424B3

424B3 1 d619185d424b3.htm 424B3 424B3

Filed Pursuant to Rule 424(b)(3)
Registration No. 333-192022

PROSPECTUS

LOGO

Whiting Petroleum Corporation

Offer to Exchange All Outstanding, Unregistered

$400,000,000 5.750% Senior Notes due 2021 (CUSIP Nos. 966387AJ1 and U9650FAC1)

For New, Registered

$400,000,000 5.750% Senior Notes due 2021 (CUSIP No. 966387AH5)

The New Notes

We are offering, upon the terms and subject to the conditions set forth in this prospectus, to exchange all of our outstanding unregistered 5.750% Senior Notes due 2021 (CUSIP Nos. 966387AJ1 and U9650FAC1) (the “original notes”) issued September 26, 2013, for our new, registered 5.750% Senior Notes due 2021 (CUSIP No. 966387AH5) (the “new notes”), which are an additional issuance of and will be fully fungible and form a single series voting together as one class with the $800,000,000 aggregate principal amount of our 5.750% Senior Notes due 2021 issued on September 12, 2013 (the “September 12 notes” and together with the new notes, the “notes”). The new notes offered hereby will have the same CUSIP number assigned to the September 12 notes. Assuming all original notes are validly tendered and accepted for exchange in this exchange offer, the aggregate principal amount of notes of this series will be $1,200,000,000.

The new notes and guarantee (as defined below) will be our senior unsecured obligations and will rank equally in right of payment with all of our senior indebtedness, including our outstanding senior notes issued on September 12, 2013, senior in right of payment to any of our subordinated indebtedness, including our outstanding senior subordinated notes, effectively subordinated to all of our secured indebtedness to the extent of the value of the collateral securing such indebtedness and structurally subordinated to any liabilities of our subsidiaries that do not guarantee the new notes. The new notes will be guaranteed (the “guarantee”) by our subsidiary Whiting Oil and Gas Corporation (the “guarantor”) on a senior unsecured basis.

Material Terms of the Exchange Offer

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The exchange offer expires at 5:00 p.m., New York City time, on December 13, 2013, unless we extend it.

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All outstanding original notes that are validly tendered and not validly withdrawn will be exchanged.

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You may withdraw your tender of original notes any time before the exchange offer expires.

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The terms of the new notes are substantially identical to those of the original notes, except that the new notes will be part of the same series as the September 12 notes, the new notes will not have securities law transfer restrictions and the registration rights relating to the original notes and the new notes will not provide for the payment of additional interest under circumstances relating to the timing of the exchange offer.

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We will not receive any proceeds from the exchange offer.

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No established trading market for the new notes currently exists. The new notes will not be listed on any securities exchange or included in any automated quotation system.

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The exchange of notes will not be a taxable event for U.S. federal income tax purposes.

Each broker-dealer that receives new notes for its own account pursuant to the exchange offer must acknowledge that it will deliver a prospectus in connection with any resale of such new notes. The letter of transmittal for the exchange offer states that by so acknowledging and by delivering a prospectus, a broker-dealer will not be deemed to admit that it is an “underwriter” within the meaning of the Securities Act of 1933, as amended (the “Securities Act”). This prospectus, as it may be amended or supplemented from time to time, may be used by a broker-dealer in connection with resales of new notes received in exchange for original notes where such original notes were acquired by such broker-dealer as a result of market-making activities or other trading activities. We have agreed that for a period of 180 days beginning when the new notes are issued to make this prospectus available to any broker-dealer for use in connection with any such resale. See “Plan of Distribution.”

See “Risk Factors” beginning on page 17 for a discussion of risk factors that you should consider before deciding to exchange your original notes for new notes.

Neither the Securities and Exchange Commission nor any state securities commission has approved or disapproved of these securities or determined if this prospectus is truthful or complete. Any representation to the contrary is a criminal offense.

The date of this prospectus is November 14, 2013.

TABLE OF CONTENTS


	Page
Glossary of Certain Definitions		ii
Special Note Regarding Forward-Looking Statements		vi
Prospectus Summary		1
Risk Factors		17
Use of Proceeds		36
Capitalization		37
Selected Historical Financial Data		38
The Exchange Offer		40
Description of New Notes		49
Material U.S. Federal Income Tax Consequences		91
Plan of Distribution		96
Where You Can Find More Information		97
Legal Matters		98
Experts		98

You should rely only on the information contained in this prospectus. We have not authorized any other person to provide you with different information. If anyone provides you with different or inconsistent information, you should not rely on it. You should assume that the information appearing in this prospectus as well as the documents incorporated by reference in this prospectus, is accurate only as of its respective date. Our business, financial condition, results of operations and prospects may have changed since that date.

In this prospectus, except as otherwise noted, “we,” “us,” “our” or “ours” refer to Whiting Petroleum Corporation and its consolidated subsidiaries.

This prospectus incorporates important business and financial information about us that is not included in or delivered with this prospectus. We will provide you without charge upon your request, a copy of any documents that we incorporate by reference, other than exhibits to those documents that are not specifically incorporated by reference into those documents. You may request a copy of a document, at no cost, by request directed to us at the following address or telephone number:

Whiting Petroleum Corporation

1700 Broadway, Suite 2300

Denver, Colorado 80290-2300

Attention: Corporate Secretary

(303) 837-1661

To ensure timely delivery, you must request the information no later than five (5) business days before the completion of the exchange offer. Therefore, you must make any request on or before December 6, 2013.

GLOSSARY OF CERTAIN DEFINITIONS

We have included below the definitions for certain terms used in this prospectus:

“3-D seismic” Geophysical data that depict the subsurface strata in three dimensions. 3-D seismic typically provides a more detailed and accurate interpretation of the subsurface strata than 2-D, or two-dimensional, seismic.

“Bbl” One stock tank barrel, or 42 U.S. gallons liquid volume, used in this prospectus in reference to oil, NGLs and other liquid hydrocarbons.

“Bcf” One billion cubic feet of natural gas.

“BOE” One stock tank barrel of oil equivalent, computed on an approximate energy equivalent basis that one Bbl of crude oil equals six Mcf of natural gas and one Bbl of crude oil equals one Bbl of natural gas liquids.

“BOE/d” One BOE per day.

“CO₂” Carbon dioxide.

“CO₂ flood” A tertiary recovery method in which CO₂ is injected into a reservoir to enhance hydrocarbon recovery.

“completion” The installation of permanent equipment for the production of crude oil or natural gas, or in the case of a dry hole, the reporting of abandonment to the appropriate agency.

“costless collar” An options position where the proceeds from the sale of a call option at its inception fund the purchase of a put option at its inception.

“differential” The difference between a benchmark price of oil and natural gas, such as the NYMEX crude oil spot, and the wellhead price received.

“FASB” Financial Accounting Standards Board.

“field” An area consisting of a single reservoir or multiple reservoirs all grouped on or related to the same individual geological structural feature and/or stratigraphic condition. There may be two or more reservoirs in a field that are separated vertically by intervening impervious strata, or laterally by local geologic barriers, or both. Reservoirs that are associated by being in overlapping or adjacent fields may be treated as a single or common operational field. The geological terms “structural feature” and “stratigraphic condition” are intended to identify localized geological features as opposed to the broader terms of basins, trends, provinces, plays, areas of interest, etc.

“GAAP” Generally accepted accounting principles in the United States of America.

“gross acres or gross wells” The total acres or wells, as the case may be, in which a working interest is owned.

“lease operating expense” or “LOE” The expenses of lifting oil or gas from a producing formation to the surface, constituting part of the current operating expenses of a working interest, and also including labor, superintendence, supplies, repairs, short-lived assets, maintenance, allocated overhead costs and other expenses incidental to production, but not including lease acquisition or drilling or completion expenses.

“MBbl” One thousand barrels of oil or other liquid hydrocarbons.

“MBOE” One thousand BOE.

“MBOE/d” One MBOE per day.

“Mcf” One thousand cubic feet of natural gas.

“MMBbl” One million Bbl.

“MMBOE” One million BOE.

“MMcf” One million cubic feet of natural gas.

“MMcf/d” One MMcf per day.

“net production” The total production attributable to our fractional working interest owned.

“NGL” Natural gas liquid.

