. 10, 2014 Subsequent event [Member] NDPSC [Member]
Regulatory matters and revenues subject to refund [Line Items]
Annual amount recovered					$ 8.6
Rate increase requested	7.4		6.8
Percent above current rates requested	4.60%		6.40%
Interim rate increase (decrease), amount		4.3
Interim rate increase, percent		4.00%
Increased expenditures covered by change application				312
Approximate annual increase in revenues				$ 11.5

XML

Goodwill and other intangible assets (Tables)

6 Months Ended

Jun. 30, 2014

Goodwill and Intangible Assets Disclosure [Abstract]

Changes in the carrying amount of goodwill

The changes in the carrying amount of goodwill were as follows:

Six Months Ended June 30, 2014	Balance as of January 1, 2014*		Goodwill Acquired During the Year		Balance as of June 30, 2014*
	(In thousands)
Natural gas distribution	$	345,736	$	—	$	345,736
Pipeline and energy services	9,737		—		9,737
Construction materials and contracting	176,290		—		176,290
Construction services	104,276		—		104,276
Total	$	636,039	$	—	$	636,039

* Balance is presented net of accumulated impairment of $12.3 million at the pipeline and energy services segment, which occurred in prior periods.

Six Months Ended June 30, 2013	Balance as of January 1, 2013*		Goodwill Acquired During the Year		Balance as of June 30, 2013*
	(In thousands)
Natural gas distribution	$	345,736	$	—	$	345,736
Pipeline and energy services	9,737		—		9,737
Construction materials and contracting	176,290		—		176,290
Construction services	104,276		—		104,276
Total	$	636,039	$	—	$	636,039

* Balance is presented net of accumulated impairment of $12.3 million at the pipeline and energy services segment, which occurred in prior periods.

Year Ended December 31, 2013	Balance as of January 1, 2013*		Goodwill Acquired During the Year		Balance as of December 31, 2013*
	(In thousands)
Natural gas distribution	$	345,736	$	—	$	345,736
Pipeline and energy services	9,737		—		9,737
Construction materials and contracting	176,290		—		176,290
Construction services	104,276		—		104,276
Total	$	636,039	$	—	$	636,039

  * Balance is presented net of accumulated impairment of $12.3 million at the pipeline and energy services segment, which occurred in prior periods.

Other amortizable intangible assets

Other amortizable intangible assets were as follows:

	June 30, 2014			June 30, 2013			December 31, 2013
	(In thousands)
Customer relationships	$	21,310		$	21,310		$	21,310
Accumulated amortization	(14,734		)	(12,715		)	(13,726		)
	6,576			8,595			7,584
Noncompete agreements	5,080			6,186			6,186
Accumulated amortization	(3,936		)	(4,557		)	(4,840		)
	1,144			1,629			1,346
Other	10,921			10,979			10,995
Accumulated amortization	(7,375		)	(5,891		)	(6,826		)
	3,546			5,088			4,169
Total	$	11,266		$	15,312		$	13,099

XML

Other intangible assets (Details 2) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Finite-Lived Intangible Assets [Line Items]
Intangible assets, net (excluding goodwill)	$ 11,266,000	$ 15,312,000	$ 11,266,000	$ 15,312,000	$ 13,099,000
Amortization of intangible assets	1,000,000	1,000,000	1,800,000	1,800,000
Estimated amortization expense for amortizable intangible assets [Abstract]
2014	3,300,000		3,300,000
2015	2,500,000		2,500,000
2016	2,200,000		2,200,000
2017	1,900,000		1,900,000
2018	1,000,000		1,000,000
Thereafter	2,200,000		2,200,000
Customer relationships [Member]
Finite-Lived Intangible Assets [Line Items]
Intangible assets, gross	21,310,000	21,310,000	21,310,000	21,310,000	21,310,000
Intangible assets, accumulated amortization	(14,734,000)	(12,715,000)	(14,734,000)	(12,715,000)	(13,726,000)
Intangible assets, net (excluding goodwill)	6,576,000	8,595,000	6,576,000	8,595,000	7,584,000
Noncompete agreements [Member]
Finite-Lived Intangible Assets [Line Items]
Intangible assets, gross	5,080,000	6,186,000	5,080,000	6,186,000	6,186,000
Intangible assets, accumulated amortization	(3,936,000)	(4,557,000)	(3,936,000)	(4,557,000)	(4,840,000)
Intangible assets, net (excluding goodwill)	1,144,000	1,629,000	1,144,000	1,629,000	1,346,000
Other intangible assets [Member]
Finite-Lived Intangible Assets [Line Items]
Intangible assets, gross	10,921,000	10,979,000	10,921,000	10,979,000	10,995,000
Intangible assets, accumulated amortization	(7,375,000)	(5,891,000)	(7,375,000)	(5,891,000)	(6,826,000)
Intangible assets, net (excluding goodwill)	$ 3,546,000	$ 5,088,000	$ 3,546,000	$ 5,088,000	$ 4,169,000