“NYMEX” The New York Mercantile Exchange.

“plugging and abandonment” Refers to the sealing off of fluids in the strata penetrated by a well so that the fluids from one stratum will not escape into another or to the surface. Regulations of many states require plugging of abandoned wells.

“possible reserves” Those reserves that are less certain to be recovered than probable reserves.

“pre-tax PV10%” The present value of estimated future revenues to be generated from the production of proved reserves calculated in accordance with the guidelines of the SEC, net of estimated lease operating expense, production taxes and future development costs, using costs as of the date of estimation without future escalation and using an average of the first-day-of-the month price for each of the 12 months within the fiscal year, without giving effect to non-property related expenses such as general and administrative expenses, debt service and depreciation, depletion and amortization, or Federal income taxes and discounted using an annual discount rate of 10%. Pre-tax PV10% may be considered a non-GAAP financial measure as defined by the SEC. See note 3 to the Proved Reserves table in “Prospectus Summary—About Our Company” of this prospectus for more information.

“probable reserves” Those reserves that are less certain to be recovered than proved reserves but which, together with proved reserves, are as likely as not to be recovered.

“proved developed reserves” Proved reserves that can be expected to be recovered through existing wells with existing equipment and operating methods or in which the cost of the required equipment is relatively minor compared to the cost of a new well.

“proved reserves” Those reserves which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible—from a given date forward, from known reservoirs and under existing economic conditions, operating methods and government regulations—prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. The project to extract the hydrocarbons must have commenced, or the operator must be reasonably certain that it will commence the project, within a reasonable time.

The area of the reservoir considered as proved includes all of the following:

the area identified by drilling and limited by fluid contacts, if any, and

adjacent undrilled portions of the reservoir that can, with reasonable certainty, be judged to be continuous with it and to contain economically producible oil or gas on the basis of available geoscience and engineering data.

iii

Reserves that can be produced economically through application of improved recovery techniques (including, but not limited to, fluid injection) are included in the proved classification when both of the following occur:

successful testing by a pilot project in an area of the reservoir with properties no more favorable than in the reservoir as a whole, the operation of an installed program in the reservoir or an analogous reservoir, or other evidence using reliable technology establishes the reasonable certainty of the engineering analysis on which the project or program was based, and

the project has been approved for development by all necessary parties and entities, including governmental entities.

Existing economic conditions include prices and costs at which economic producibility from a reservoir is to be determined. The price shall be the average price during the 12-month period before the ending date of the period covered by the report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within such period, unless prices are defined by contractual arrangements, excluding escalations based upon future conditions.

“proved undeveloped reserves” Proved reserves that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for recompletion. Reserves on undrilled acreage shall be limited to those directly offsetting development spacing areas that are reasonably certain of production when drilled, unless evidence using reliable technology exists that establishes reasonable certainty of economic producibility at greater distances. Undrilled locations can be classified as having undeveloped reserves only if a development plan has been adopted indicating that they are scheduled to be drilled within five years, unless specific circumstances justify a longer time. Under no circumstances shall estimates for proved undeveloped reserves be attributable to any acreage for which an application of fluid injection or other improved recovery technique is contemplated, unless such techniques have been proved effective by actual projects in the same reservoir or an analogous reservoir, or by other evidence using reliable technology establishing reasonable certainty.

“reasonable certainty” If deterministic methods are used, reasonable certainty means a high degree of confidence that the quantities will be recovered. If probabilistic methods are used, there should be at least a 90 percent probability that the quantities actually recovered will equal or exceed the estimate. A high degree of confidence exists if the quantity is much more likely to be achieved than not, and, as changes due to increased availability of geoscience (geological, geophysical and geochemical) engineering, and economic data are made to estimated ultimate recovery with time, reasonably certain estimated ultimate recovery is much more likely to increase or remain constant than to decrease.

“recompletion” An operation whereby a completion in one zone is abandoned in order to attempt a completion in a different zone within the existing wellbore.

“reserves” Estimated remaining quantities of oil and gas and related substances anticipated to be economically producible, as of a given date, by application of development projects to known accumulations. In addition, there must exist, or there must be a reasonable expectation that there will exist, the legal right to produce or a revenue interest in the production, installed means of delivering oil and gas or related substances to market, and all permits and financing required to implement the project.

“reservoir” A porous and permeable underground formation containing a natural accumulation of producible crude oil and/or natural gas that is confined by impermeable rock or water barriers and is individual and separate from other reservoirs.

“resource play” Refers to drilling programs targeted at regionally distributed oil or natural gas accumulations. Successful exploitation of these reservoirs is dependent upon new technologies such as horizontal drilling and multi-stage fracture stimulation to access large rock volumes in order to produce economic quantities of oil or natural gas.

“SEC” The United States Securities and Exchange Commission.

“standardized measure of discounted future net cash flows” The discounted future net cash flows relating to proved reserves based on the average price during the 12-month period before the ending date of the period covered by the report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within such period (unless prices are defined by contractual arrangements, excluding escalations based upon future conditions); current costs and statutory tax rates (to the extent applicable); and a 10% annual discount rate.

SPECIAL NOTE REGARDING FORWARD-LOOKING STATEMENTS

This prospectus and the documents incorporated by reference herein contain statements that we believe to be “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements other than historical facts, including, without limitation, statements regarding our future financial position, business strategy, projected revenues, earnings, costs, capital expenditures and debt levels, and plans and objectives of management for future operations, are forward-looking statements. We caution that these statements and any other forward-looking statements in this prospectus and the documents incorporated by reference herein only reflect our expectations and do not guarantee performance. When used in this prospectus and the documents incorporated by reference herein, words such as we “expect,” “intend,” “plan,” “estimate,” “anticipate,” “believe” or “should” or the negative thereof or variations thereon or similar terminology are generally intended to identify forward-looking statements. Such forward-looking statements are subject to risks and uncertainties that could cause actual results to differ materially from those expressed in, or implied by, such statements. These risks and uncertainties include, but are not limited to:

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declines in oil, NGL or natural gas prices;

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our level of success in exploration, development and production activities;

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adverse weather conditions that may negatively impact development or production activities;

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the timing of our exploration and development expenditures;

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our ability to obtain sufficient quantities of CO₂ necessary to carry out our enhanced oil recovery projects;

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inaccuracies of our reserve estimates or our assumptions underlying them;

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revisions to reserve estimates as a result of changes in commodity prices;

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risks related to our level of indebtedness and periodic redeterminations of the borrowing base under our credit agreement;

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our ability to generate sufficient cash flows from operations to meet the internally funded portion of our capital expenditures budget;

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our ability to obtain external capital to finance exploration and development operations and acquisitions;

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federal and state initiatives relating to the regulation of hydraulic fracturing;

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the potential impact of federal debt reduction initiatives and tax reform legislation being considered by the U.S. Federal government that could have a negative effect on the oil and gas industry;

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our ability to identify and complete acquisitions and to successfully integrate acquired businesses;

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unforeseen underperformance of or liabilities associated with acquired properties;

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our ability to successfully complete potential asset dispositions and the risks related thereto;

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the impacts of hedging on our results of operations;

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failure of our properties to yield oil or gas in commercially viable quantities;

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uninsured or underinsured losses resulting from our oil and gas operations;

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our inability to access oil and gas markets due to market conditions or operational impediments;

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the impact and costs of compliance with laws and regulations governing our oil and gas operations;

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our ability to replace our oil and natural gas reserves;

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any loss of our senior management or technical personnel;

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competition in the oil and gas industry in the regions in which we operate;

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risks arising out of our hedging transactions; and

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other risks described under the caption “Risk Factors” in this prospectus.

We assume no obligation, and disclaim any duty, to update the forward-looking statements in this prospectus or the documents we incorporate by reference herein. We urge you to carefully review and consider the disclosures made in this prospectus and our reports filed with the SEC and incorporated by reference herein that attempt to advise interested parties of the risks and factors that may affect our business.

vii

PROSPECTUS SUMMARY

This summary highlights information contained elsewhere in this prospectus and the documents we incorporate by reference herein. This summary may not contain all of the information that may be important to you. You should read the entire prospectus, including “Risk Factors,” and the documents we incorporate by reference into this prospectus carefully before making a decision to participate in the exchange offer of original notes for new notes. We have provided definitions for the oil and gas terms used in this prospectus in the “Glossary of Certain Definitions” included in this prospectus.