XML

Derivative instruments

6 Months Ended

Jun. 30, 2014

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments

Derivative instruments

The Company's policy allows the use of derivative instruments as part of an overall energy price, foreign currency and interest rate risk management program to efficiently manage and minimize commodity price, foreign currency and interest rate risk. As of June 30, 2014, the Company had no outstanding foreign currency or interest rate hedges.

The fair value of derivative instruments must be estimated as of the end of each reporting period and is recorded on the Consolidated Balance Sheets as an asset or a liability.

Fidelity

At June 30, 2014 and 2013, and December 31, 2013, Fidelity held oil swap and collar agreements with total forward notional volumes of 2.5 million, 3.1 million and 2.9 million Bbl, respectively, and natural gas swap agreements with total forward notional volumes of 11.0 million, 21.4 million and 18.3 million MMBtu, respectively. Fidelity utilizes these derivative instruments to manage a portion of the market risk associated with fluctuations in the price of oil and natural gas on its forecasted sales of oil and natural gas production.

Effective April 1, 2013, Fidelity elected to de-designate all commodity derivative contracts previously designated as cash flow hedges and elected to discontinue hedge accounting prospectively for all of its commodity derivative instruments. When the criteria for hedge accounting is not met or when hedge accounting is not elected, realized gains and losses and unrealized gains and losses are both recorded in operating revenues on the Consolidated Statements of Income. As a result of discontinuing hedge accounting on commodity derivative instruments, gains and losses on the oil and natural gas derivative instruments remain in accumulated other comprehensive income (loss) as of the de-designation date and are reclassified into earnings in future periods as the underlying hedged transactions affect earnings. At April 1, 2013, accumulated other comprehensive income (loss) included $1.8 million of unrealized gains, representing the mark-to-market value of the Company's commodity derivative instruments that qualified as cash flow hedges as of the balance sheet date. The Company expects to reclassify into earnings from accumulated other comprehensive income (loss) the remaining value related to de-designating commodity derivative instruments over the next 6 months.

Prior to April 1, 2013, changes in the fair value attributable to the effective portion of the hedging instruments, net of tax, were recorded in stockholders' equity as a component of accumulated other comprehensive income (loss). To the extent that the hedges were not effective or did not qualify for hedge accounting, the ineffective portion of the changes in fair market value was recorded directly in earnings. Gains and losses on the oil and natural gas derivative instruments were reclassified from accumulated other comprehensive income (loss) into operating revenues on the Consolidated Statements of Income at the date the oil and natural gas quantities were settled.

There were no components of the derivative instruments' gain or loss excluded from the assessment of hedge effectiveness. Gains and losses must be reclassified into earnings as a result of the discontinuance of cash flow hedges if it is probable that the original forecasted transactions will not occur, and there were no such reclassifications.

Certain of Fidelity's derivative instruments contain cross-default provisions that state if Fidelity or any of its affiliates fails to make payment with respect to certain indebtedness, in excess of specified amounts, the counterparties could require early settlement or termination of the derivative instruments in liability positions. The aggregate fair value of Fidelity's derivative instruments with credit-risk-related contingent features that are in a liability position at June 30, 2014 and 2013, and December 31, 2013, were $17.4 million, $1.4 million and $7.5 million, respectively. The aggregate fair value of assets that would have been needed to settle the instruments immediately if the credit-risk-related contingent features were triggered on June 30, 2014 and 2013, and December 31, 2013, were $17.4 million, $1.4 million and $7.5 million, respectively.

Centennial

Centennial has historically entered into interest rate derivative instruments to manage a portion of its interest rate exposure on the forecasted issuance of long-term debt. As of June 30, 2014 and 2013, and December 31, 2013, Centennial had no outstanding interest rate swap agreements.

Fidelity and Centennial

The gains and losses on derivative instruments were as follows:

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2014			2013			2014			2013
	(In thousands)
Commodity derivatives designated as cash flow hedges:
Amount of loss recognized in accumulated other comprehensive loss (effective portion), net of tax	$	—		$	—		$	—		$	(6,154	)
Amount of (gain) loss reclassified from accumulated other comprehensive loss into operating revenues (effective portion), net of tax	(86		)	(871		)	158			(3,714		)
Amount of loss recognized in operating revenues (ineffective portion), before tax	—			—			—			(1,422		)
Interest rate derivatives designated as cash flow hedges:
Amount of gain recognized in accumulated other comprehensive loss (effective portion), net of tax	—			254			—			560
Amount of loss reclassified from accumulated other comprehensive loss into interest expense (effective portion), net of tax	99			475			199			546
Amount of loss recognized in interest expense (ineffective portion), before tax	—			(610		)	—			(769		)
Commodity derivatives not designated as hedging instruments:
Amount of gain (loss) recognized in operating revenues, before tax	(5,196		)	13,047			(11,908		)	8,637

Over the next 12 months net losses of approximately $535,000 (after tax) are estimated to be reclassified from accumulated other comprehensive income (loss) into earnings, as the hedged transactions affect earnings.

The location and fair value of the gross amount of the Company's derivative instruments on the Consolidated Balance Sheets were as follows:

Asset Derivatives	Location on Consolidated Balance Sheets	Fair Value at June 30, 2014		Fair Value at June 30, 2013		Fair Value at December 31, 2013
		(In thousands)
Not designated as hedges:
Commodity derivatives	Commodity derivative instruments	$	129	$	9,797	$	1,447
	Other assets - noncurrent	131		1,447		503
Total asset derivatives		$	260	$	11,244	$	1,950

Liability Derivatives	Location on Consolidated Balance Sheets	Fair Value at June 30, 2014		Fair Value at June 30, 2013		Fair Value at December 31, 2013
		(In thousands)
Not designated as hedges:
Commodity derivatives	Commodity derivative instruments	$	17,449	$	1,388	$	7,483
Total liability derivatives		$	17,449	$	1,388	$	7,483

All of the Company's commodity derivative instruments at June 30, 2014 and 2013, and December 31, 2013, were subject to legally enforceable master netting agreements. However, the Company's policy is to not offset fair value amounts for derivative instruments and, as a result, the Company's derivative assets and liabilities are presented gross on the Consolidated Balance Sheets. The gross derivative assets and liabilities (excluding settlement receivables and payables that may be subject to the same master netting agreements) presented on the Consolidated Balance Sheets and the amount eligible for offset under the master netting agreements is presented in the following table:

June 30, 2014	Gross Amounts Recognized on the Consolidated Balance Sheets		Gross Amounts Not Offset on the Consolidated Balance Sheets			Net
	(In thousands)
Assets:
Commodity derivatives	$	260	$	(260	)	$	—
Total assets	$	260	$	(260	)	$	—
Liabilities:
Commodity derivatives	$	17,449	$	(260	)	$	17,189
Total liabilities	$	17,449	$	(260	)	$	17,189

June 30, 2013	Gross Amounts Recognized on the Consolidated Balance Sheets		Gross Amounts Not Offset on the Consolidated Balance Sheets			Net
	(In thousands)
Assets:
Commodity derivatives	$	11,244	$	(1,388	)	$	9,856
Total assets	$	11,244	$	(1,388	)	$	9,856
Liabilities:
Commodity derivatives	$	1,388	$	(1,388	)	$	—
Total liabilities	$	1,388	$	(1,388	)	$	—

December 31, 2013	Gross Amounts Recognized on the Consolidated Balance Sheets		Gross Amounts Not Offset on the Consolidated Balance Sheets			Net
	(In thousands)
Assets:
Commodity derivatives	$	1,950	$	(1,950	)	$	—
Total assets	$	1,950	$	(1,950	)	$	—
Liabilities:
Commodity derivatives	$	7,483	$	(1,950	)	$	5,533
Total liabilities	$	7,483	$	(1,950	)	$	5,533