About Our Company

We are an independent oil and gas company engaged in exploration, development, acquisition and production activities primarily in the Rocky Mountains, Permian Basin, Michigan, Gulf Coast and Mid-Continent regions of the United States. Prior to 2006, we generally emphasized the acquisition of properties that increased our production levels and provided upside potential through further development. Since 2006, we have focused primarily on organic drilling activity and on the development of previously acquired properties, specifically on projects that we believe provide the opportunity for repeatable successes and production growth. On September 20, 2013, we completed the acquisition of certain producing oil and gas wells and undeveloped acreage in the Williston Basin in Williams and McKenzie counties of North Dakota and Roosevelt and Richland counties of Montana (collectively, the “Williston Basin assets”) for $261.3 million, subject to post-closing adjustments. We estimate that the Williston Basin assets had proved reserves of 17.1 MMBOE as of the August 1, 2013 effective date of the acquisition and average daily production of 2.4 MBOE/d for the month of August 2013. We believe the combination of acquisitions, subsequent development and organic drilling provides us with a broad set of growth alternatives and allows us to direct our capital resources to what we believe to be the most advantageous investments.

As demonstrated by our recent capital expenditure programs, we are increasingly focused on a balanced exploration and development program, while continuing to selectively pursue acquisitions that complement our existing core properties. We believe that our significant drilling inventory, combined with our operating experience and cost structure, provides us with meaningful organic growth opportunities. Our growth plan is centered on the following activities:

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pursuing the development of projects that we believe will generate attractive rates of return;

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allocating a portion of our exploration and development budget to leasing and exploring prospect areas;

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maintaining a balanced portfolio of lower risk, long-lived oil and gas properties that provide stable cash flows; and

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seeking property acquisitions that complement our core areas.

We have historically acquired operated and non-operated properties that exceed our rate of return criteria. For acquisitions of properties with additional development and exploration potential, our focus has been on acquiring operated properties so that we can better control the timing and implementation of capital spending. In some instances, we have been able to acquire non-operated property interests at attractive rates of return that established a presence in a new area of interest or that have complemented our existing operations. We intend to continue to acquire both operated and non-operated interests to the extent we believe they meet our return criteria. In addition, our willingness to acquire non-operated properties in new geographic regions provides us with geophysical and geologic data in some cases that leads to further acquisitions in the same region, whether on an operated or non-operated basis.

We continually evaluate our current property portfolio and sell properties when we believe that the sales price realized will provide an above average rate of return for the property or when the property no longer matches the profile of properties we desire to own.

As of December 31, 2012, our estimated proved reserves totaled 378.8 MMBOE, of which 64% were classified as proved developed. These estimated reserves had a pre-tax PV10% value of approximately $7,283.9 million, of which approximately 99% came from properties located in our Rocky Mountains, Permian Basin and Mid-Continent core areas. The following table summarizes our estimated proved reserves as of December 31, 2012 by core area, the corresponding pre-tax PV10% value and the nine months ended September 30, 2013 average daily production rate:


	Proved Reserves as of December 31, 2012(1)(2)
Core Area	Oil (MMBbl)		NGLs (MMBbl)		Natural Gas (Bcf)		Total (MMBOE)		% Oil			Pre-Tax PV10% Value(3) (In millions)			Nine Months Ended September 30, 2013 Average Daily Net Production (MBOE/d)
Rocky Mountains		154.0		17.9		139.8		195.2		79	%	$	4,488.9			70.3
Permian Basin		103.7		15.9		25.1		123.8		84	%		1,731.9			9.8
Mid-Continent(4)		40.9		4.9		20.4		49.2		83	%		969.4			8.0
Michigan		1.7		1.2		28.1		7.6		22	%		62.0			2.4
Gulf Coast		1.0		0.2		10.9		3.0		33	%		31.7			1.3

Total		301.3		40.1		224.3		378.8		80	%	$	7,283.9			91.8

Discounted Future Income Taxes													(1,876.9	)

Standardized Measure of Discounted Future Net Cash Flows												$	5,407.0

(1)	Oil and gas reserve quantities and related discounted future net cash flows have been derived from oil and gas prices calculated using an average of the first-day-of-the month price for each month within the 12 months ended December 31, 2012, pursuant to current SEC and FASB guidelines.

(2)

Estimated total proved reserves at July 31, 2013 were 396.3 MMBOE based on internal engineering with an associated pre-tax PV10% value of $7.7 billion calculated using an average of the first-day-of-the month price for each month within the 12 months ended July 31, 2013, pursuant to current SEC and FASB guidelines. This number does not include any proved reserves attributable to our Postle properties, which we sold on July 15, 2013, or reflect the estimated 17.1 MMBOE associated with the Williston Basin assets, which we acquired on September 20, 2013, but does include the 4.8 MMBOE of proved reserves as of July 31, 2013 associated with the sale of certain properties in the Big Tex prospect which closed on October 31, 2013.

(3)

Pre-tax PV10% may be considered a non-GAAP financial measure as defined by the SEC and is derived from the standardized measure of discounted future net cash flows, which is the most directly comparable GAAP financial measure. Pre-tax PV10% is computed on the same basis as the standardized measure of discounted future net cash flows but without deducting future income taxes. We believe pre-tax PV10% is a useful measure for investors for evaluating the relative monetary significance of our oil and natural gas properties. We further believe investors may utilize our pre-tax PV10% as a basis for comparison of the relative size and value of our proved reserves to other companies because many factors that are unique to each individual company impact the amount of future income taxes to be paid. Our management uses this measure when assessing the potential return on investment related to our oil and gas properties and acquisitions. However, pre-tax PV10% is not a substitute for the standardized measure of discounted future net cash flows. Our pre-tax PV10% and the standardized measure of discounted future net cash flows do not purport to present the fair value of our proved oil, NGL and natural gas reserves.

(4)

Includes total estimated proved reserves of 45.1 MMBOE as of December 31, 2012 and average daily net production of 7.6 MBOE/d (over 196 days from January 1, 2013 to July 15, 2013) during the nine months ended September 30, 2013 attributable to our Postle properties, which we sold on July 15, 2013. See “—Recent Developments—Sale of Postle Properties” below for more information.

Business Strategy

Our goal is to generate meaningful growth in our net asset value per share of proved reserves through the exploration, development and acquisition of oil and gas projects with attractive rates of return on capital employed. To date, we have pursued this goal through both continued field development in our core areas and the acquisition of reserves. Because of our extensive property base, we are pursuing several economically attractive oil and gas opportunities to exploit and develop properties as well as explore our acreage positions for additional production growth and proved reserves. Specifically, we have focused, and plan to continue to focus, on the following:

Pursuing High-Return Organic Reserve Additions. The development of large resource plays such as our Williston Basin project has become one of our central objectives. As of September 30, 2013, we have assembled approximately 1,188,900 gross (729,700 net) developed and undeveloped acres in the Williston Basin located in Montana and North Dakota. As of September 30, 2013, we had 18 drilling rigs operating in the Williston Basin. During 2012 and the first nine months of 2013, the focus of our development has expanded beyond the Sanish field to include several additional areas in the Williston Basin such as the Lewis & Clark/Pronghorn, Hidden Bench/Tarpon, Missouri Breaks and Cassandra prospects. We have completed the construction of our gas processing plant located south of Belfield, North Dakota, which has a processing capacity of 35 MMcf/d and primarily processes production from the Pronghorn area. Currently, there is inlet compression in place to process 35 MMcf/d, and as of September 30, 2013 the plant was processing 20 MMcf/d. In November 2012, we began connecting other operators’ wells to the plant, and we added inlet compression during 2013 in order to fully utilize the plant’s processing capability. During the second quarter of 2013, we installed fractionation equipment to convert NGLs into propane and butane, which can then be sold locally for higher realized prices. Additionally, we completed construction on an oil terminal and a seven-mile oil transmission line to allow for the delivery of oil production from the Pronghorn prospect into the Bridger Four Bears and Bakken Link oil transmission systems. We expect the use of this terminal to reduce our transportation costs per barrel and increase our returns on the development of this prospect.