XML

Employee benefit plans

6 Months Ended

Jun. 30, 2014

Defined Benefit Plans and Other Postretirement Benefit Plans Disclosures [Abstract]

Pension and other postretirement benefit plans

Employee benefit plans

The Company has noncontributory defined benefit pension plans and other postretirement benefit plans for certain eligible employees. Components of net periodic benefit cost for the Company's pension and other postretirement benefit plans were as follows:

							Other
							Postretirement
	Pension Benefits						Benefits
Three Months Ended June 30,	2014			2013			2014			2013
	(In thousands)
Components of net periodic benefit cost:
Service cost	$	31		$	37		$	380		$	334
Interest cost	4,405			4,106			924			667
Expected return on assets	(5,484		)	(4,875		)	(1,242		)	(1,065		)
Amortization of prior service cost (credit)	18			18			(348		)	(364		)
Amortization of net actuarial loss	1,121			1,716			6			407
Net periodic benefit cost, including amount capitalized	91			1,002			(280		)	(21		)
Less amount capitalized	73			158			(19		)	61
Net periodic benefit cost (credit)	$	18		$	844		$	(261	)	$	(82	)

							Other
							Postretirement
	Pension Benefits						Benefits
Six Months Ended June 30,	2014			2013			2014			2013
	(In thousands)
Components of net periodic benefit cost:
Service cost	$	64		$	77		$	759		$	838
Interest cost	8,845			8,124			1,782			1,607
Expected return on assets	(10,609		)	(9,958		)	(2,309		)	(2,172		)
Amortization of prior service cost (credit)	36			36			(696		)	(728		)
Amortization of net actuarial loss	2,434			3,580			324			1,078
Net periodic benefit cost, including amount capitalized	770			1,859			(140		)	623
Less amount capitalized	168			268			10			90
Net periodic benefit cost (credit)	$	602		$	1,591		$	(150	)	$	533

In addition to the qualified plan defined pension benefits reflected in the table, the Company has unfunded, nonqualified benefit plans for executive officers and certain key management employees that generally provide for defined benefit payments at age 65 following the employee's retirement or to their beneficiaries upon death for a 15-year period. The Company's net periodic benefit cost for this plan for the three and six months ended June 30, 2014, was $1.6 million and $3.3 million, respectively. The Company's net periodic benefit cost for this plan for the three and six months ended June 30, 2013, was $1.8 million and $3.6 million, respectively.

XML

Equity method investments (Details) (USD $) In Millions, unless otherwise specified		0 Months Ended
	Jun. 30, 2013	Nov. 30, 2010 ECTE [Member]	Aug. 31, 2013 ECTE [Member]	Aug. 31, 2012 ECTE [Member]	Nov. 30, 2011 ECTE [Member]	Nov. 30, 2010 ECTE [Member]	Nov. 30, 2010 ENTE [Member]	Nov. 30, 2010 ERTE [Member]
Schedule of Equity Method Investments [Line Items]
Percentage ownership interest in equity method investment sold						59.96%	100.00%	100.00%
Number of years over which remaining ownership interest in equity method investment will be sold		4 years
Portion of remaining interest sold			25.00%	25.00%	25.00%
Total assets of equity method investments	$ 114.8
Total long-term debt of equity method investments	56.2
Investment in equity method investments	5.5
Undistributed earnings of equity method investments	$ 2.0

XML

Accounts receivable and allowance for doubtful accounts (Details) (USD $) In Millions, unless otherwise specified	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2013
Receivables [Abstract]
Receivables past due 90 days or more	$ 29.6	$ 36.4	$ 35.1
Allowance for doubtful accounts receivable	$ 9.6	$ 10.1	$ 10.6

XML

Consolidated Balance Sheets (USD $) In Thousands, unless otherwise specified	Jun. 30, 2014		Dec. 31, 2013		Jun. 30, 2013
Current assets:
Cash and cash equivalents	$ 90,318		$ 45,225		$ 114,971
Receivables, net	731,247		713,067		734,765
Inventories	331,422		282,391		345,885
Deferred income taxes	29,110		25,048		27,959
Commodity derivative instruments	129		1,447		9,797
Prepayments and other current assets	93,980		49,510		58,870
Total current assets	1,276,206		1,116,688		1,292,247
Investments	116,594		112,939		106,508
Property, plant and equipment	9,390,538		8,803,866		8,454,204
Less accumulated depreciation, depletion and amortization	4,011,858		3,872,487		3,709,679
Net property, plant and equipment	5,378,680		4,931,379		4,744,525
Deferred charges and other assets:
Goodwill	636,039	[1]	636,039	[1]	636,039	[1]
Other intangible assets, net	11,266		13,099		15,312
Other	249,532		251,188		297,040
Total deferred charges and other assets	896,837		900,326		948,391
Total assets	7,668,317		7,061,332		7,091,671
Current liabilities:
Short-term borrowings	0		11,500		31,600
Long-term debt due within one year	42,215		12,277		69,091
Accounts payable	424,201		404,961		411,621
Taxes payable	48,985		74,175		89,896
Dividends payable	34,388		33,737		32,745
Accrued compensation	50,024		69,661		44,159
Commodity derivative instruments	17,449		7,483		1,388
Other accrued liabilities	179,402		171,106		185,389
Total current liabilities	796,664		784,900		865,889
Long-term debt	2,144,879		1,842,286		1,937,663
Deferred credits and other liabilities:
Deferred income taxes	925,813		859,306		782,838
Other liabilities	736,519		718,938		810,639
Total deferred credits and other liabilities	1,662,332		1,578,244		1,593,477
Equity:
Preferred stocks	15,000		15,000		15,000
Common stockholders' equity:
Authorized - 500,000,000 shares, $1.00 par value. Shares issued - 194,138,654 at June 30, 2014, 189,369,450 at June 30, 2013 and 189,868,780 at December 31, 2013	194,139		189,869		189,369
Other paid-in-capital	1,186,900		1,056,996		1,040,379
Retained earnings	1,645,291		1,603,130		1,494,419
Accumulated other comprehensive loss	(37,198)		(38,205)		(56,821)
Treasury stock at cost - 538,921 shares	(3,626)		(3,626)		(3,626)
Total common stockholders' equity	2,985,506		2,808,164		2,663,720
Total stockholders' equity	3,000,506		2,823,164		2,678,720
Noncontrolling interest	63,936		32,738		15,922
Total equity	3,064,442		2,855,902		2,694,642
Total liabilities and equity	$ 7,668,317		$ 7,061,332		$ 7,091,671

[1] Balance is presented net of accumulated impairment of $12.3 million at the pipeline and energy services segment, which occurred in prior periods.

XML

Accounts receivable and allowance for doubtful accounts

6 Months Ended

Jun. 30, 2014

Receivables [Abstract]

Accounts receivable and allowance for doubtful accounts

Accounts receivable and allowance for doubtful accounts

Accounts receivable consist primarily of trade receivables from the sale of goods and services which are recorded at the invoiced amount net of allowance for doubtful accounts, and costs and estimated earnings in excess of billings on uncompleted contracts. The total balance of receivables past due 90 days or more was $29.6 million, $35.1 million and $36.4 million at June 30, 2014 and 2013, and December 31, 2013, respectively.

The allowance for doubtful accounts is determined through a review of past due balances and other specific account data. Account balances are written off when management determines the amounts to be uncollectible. The Company's allowance for doubtful accounts at June 30, 2014 and 2013, and December 31, 2013, was $9.6 million, $10.6 million and $10.1 million, respectively.

XML

Fair value measurements (Details 3) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2013
Carrying amount [Member]
Fair value, balance sheet grouping [Line Items]
Long-term debt	$ 2,187,094	$ 1,854,563	$ 2,006,754
Fair value [Member]
Fair value, balance sheet grouping [Line Items]
Long-term debt, fair value	$ 2,283,351	$ 1,912,590	$ 2,090,208

XML

Regulatory matters and revenues subject to refund

6 Months Ended

Jun. 30, 2014

Regulated Operations [Abstract]

Regulatory matters and revenues subject to refund

Regulatory matters and revenues subject to refund

On April 8, 2014, Montana-Dakota submitted a request to the NDPSC to update the environmental cost recovery rider to reflect actual costs incurred through February 2014 and projected costs through June 2015 related to the recovery of Montana-Dakota's share of the costs resulting from the environmental retrofit required to be installed at the Big Stone Station. The NDPSC approved the proposed rider on July 10, 2014, reflecting an annual amount of $8.6 million to be recovered under the rider. The rider was effective with service rendered on and after July 15, 2014.