Developing and Exploiting Existing Properties. Our existing property base and our acquisitions over the past five years have provided us with numerous low-risk opportunities for exploitation and development drilling. As of December 31, 2012, we have identified a drilling inventory of over 2,400 gross wells that we believe will add substantial production over the next five years. Our drilling inventory consists of the development of our proved and non-proved reserves. Additionally, we have several opportunities to apply and expand enhanced recovery techniques that we expect will increase proved reserves and extend the productive lives of our mature fields. In 2005, we acquired the North Ward Estes field, located in the Permian Basin of West Texas. We have experienced significant production increases to date in this field through the use of secondary and tertiary recovery techniques, and we anticipate such production increases to continue over the next five to seven years. In this field, we are actively injecting water and CO₂ and executing extensive re-development, drilling and completion operations, as well as expanding our gas processing facilities, which will allow us to separate and inject approximately 240 MMcf/d of recycled CO₂ and thereby maximize our recovery of oil and gas from this reservoir.

Growing Through Accretive Acquisitions. From 2004 to September 30, 2013, we completed 17 separate significant acquisitions of producing properties for estimated proved reserves of 248.0 MMBOE, as of the effective dates of the acquisitions. Our experienced team of management, land, engineering and geoscience professionals has developed and refined an acquisition program designed to increase reserves and complement

our existing properties, including identifying and evaluating acquisition opportunities, closing purchases and then effectively managing properties we acquire. We intend to selectively pursue the acquisition of properties complementary to our core operating areas.

Disciplined Financial Approach. Our goal is to remain financially strong, yet flexible, through the prudent management of our balance sheet and active management of commodity price volatility. We have historically funded our acquisitions and growth activity through a combination of equity and debt issuances, bank borrowings, internally generated cash flow and certain oil and gas divestitures, as appropriate, to maintain our strong financial position. From time to time, we monetize non-core properties and use the net proceeds from these asset sales to repay debt under our credit facility as we did with the sale of our Postle properties, which we completed on July 15, 2013. To support cash flow generation on our existing properties and help ensure expected cash flows from acquired properties, we periodically enter into derivative contracts. Typically, we use costless collars and fixed price gas contracts to provide an attractive base commodity price level.

Competitive Strengths

We believe that our key competitive strengths lie in our balanced asset portfolio, our experienced management and technical team and our commitment to effective application of new technologies.

Balanced, Long-Lived Asset Base. As of December 31, 2012, we had interests in 10,218 gross (3,927 net) productive wells across approximately 1,277,400 gross (680,300 net) developed acres in our five core geographical areas. We believe this geographic mix of properties and organic drilling opportunities, combined with our continuing business strategy of acquiring and exploiting properties in these areas, presents us with multiple opportunities to execute our strategy. Our proved reserve life is approximately 12.6 years based on year-end 2012 proved reserves and 2012 production.

Experienced Management Team. Our management team averages 28 years of experience in the oil and gas industry. Our personnel have extensive experience in each of our core geographical areas and in all of our operational disciplines. In addition, each of our acquisition professionals has at least 29 years of experience in the evaluation, acquisition and operational assimilation of oil and gas properties.

Commitment to Technology. In each of our core operating areas, we have accumulated detailed geologic and geophysical knowledge and have developed significant technical and operational expertise. In recent years, we have developed considerable expertise in conventional and 3-D seismic imaging and interpretation. As of September 30, 2013, our technical team has access to approximately 7,241 square miles of 3-D seismic data, digital well logs and other subsurface information. This data is analyzed with advanced geophysical and geological computer resources dedicated to the accurate and efficient characterization of the subsurface oil and gas reservoirs that comprise our asset base. In addition, our information systems enable us to update our production databases through daily uploads from hand held computers in the field. We have a team of 10 professionals averaging over 24 years of expertise managing CO₂ floods, which provides us with the ability to pursue CO₂ flood targets and employ this technology to add reserves to our portfolio. This commitment to technology has increased the productivity and efficiency of our field operations and development activities.

In 2011, we completed the build-out and installation of our in-house rock analysis laboratory. This state-of-the-art facility includes two scanning electron microscopes (“SEM”), and these SEMs enable rapid turnaround analysis of drilling or cored wells designed to support real-time drilling and completion decisions. These SEMs also allow us to quantify porosity networks, which in turn helps our staff comparatively evaluate producing zones in present and future plays under consideration. In addition, having SEMs in-house allows our team of experts to analyze samples more rapidly than an outside service company would and with the full operational context that

only full-time employees possess, while protecting our proprietary data. Furthermore, we have established a core layout facility capable of displaying several hundred feet of core slabs under plain or ultraviolet light. The ability for multidisciplinary groups such as geoscientists, operations personnel, reservoir engineers, drilling engineers and senior management to discuss technical issues over the displayed cores has helped us become a leader in tight oil play exploration and development.

Over the past few years, we utilized our “Drill Well on Paper” optimization process to significantly reduce the number of days it takes to drill a well. Due to the success of this program, we expanded the concept using a program called “Build-to-POP” in September 2012. The objective of this program is to optimize the process from the time we build a drilling location to the time we put a well on production (“POP”), to reduce our overall cycle time. Early results have reduced the time from spud to POP from just under 91 days per well to approximately 67 days per well. We have realized additional reductions in the amount of time required to move a rig from one location to the next. Our rig move times have dropped from approximately nine days to just over seven days. We plan to take what we have learned with this project in the Williston Basin and apply these processes to our Redtail prospect in Colorado.

As the Bakken project in the Williston Basin matures and wells are drilled across large areas of the Williston Basin, we have assembled a more comprehensive database of information. This provides the opportunity to apply more scientific analysis of the data and to develop tools to assist our petro-technical staff with well and completion designs. In mid-2012, we initiated a study with a major service provider to review, analyze and make refinements to our fracture stimulations. Results from this study have enhanced our ability to numerically model fracture stimulations and to make refinements to increase the effectiveness of these stimulations and improve well performance.

Recent Developments

Dispositions and Acquisitions

Sale of Postle Properties. On July 15, 2013, we completed the sale of our interests in oil and gas producing properties located in our enhanced oil recovery projects in the Postle and Northeast Hardesty fields in Texas County, Oklahoma, including the related Dry Trail plant gathering and processing facility, oil delivery pipeline, our entire 60% interest in the Transpetco CO₂ pipeline, crude oil swap contracts and certain other related assets and liabilities (collectively the “Postle properties”), effective April 1, 2013, for a cash purchase price of $816.5 million after selling costs and post-closing adjustments. We used the net proceeds from this sale to repay a portion of the debt outstanding under the senior secured credit facility of our wholly-owned subsidiary, Whiting Oil and Gas Corporation (the “credit facility”). The Postle properties had estimated proved reserves of 45.1 MMBOE as of December 31, 2012, representing 11.9% of our proved reserves as of that date, and generated 8% (or 7.6 MBOE/d) of our June 2013 average daily net production.

Acquisition of Williston Basin Assets. On September 20, 2013, we completed the acquisition of certain producing oil and gas wells and undeveloped acreage in the Williston Basin in Williams and McKenzie counties of North Dakota and Roosevelt and Richland counties of Montana for a purchase price of $261.3 million, subject to post-closing adjustments. We estimate that the Williston Basin assets had proved reserves of 17.1 MMBOE as of the August 1, 2013 effective date of the acquisition and average daily production of 2.4 MBOE/d for the month of August 2013.

Sale of Big Tex Acreage. On October 31, 2013, we completed the sale to an undisclosed third party of approximately 45,000 gross (32,200 net) acres, including our interests in certain producing oil and gas wells and undeveloped acreage, located in our Big Tex prospect in the Delaware Basin for a cash purchase price of $150.1 million, subject to normal closing and post-closing adjustments. Of the total net acres sold, approximately 30,800 net acres are located in Pecos County, Texas, and approximately 1,400 net acres are located in Reeves

County, Texas. The effective date of the transaction is October 1, 2013. The producing properties had estimated proved reserves of 1.1 MMBOE as of December 31, 2012, representing 0.3% of our proved reserves as of that date, and generated 0.2 MBOE/d of our third quarter 2013 average daily net production.

Financing Transactions

Completion of $1.9 Billion Senior Notes Offering. On September 12, 2013, we completed the public offering of $1,100.0 million aggregate principal amount of 5.000% Senior Notes due 2019, which mature on March 15, 2019, and $800.0 million aggregate principal amount of 5.750% Senior Notes due 2021, which mature on March 15, 2021. We received net proceeds of approximately $1,877.5 million from the offering, after deducting the underwriting discount and commissions and estimated expenses of the offering. We used or will use the net proceeds from such offering to repay all of the debt outstanding under the credit facility, to fund the $261.3 million acquisition of the Williston Basin assets, to redeem the $250.0 million of outstanding 7.0% Senior Subordinated Notes due 2014 (the “2014 notes”) on October 31, 2013 and for general corporate purposes, including capital expenditures.

Reduction in Commitments under the Credit Facility. On September 12, 2013, we reduced the aggregate commitments under the credit facility from $2.15 billion to $1.2 billion. As of September 30, 2013, we had no borrowings and $3.0 million in letters of credit outstanding under the credit facility with $1,197.0 million of available borrowing capacity.

Completion of $400 Million Senior Notes Offering. On September 26, 2013, we completed the private placement of $400.0 million aggregate principal amount of the original notes subject to this exchange offer, which mature on March 15, 2021. We received net proceeds of approximately $399.3 million from the private placement, after deducting the initial purchaser discount and commissions and estimated expenses of the private placement. We used or will use the net proceeds from such private placement for general corporate purposes, including capital expenditures. In connection with this private placement, we entered into a registration rights agreement and this exchange offer is intended to satisfy our obligations under such agreement.

Redemption of Senior Subordinated Notes Due 2014. On October 31, 2013, we redeemed the 2014 notes at a redemption price equal to 100% of the principal amount thereof, plus the make-whole redemption premium described in the indenture governing the 2014 notes, plus the accrued and unpaid interest up to but not including the date of redemption.

Operational Highlights

Accelerated Development of Redtail Niobrara Area. As of September 30, 2013, we held a total of approximately 168,600 gross (120,000 net) acres in our Redtail area located in the Denver Julesberg Basin in Weld County, Colorado. Our Redtail acreage produces from the Niobrara “B” zone and is also prospective in the Niobrara “A” and “C” zones, as well as the Codell formation. The average acquisition price for acreage in our Redtail area equals $431 per net acre.

Highlighting our recent drilling results at Redtail was the completion of the Razor 33-2813H, which flowed 966 Bbl of oil and 620 Mcf of gas, for a total of 1,069 BOE/d from the Niobrara “B” zone on July 9, 2013. The well’s 6,047-foot lateral was fracture stimulated in a total of 32 stages using our new frac design. We hold a 73.4% working interest and a 61.6% net revenue interest in this well, which was drilled on a 960-acre spacing unit. We have also applied this new frac design to our 640-acre spacing unit wells with positive results. The Razor 25-2514H flowed 593 Bbl of oil and 255 Mcf of gas, for a total of 636 BOE/d from the Niobrara “B” zone on June 30, 2013. The well’s 3,716-foot lateral was fracture stimulated in a total of 18 stages. We hold an 87.5% working interest and a 70.3% net revenue interest in this well. In the eastern portion of the Redtail area, we recently completed the Wildhorse 04-0424H also using our new frac design. This well flowed 596 Bbl of oil and

973 Mcf of gas, for a total of 758 BOE/d from the Niobrara “B” zone on July 28, 2013. The well’s 3,657-foot lateral was fracture stimulated in a total of 24 stages. We hold a 100% working interest and an 80.0% net revenue interest in this well.

We plan to add a third rig to our Redtail drilling program in November 2013. We also plan to add a fourth rig in January 2014 and a fifth rig in June 2014. Our drilling in this area has shifted to pad drilling. As of October 15, 2013, we had three wells flowing back and 10 wells awaiting completion. Our development plan for the Redtail prospect is to drill eight wells per spacing unit to the Niobrara “B” zone and eight wells per spacing unit to the Niobrara “A” zone.

Accumulation of Acreage in New Oil Resource Plays in New Basins for Whiting. We have recently acquired approximately 603,500 gross (500,200) net acres in three new oil resource plays, which are located in three separate basin areas that are new to us, for a total cost of $114.0 million or at an average cost of $228 per net acre.

Corporate Information

Our principal executive offices are located at 1700 Broadway, Suite 2300, Denver, Colorado 80290-2300, and our telephone number is (303) 837-1661.

The Exchange Offer

The following is a brief description of the material terms of the exchange offer. We are offering to exchange the original notes for the new notes. The terms of the new notes offered in the exchange offer are substantially identical to the terms of the original notes, except that the new notes will be part of the same series as the September 12 notes, the new notes will be registered under the Securities Act and certain transfer restrictions, registration rights and additional interest provisions relating to the original notes do not apply to the new notes. For a more complete description, see “Description of New Notes.”

Original Notes

$400,000,000 aggregate principal amount of 5.750% Senior Notes due 2021.

The original notes were issued in transactions exempt from registration under the Securities Act and are subject to transfer restrictions.

New Notes

$400,000,000 aggregate principal amount of 5.750% Senior Notes due 2021.

The Exchange Offer

We are offering to exchange $1,000 principal amount of the new notes for each $1,000 principal amount of your original notes. Original notes tendered in the exchange offer must be in minimum denominations of $2,000 principal amount and any integral multiples of $1,000 in excess thereof. In order for us to exchange your original notes, you must validly tender them to us and we must accept them. For procedures for tendering, see “The Exchange Offer—Procedures for Tendering Original Notes.”

Expiration Date

The exchange offer will expire at 5:00 p.m., New York City time, on December 13, 2013, unless we extend it.

Acceptance of Original Notes and Delivery of New Notes

We will accept for exchange any and all original notes that are validly tendered in the exchange offer and not withdrawn before the exchange offer expires. The new notes will be delivered promptly following the exchange offer.

Withdrawal Rights

You may withdraw your tender of original notes at any time before the exchange offer expires.

Conditions of the Exchange Offer

Our obligation to consummate the exchange offer is not subject to any conditions, other than that the exchange offer does not violate any applicable law or SEC staff interpretation. See “The Exchange Offer—Conditions.” We reserve the right to terminate or amend the exchange offer at any time prior to the expiration date if, among other things, there shall have been proposed, adopted or enacted any law, statute, rule, regulation or SEC staff interpretation which, in our judgment, could reasonably be expected to materially impair our ability to proceed with the exchange offer.

Consequences of Failure to Exchange

If you are eligible to participate in the exchange offer and you do not tender your original notes, then you will not have further exchange or registration rights and you will continue to hold original notes subject to restrictions on transfer.

Federal Income Tax Consequences

The exchange of original notes for new notes will not be a taxable event for federal income tax purposes. See “Material U.S. Federal Income Tax Consequences.”

Use of Proceeds

We will not receive any proceeds from the exchange offer.

Accounting Treatment

We will not recognize any gain or loss on the exchange of notes. See “The Exchange Offer—Accounting Treatment.”

Exchange Agent

The Bank of New York Mellon Trust Company, N.A. is the exchange agent. See “The Exchange Offer—Exchange Agent.”

Resales of New Notes

Based on interpretations by the staff of the SEC set forth in no-action letters issued to other parties, we believe that the new notes issued pursuant to the exchange offer in exchange for original notes may be offered for resale, resold and otherwise transferred by you without compliance with the registration and prospectus delivery provisions of the Securities Act if:

•

you are not our “affiliate” within the meaning of Rule 405 under the Securities Act;

•

you are acquiring the new notes in the ordinary course of your business;

•

you have not engaged in, do not intend to engage in, and have no arrangement or understanding with any person to participate in, a distribution (within the meaning of the Securities Act) of the new notes; and

•

you are not acting on behalf of any person who could not truthfully make the foregoing representations.

If you are an affiliate of ours, or are engaging in or intend to engage in, or have any arrangement or understanding with any person to participate in, a distribution of the new notes, then:

•

you may not rely on the applicable interpretations of the staff of the SEC;

•

you will not be permitted to tender original notes in the exchange offer; and

•

you must comply with the registration and prospectus delivery requirements of the Securities Act in connection with any resale of the original notes.