On September 18, 2013, Montana-Dakota filed an application with the NDPSC for a natural gas rate increase. Montana-Dakota requested a total increase of $6.8 million annually or approximately 6.4 percent above current rates. The requested increase includes the costs associated with the increased investment in facilities, including ongoing investment in new and replacement distribution facilities, an operations building, automated meter reading and a new customer billing system. An interim increase of $4.3 million annually or approximately 4.0 percent went into effect for service rendered on or after November 17, 2013. On December 30, 2013, the NDPSC approved a settlement agreement for an increase in the same amount as the interim increase. A hearing on the rate design portion of the case was held February 5, 2014. The NDPSC voted to approve an order approving the allocation of the revenue increase to each rate class and the rate design on April 9, 2014. Final rates were implemented May 1, 2014.

On February 27, 2014, Montana-Dakota filed an application with the NDPSC for approval of an electric generation resource recovery rider for recovery of Montana-Dakota's investment in the 88-MW simple-cycle natural gas turbine and associated facilities currently under construction near Mandan, ND. Montana-Dakota requested recovery of $7.4 million annually or approximately 4.6 percent above current rates. Advance determination of prudence and a certificate of public convenience and necessity were received from the NDPSC on April 11, 2012. On March 12, 2014, the NDPSC suspended the filing pending further review. The NDPSC held a hearing regarding this matter on May 28, 2014. The matter is pending before the NDPSC.

On October 31, 2013, WBI Energy Transmission filed a general natural gas rate change application with the FERC based on an increase in investments of $312 million, increased operating costs, and the effect of lower storage and off system volumes. On April 30, 2014, WBI Energy Transmission reached a settlement in principle with FERC Trial Staff and all active parties to resolve the rate case. WBI Energy Transmission filed settlement rates to take effect on an interim basis, effective May 1, 2014, pending final approval of the settlement. On June 4, 2014, WBI Energy Transmission submitted to the FERC an Uncontested Offer of Settlement. On June 11, 2014, the Presiding Administrative Law Judge issued a Certification of Uncontested Settlement recommending FERC approval of the settlement without modification. The matter is pending before the FERC. Based on the adjusted base period volumes filed in the case, the annual increase in revenues is approximately $11.5 million.

XML

Business segment data (Tables)

6 Months Ended

Jun. 30, 2014

Segment Reporting [Abstract]

Information on the Company's businesses

Information on the Company's businesses was as follows:

Three Months Ended June 30, 2014	External Operating Revenues		Inter- segment Operating Revenues			Earnings on Common Stock
	(In thousands)
Electric	$	65,149	$	—		$	7,823
Natural gas distribution	146,077		—			(4,494		)
Pipeline and energy services	43,463		7,888			5,789
	254,689		7,888			9,118
Exploration and production	129,309		10,271			19,180
Construction materials and contracting	434,452		8,106			10,554
Construction services	275,109		7,273			14,307
Other	487		1,744			1,608
	839,357		27,394			45,649
Intersegment eliminations	—		(35,282		)	(832		)
Total	$	1,094,046	$	—		$	53,935

Three Months Ended June 30, 2013	External Operating Revenues		Inter- segment Operating Revenues			Earnings on Common Stock
	(In thousands)
Electric	$	56,981	$	—		$	4,410
Natural gas distribution	127,584		—			(5,893		)
Pipeline and energy services	42,877		7,999			(6,395		)
	227,442		7,999			(7,878		)
Exploration and production	137,053		12,556			32,995
Construction materials and contracting	418,345		12,958			10,025
Construction services	277,259		2,340			12,915
Other	496		1,839			340
	833,153		29,693			56,275
Intersegment eliminations	—		(37,692		)	(2,056		)
Total	$	1,060,595	$	—		$	46,341