Each participating broker-dealer that receives new notes for its own account under the exchange offer in exchange for original notes that were acquired by the broker-dealer as a result of market-making or other trading activity must acknowledge that it will deliver a prospectus in connection with any resale of the new notes.

Any broker-dealer that acquired original notes from us may not rely on the applicable interpretations of the staff of the SEC and must comply with registration and prospectus delivery requirements of the Securities Act (including being named as a selling security holder) in connection with any resales of the original notes or the new notes.

See “The Exchange Offer—Procedures for Tendering Original Notes” and “Plan of Distribution.”

The New Notes

The following is a brief summary of the terms of the new notes. As used in this section, the terms “we,” “us” or “our” refer to Whiting Petroleum Corporation and not any of its subsidiaries. For a more complete description of the new notes, see “Description of New Notes” in this prospectus.

Issuer

Whiting Petroleum Corporation, a Delaware corporation.

Notes offered

Up to $400,000,000 aggregate principal amount of 5.750% Senior Notes due 2021.

The new notes are an additional issuance of and will be fully fungible and form a single series voting together as one class with the 5.750% Senior Notes due 2021 issued on September 12, 2013 (the “September 12 notes” and together with the new notes, the “notes”). The new notes will have the same CUSIP number assigned to the September 12 notes. Assuming all original notes are validly tendered and accepted for exchange in this exchange offer, the aggregate principal amount of notes of this series will be $1.2 billion.

Maturity date

The new notes will mature on March 15, 2021.

Interest

Interest will accrue on the new notes at the rate of 5.750% per annum from September 12, 2013. Interest will be paid semi-annually in arrears on each March 15 and September 15, commencing March 15, 2014.

Guarantee

The new notes will be unconditionally guaranteed by our only existing material subsidiary, Whiting Oil and Gas Corporation (the “note guarantor”), and by our future material domestic subsidiaries on a senior unsecured basis.

Ranking

The new notes and new note guarantee will be our and the note guarantor’s senior unsecured obligations and will:

•

rank equally in right of payment with all of our and the note guarantor’s senior indebtedness, including our outstanding senior notes issued on September 12, 2013;

•

rank senior in right of payment to all of our and the note guarantor’s subordinated indebtedness, including our outstanding senior subordinated notes;

•

rank effectively junior to any of our and the note guarantor’s secured indebtedness to the extent of the value of the collateral securing such indebtedness, including the indebtedness under Whiting Oil and Gas Corporation’s credit facility; and

•

rank effectively junior to the obligations of any of our subsidiaries that do not guarantee the new notes, to the extent of the assets of such subsidiaries.

As of September 30, 2013, we had no borrowings and $3.0 million in letters of credit outstanding under Whiting Oil and Gas Corporation’s credit facility, as well as $2,300.0 million of senior debt consisting of the original notes and the senior notes issued on September 12, 2013 and $600.0 million of senior subordinated debt consisting of our 6.5%

Senior Subordinated Notes due 2018 and our 2014 notes. However, on October 31, 2013 we redeemed all $250.0 million aggregate principal amount of the 2014 notes.

Optional redemption

On or after December 15, 2020, we may redeem all or part of the new notes at a redemption price equal to 100% of the principal amount, together with accrued and unpaid interest, if any, to the date of redemption.

Prior to December 15, 2020, we may also redeem all or a part of the new notes at the make-whole redemption price described in this prospectus, together with accrued and unpaid interest, if any, to the date of redemption.

Change of control

If a change of control event occurs and is followed by a rating decline as described in the indenture, each holder of new notes may require us to repurchase all or a portion of its new notes at a price equal to 101% of the principal amount of the new notes, plus any accrued and unpaid interest, if any, to the date of repurchase.

Certain covenants

The indenture governing the new notes contains covenants that, among other things, will limit our ability and the ability of our restricted subsidiaries to:

•

pay dividends on, redeem or repurchase our capital stock or redeem or repurchase debt that is subordinated to the new notes;

•

make investments;

•

incur additional indebtedness or issue preferred stock;

•

create certain liens;

•

sell assets;

•

enter into agreements that restrict dividends or other payments from our restricted subsidiaries to us;

•

consolidate, merge or transfer all or substantially all of the assets of us and our restricted subsidiaries taken as a whole;

•

engage in transactions with affiliates; and

•

create unrestricted subsidiaries.

These covenants are subject to important exceptions and qualifications that are described under the heading “Description of New Notes” in this prospectus. In addition, certain of these covenants will terminate if the new notes achieve an investment grade rating as specified herein.

Denominations

The new notes will only be issued in denominations of $2,000 and any integral multiple of $1,000 in excess thereof.

Summary Historical and Unaudited Pro Forma Financial Information

The following summary historical financial information for the year ended December 31, 2012 has been derived from, and is qualified by reference to, our audited consolidated financial statements and related notes. The following summary historical financial information for the nine months ended September 30, 2013 has been derived from, and is qualified by reference to, our unaudited consolidated financial statements and related notes. This information is only a summary and you should read it in conjunction with our consolidated financial statements and related notes incorporated by reference in this prospectus. The unaudited interim period financial information, in our opinion, includes all adjustments, which are normal and recurring in nature, necessary for a fair presentation for the periods shown. Results for the nine months ended September 30, 2013 are not necessarily indicative of the results to be expected for the full fiscal year.

The following summary unaudited pro forma financial information for the year ended December 31, 2012 and the nine months ended September 30, 2013 has been derived from our unaudited pro forma consolidated financial statements and related notes. This information is only a summary and you should read it in conjunction with our unaudited pro forma consolidated financial statements and related notes incorporated by reference in this prospectus. The unaudited pro forma consolidated statements of income for the year ended December 31, 2012 and the nine months ended September 30, 2013 both give effect to the disposition of the Postle properties as if it had occurred on January 1, 2012. In our opinion, all adjustments that are necessary to present fairly the pro forma information have been made. The following unaudited pro forma consolidated financial statements do not purport to represent what results of operations would have been if the disposition of the Postle properties had occurred on the date indicated above, nor are they indicative of future results of operations. In addition, the unaudited pro forma consolidated financial statements do not give effect to this offering. These unaudited pro forma financial statements should be read in conjunction with our historical financial statements and related notes for the periods presented.


	Year Ended December 31, 2012			Pro Forma for the Year Ended December 31, 2012			Nine Months Ended September 30, 2013			Pro Forma for the Nine Months Ended September 30, 2013
	(In millions)
Statement of Income:
Revenues and other income:
Oil, NGL and natural gas sales	$	2,137.7		$	1,898.2		$	1,963.5		$	1,842.7
Gain (loss) on hedging activities		2.3			2.3			(1.3	)		(1.3	)
Amortization of deferred gain on sale		29.5			29.5			23.7			23.7
Gain on sale of properties		3.4			3.4			119.7			3.2
Interest income and other		0.5			0.5			2.3			2.3

Total revenues and other income		2,173.4			1,933.9			2,107.9			1,870.6

Costs and expenses:
Lease operating		376.4			330.9			314.1			289.9
Production taxes		171.6			155.0			166.2			158.0
Depreciation, depletion and amortization		684.7			629.4			644.1			617.6
Exploration and impairment		167.0			167.0			127.8			127.8
General and administrative		108.6			107.0			108.5			107.1
Interest expense		75.2			58.8			69.6			59.9
Change in Production Participation Plan liability		13.8			13.8			1.3			1.3
Commodity derivative (gain) loss, net		(85.9	)		(85.9	)		25.3			23.5

Total costs and expenses		1,511.4			1,376.0			1,456.9			1,385.1

Income before income taxes		662.0			557.9			651.0			485.5
Income tax expense (benefit):
Current		(0.7	)		(41.2	)		5.1			(59.3	)
Deferred		248.6			248.6			220.6			220.6

Total income tax expense		247.9			207.4			225.7			161.3

Net income	$	414.1		$	350.5		$	425.3		$	324.2

Summary Historical Reserve and Operating Data

The following tables present summary information regarding our estimated net proved oil and natural gas reserves as of December 31, 2010, 2011 and 2012 and our historical operating data for the years ended December 31, 2010, 2011 and 2012 and the nine month periods ended September 30, 2012 and 2013. The reserve estimates presented in the table below are based on reports prepared by Cawley Gillespie & Associates, Inc., independent reserve engineers.


	As of December 31,
	2010		2011		2012
Reserve Data:(1)
Total estimated proved developed reserves:
Oil (MBbl)		160,088		180,975		190,845
NGLs (MBbl)		18,321		22,109		24,204
Natural gas (MMcf)		220,530		211,297		160,893
Total (MBOE)		215,164		238,300		241,864
Total estimated proved reserves:
Oil (MBbl)		224,196		260,144		301,285
NGLs (MBbl)		30,082		37,609		40,098
Natural gas (MMcf)		303,544		284,975		224,264
Total (MBOE)(2)		304,869		345,249		378,760
Pre-tax PV10% value (in millions)(3)	$	5,044.4	$	7,404.7	$	7,283.9
Standardized measure of discounted future net cash flows (in millions)	$	3,667.6	$	5,272.5	$	5,407.0
Total estimated probable reserves:
Oil (MBbl)		49,638		57,128		84,982
NGLs (MBbl)		15,068		13,706		11,922
Natural gas (MMcf)		212,201		210,874		109,582
Total (MBOE)(2)		100,073		105,979		115,168
Total estimated possible reserves:
Oil (MBbl)		146,313		129,066		123,179
NGLs (MBbl)		36,702		34,987		21,936
Natural gas (MMcf)		204,765		187,212		156,382
Total (MBOE)(2)		217,142		195,255		171,178

(1)

Oil and gas reserve quantities and related discounted future net cash flows have been derived from oil and gas prices calculated using an average of the first-day-of-the month price for each month within the 12 months ended December 31, 2010, 2011 and 2012, respectively, pursuant to current SEC and FASB guidelines.

(2)	The proved, probable and possible reserves attributable to the Postle properties, which were sold on July 15, 2013, were 45,065 MBOE, 13,150 MBOE and 80 MBOE, respectively, as of December 31, 2012. See “—Recent Developments—Sale of Postle Properties” above for more information.

(3)


	Year Ended December 31,									Nine Months Ended September 30,
	2010			2011			2012			2012			2013
Operating Data:
Net production:
Oil (MMBbl)		17.5			18.3			23.1			17.0			19.7
NGLs (MMBbl)		1.5			2.1			2.8			2.1			2.1
Natural gas (Bcf)		27.4			26.4			25.8			19.3			19.8
Total production (MMBOE)(1)		23.6			24.8			30.2			22.3			25.1

Net sales (in millions)
Oil(2)	$	1,268.2		$	1,621.5		$	1,940.5		$	1,429.5		$	1,806.1
NGLs		74.0			108.6			108.9			78.2			80.3
Natural gas(2)		133.1			130.0			88.3			64.9			77.1

Total oil, NGL and natural gas sales	$	1,475.3		$	1,860.1		$	2,137.7		$	1,572.6		$	1,963.5

Average sales prices:
Oil (per Bbl)	$	72.61		$	88.61		$	83.86		$	83.99		$	91.74
Effect of oil hedges on average price (per Bbl)		(1.47	)		(1.67	)		(1.25	)		(1.55	)		(1.31	)

Oil net of hedging (per Bbl)	$	71.14		$	86.94		$	82.61		$	82.44		$	90.43

Average NYMEX price (per Bbl)	$	79.55		$	95.14		$	94.19		$	96.20		$	98.17

NGLs (per Bbl)	$	47.33		$	52.38		$	39.36		$	38.06		$	38.78

Natural gas (per Mcf)	$	4.86		$	4.92		$	3.42		$	3.36		$	3.90
Effect of natural gas hedges on average price (per Mcf)		0.04			0.04			0.06			0.06			—

Natural gas net of hedging (per Mcf)	$	4.90		$	4.96		$	3.48		$	3.42		$	3.90

Average NYMEX price (per Mcf)	$	4.39		$	4.04		$	2.79		$	2.58		$	3.67

Cost and expenses (per BOE):
Lease operating expenses	$	11.37		$	12.33		$	12.46		$	12.48		$	12.54
Production taxes	$	4.40		$	5.62		$	5.68		$	5.78		$	6.64
Depreciation, depletion and amortization expense	$	16.69		$	18.89		$	22.67		$	22.26		$	25.71
General and administrative expenses	$	2.74		$	3.43		$	3.59		$	3.80		$	4.33

(1)	The production attributable to the Postle properties, which were sold on July 15, 2013, was 3.4 MMBOE, 3.0 MMBOE and 3.0 MMBOE for the years ended December 31, 2010, 2011 and 2012, respectively, and 2.2 MMBOE and 1.5 MMBOE for the nine months ended September 30, 2012 and 2013, respectively.

(2)	Before consideration of hedging transactions.

Summary Historical Financial Information

The following summary historical financial information for the years ended December 31, 2010, 2011 and 2012 and as of December 31, 2010, 2011 and 2012 has been derived from, and is qualified by reference to, our audited consolidated financial statements and related notes. The following summary historical financial information for the nine months ended September 30, 2012 and 2013 and as of September 30, 2012 and 2013 has been derived from, and is qualified by reference to, our unaudited consolidated financial statements and related notes. This information is only a summary and you should read it in conjunction with our financial statements and related notes incorporated by reference in this prospectus. The unaudited interim period financial information, in our opinion, includes all adjustments, which are normal and recurring in nature, necessary for a fair presentation for the periods shown. Results for the nine months ended September 30, 2013 are not necessarily indicative of the results to be expected for the full fiscal year.


	Year Ended December 31,									Nine Months Ended September 30,
	2010			2011			2012			2012			2013
	(In millions, except per share data)
Consolidated Statements of Income Information:
Revenues and other income:
Oil, NGL and natural gas sales	$	1,475.3		$	1,860.1		$	2,137.7		$	1,572.6		$	1,963.5
Gain (loss) on hedging activities		23.2			8.8			2.3			2.3			(1.3	)
Amortization of deferred gain on sale		15.6			13.9			29.5			21.3			23.7
Gain (loss) on sale of properties		1.4			16.3			3.4			(0.2	)		119.7
Interest income and other		0.6			0.5			0.5			0.4			2.3

Total revenues and other income		1,516.1			1,899.6			2,173.4			1,596.4			2,107.9


Costs and expenses:
Lease operating		268.3			305.5			376.4			278.1			314.1
Production taxes		103.9			139.2			171.6			128.9			166.2
Depreciation, depletion and amortization		393.9			468.2			684.7			496.3			644.1
Exploration and impairment		59.4			84.6			167.0			79.4			127.8
General and administrative		64.7			85.0			108.6			84.6			108.5
Interest expense		59.1			62.5			75.2			55.1			69.6
Loss on early extinguishment of debt		6.2			—			—			—			—
Change in Production Participation Plan liability		12.1			(0.9	)		13.8			6.2			1.3
Commodity derivative (gain) loss, net		7.1			(24.8	)		(85.9	)		(64.2	)		25.3

Total costs and expenses		974.7			1,119.3			1,511.4			1,064.4			1,456.9

Income before income taxes		541.4			780.3			662.0			532.0			651.0
Income tax expense		204.8			288.7			247.9			199.5			225.7

Net income		336.7			491.6			414.1			332.4			425.3
Net loss attributable to noncontrolling interest		—			0.1			0.1			0.1			—

Net income available to shareholders		336.7			491.7			414.2			332.5			425.3
Preferred stock dividends(1)		(64.0	)		(1.1	)		(1.1	)		(0.8	)		(0.5	)

Net income available to common shareholders	$	272.7		$	490.6		$	413.1		$	331.7		$	424.8

Earnings per common share, basic(2)	$	2.57		$	4.18		$	3.51		$	2.82		$	3.60

Earnings per common share, diluted(2)	$	2.55		$	4.14		$	3.48		$	2.79		$	3.56


Other Financial Information:
Net cash provided by operating activities	$	997.3		$	1,192.1		$	1,401.2		$	1,017.9		$	1,254.1
Net cash used in investing activities	$	(914.6	)	$	(1,760.0	)	$	(1,780.3	)	$	(1,221.2	)	$	(1,341.8	)
Net cash provided by (used in) financing activities	$	(75.7	)	$	564.8		$	408.1		$	213.5		$	1,068.4
Capital expenditures	$	923.8		$	1,804.3		$	2,171.5		$	1,612.6		$	2,108.3
Consolidated Balance Sheet Information:
Total assets	$	4,648.8		$	6,045.6		$	7,272.4		$	6,929.5		$	9,127.0
Long-term debt	$	800.0		$	1,380.0		$	1,800.0		$	1,600.0		$	2,904.0
Total equity	$	2,531.3		$	3,029.1		$	3,453.2		$	3,367.1		$	3,890.1

(1)	The year ended December 31, 2010 includes a cash premium of $47.5 million for the induced conversion of our 6.25% convertible perpetual preferred stock.