Six Months Ended June 30, 2014	External Operating Revenues		Inter- segment Operating Revenues			Earnings on Common Stock
	(In thousands)
Electric	$	138,796	$	—		$	18,856
Natural gas distribution	520,311		—			22,768
Pipeline and energy services	87,124		26,164			10,138
	746,231		26,164			51,762
Exploration and production	245,976		31,139			40,120
Construction materials and contracting	598,875		12,123			(13,019		)
Construction services	545,002		11,010			30,875
Other	815		3,468			1,872
	1,390,668		57,740			59,848
Intersegment eliminations	—		(83,904		)	(1,184		)
Total	$	2,136,899	$	—		$	110,426

Six Months Ended June 30, 2013	External Operating Revenues		Inter- segment Operating Revenues			Earnings on Common Stock
	(In thousands)
Electric	$	121,635	$	—		$	14,235
Natural gas distribution	459,337		—			26,624
Pipeline and energy services	70,593		26,717			(4,064		)
	651,565		26,717			36,795
Exploration and production	252,415		22,369			53,279
Construction materials and contracting	580,323		17,251			(10,557		)
Construction services	507,065		3,914			24,579
Other	830		3,657			645
	1,340,633		47,191			67,946
Intersegment eliminations	—		(73,908		)	(2,056		)
Total	$	1,992,198	$	—		$	102,685

XML

Goodwill and other intangible assets

6 Months Ended

Jun. 30, 2014

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill and other intangible assets

Goodwill and other intangible assets

The changes in the carrying amount of goodwill were as follows:

Six Months Ended June 30, 2014	Balance as of January 1, 2014*		Goodwill Acquired During the Year		Balance as of June 30, 2014*
	(In thousands)
Natural gas distribution	$	345,736	$	—	$	345,736
Pipeline and energy services	9,737		—		9,737
Construction materials and contracting	176,290		—		176,290
Construction services	104,276		—		104,276
Total	$	636,039	$	—	$	636,039

* Balance is presented net of accumulated impairment of $12.3 million at the pipeline and energy services segment, which occurred in prior periods.

Six Months Ended June 30, 2013	Balance as of January 1, 2013*		Goodwill Acquired During the Year		Balance as of June 30, 2013*
	(In thousands)
Natural gas distribution	$	345,736	$	—	$	345,736
Pipeline and energy services	9,737		—		9,737
Construction materials and contracting	176,290		—		176,290
Construction services	104,276		—		104,276
Total	$	636,039	$	—	$	636,039

* Balance is presented net of accumulated impairment of $12.3 million at the pipeline and energy services segment, which occurred in prior periods.

Year Ended December 31, 2013	Balance as of January 1, 2013*		Goodwill Acquired During the Year		Balance as of December 31, 2013*
	(In thousands)
Natural gas distribution	$	345,736	$	—	$	345,736
Pipeline and energy services	9,737		—		9,737
Construction materials and contracting	176,290		—		176,290
Construction services	104,276		—		104,276
Total	$	636,039	$	—	$	636,039

  * Balance is presented net of accumulated impairment of $12.3 million at the pipeline and energy services segment, which occurred in prior periods.

Other amortizable intangible assets were as follows:

	June 30, 2014			June 30, 2013			December 31, 2013
	(In thousands)
Customer relationships	$	21,310		$	21,310		$	21,310
Accumulated amortization	(14,734		)	(12,715		)	(13,726		)
	6,576			8,595			7,584
Noncompete agreements	5,080			6,186			6,186
Accumulated amortization	(3,936		)	(4,557		)	(4,840		)
	1,144			1,629			1,346
Other	10,921			10,979			10,995
Accumulated amortization	(7,375		)	(5,891		)	(6,826		)
	3,546			5,088			4,169
Total	$	11,266		$	15,312		$	13,099

Amortization expense for amortizable intangible assets for the three and six months ended June 30, 2014, was $1.0 million and $1.8 million, respectively. Amortization expense for amortizable intangible assets for the three and six months ended June 30, 2013, was $1.0 million and $1.8 million, respectively. Estimated amortization expense for amortizable intangible assets is $3.3 million in 2014, $2.5 million in 2015, $2.2 million in 2016, $1.9 million in 2017, $1.0 million in 2018 and $2.2 million thereafter.