(2)

On January 26, 2011, our Board of Directors approved a two-for-one split of the Company’s shares of common stock to be effected in the form of a stock dividend effective February 22, 2011. Earnings per common share, basic and diluted for periods prior to February 2011 have been retroactively adjusted to reflect the stock split.

Ratio of Earnings to Fixed Charges

The following table presents our ratios of consolidated earnings to fixed charges for the periods presented.

Nine Months Ended
September 30, 2013

Years Ended December 31,

2012

2011

2010

2009

2008

Ratio of earnings to fixed charges(1)

10.16x

9.36x

12.63x

9.61x

)

6.92x

(1)

For purposes of calculating the ratios above, earnings consist of income (loss) before income taxes and before income or loss from equity investees, plus fixed charges and amortization of capitalized interest and distributed income of equity investees, less capitalized interest. Fixed charges consist of interest expensed, interest capitalized, amortized premiums, discounts and capitalized expenses related to indebtedness and an estimate of interest within rental expense.

(2)

For the year ended December 31, 2009, earnings were inadequate to cover fixed charges, and the ratio of earnings to fixed charges therefore has not been presented for that period. The coverage deficiency necessary for the ratio of earnings to fixed charges to equal 1.00x (one-to-one coverage) was $165.3 million for the year ended December 31, 2009.

RISK FACTORS

Each of the risks described below should be carefully considered, together with all of the other information contained or incorporated by reference in this prospectus, before making an investment decision with respect to participating in the exchange offer of original notes for new notes. If any of the following risks develop into actual events, our business, financial condition or results of operations could be materially and adversely affected, and you may lose all or part of your investment.

Risks Related to the Exchange Offer and New Notes

You may have difficulty selling the original notes that you do not exchange.

If you do not exchange your original notes for the new notes offered in the exchange offer, then you will continue to be subject to the restrictions on transfer of your original notes. Those transfer restrictions are described in the indenture governing the original notes and in the legend contained on the original notes, and arose because we originally issued the original notes under exemptions from, and in transactions not subject to, the registration requirements of the Securities Act.

In general, you may offer or sell your original notes only if they are registered under the Securities Act and applicable state securities laws, or if they are offered and sold under an exemption from those requirements. We do not intend to register the original notes under the Securities Act.

If a large number of original notes are exchanged for new notes issued in the exchange offer, then it may be more difficult for you to sell your unexchanged original notes. In addition, if you do not exchange your original notes in the exchange offer, then you will no longer be entitled to have those original notes registered under the Securities Act.

See “The Exchange Offer—Consequences of Failure to Exchange Original Notes” for a discussion of the possible consequences of failing to exchange your original notes.

You must carefully follow the required procedures to exchange your original notes.

The new notes will be issued in exchange for original notes only after timely receipt by the exchange agent of a duly executed letter of transmittal (or an agent’s message (as defined under “The Exchange Offer—Procedures for Tendering Original Notes”)) and all other required documents. Therefore, if you wish to tender your original notes, you must allow sufficient time to ensure timely delivery. Neither we nor the exchange agent has any duty to notify you of defects or irregularities with respect to tenders of original notes for exchange. Any holder of original notes who tenders in the exchange offer for the purpose of participating in a distribution of the new notes will be required to comply with the registration and prospectus delivery requirements of the Securities Act in connection with any resale transaction. Each broker-dealer that receives new notes for its own account in exchange for original notes that were acquired in market-making or other trading activities must acknowledge that it will deliver a prospectus in connection with any resale of the new notes.

Late deliveries of original notes and other required documents could prevent a holder from exchanging its original notes.

Holders are responsible for complying with all exchange offer procedures. The issuance of new notes in exchange for original notes will only occur upon completion of the procedures described in this prospectus under “The Exchange Offer.” Therefore, holders of original notes who wish to exchange them for new notes should allow sufficient time for timely completion of the exchange procedure. Neither we nor the exchange agent are obligated to extend the offer, notify you of any failure to follow the proper procedure or waive any defect if you fail to follow the proper procedure.

We cannot assure you that an active trading market will develop for the new notes.

We do not intend to apply for listing of the new notes on any securities exchange or to arrange for quotation on any interdealer quotation system. In addition, the liquidity of the trading market in the new notes, and the market price quoted for the new notes, may be adversely affected by changes in the overall market for this type of security and by changes in our financial performance or prospects or in the prospects for companies in our industry generally. In addition, such market-making activities will be subject to limits imposed by the United States federal securities laws. As a result, we cannot assure you that an active trading market will develop for the new notes. If an active trading market does not develop or is not maintained, the market price and liquidity of the new notes may be adversely affected. In that case you may not be able to sell your new notes at a particular time or you may not be able to sell your new notes at a favorable price.

If you are a broker-dealer, your ability to transfer the new notes may be restricted.

A broker-dealer that purchased original notes for its own account as part of market-making or trading activities must comply with the prospectus delivery requirements of the Securities Act when it sells the new notes. Our obligation to make this prospectus available to broker-dealers is limited. Consequently, we cannot guarantee that a proper prospectus will be available to broker-dealers wishing to resell their new notes.

Our debt level and the covenants in the agreements governing our debt could negatively impact our financial condition, results of operations, cash flows and business prospects and prevent us from fulfilling our obligations under the new notes.

As of September 30, 2013, we had no borrowings and $3.0 million in letters of credit outstanding under Whiting Oil and Gas Corporation’s credit facility with $1,197.0 million of available borrowing capacity, as well as $2,300.0 million of senior notes outstanding and $600.0 million of senior subordinated notes outstanding. However, on October 31, 2013 we redeemed all $250.0 million aggregate principal amount of our 7.0% Senior Subordinated Notes due 2014.

We are permitted to incur additional indebtedness, provided we meet certain requirements in the indentures governing the new and original notes, our outstanding senior notes and our senior subordinated notes and Whiting Oil and Gas Corporation’s credit facility.

Our level of indebtedness and the covenants contained in the agreements governing our debt could have important consequences for our operations, including:

•

requiring us to dedicate a substantial portion of our cash flow from operations to required payments on debt, thereby reducing the availability of cash flow for working capital, capital expenditures and other general business activities;

•

limiting our ability to obtain additional financing in the future for working capital, capital expenditures, acquisitions and general corporate and other activities;

•

limiting our flexibility in planning for, or reacting to, changes in our business and the industry in which we operate;

•

placing us at a competitive disadvantage relative to other less leveraged competitors; and

•

making us vulnerable to increases in interest rates, because debt under Whiting Oil and Gas Corporation’s credit agreement is subject to certain rate variability.

We may be required to repay all or a portion of our debt, including the new notes, on an accelerated basis in certain circumstances. If we fail to comply with the covenants and other restrictions in the agreements governing our debt, including the new notes, it could lead to an event of default and the acceleration of our repayment of outstanding debt, including the new notes. Our ability to comply with these covenants and other restrictions may

be affected by events beyond our control, including prevailing economic and financial conditions. Moreover, the borrowing base limitation on Whiting Oil and Gas Corporation’s credit agreement is periodically redetermined based on an evaluation of our oil and gas reserves. Upon a redetermination, if borrowings in excess of the revised borrowing capacity were outstanding, we could be forced to immediately repay a portion of our debt under the credit agreement.

We may not have sufficient funds to make such repayments, including under the new notes. If we are unable to repay our debt out of cash on hand, we could attempt to refinance such debt, sell assets or repay such debt with the proceeds from an equity offering. We may not be able to generate sufficient cash flow to pay the interest on our debt or future borrowings, and equity financings or proceeds from the sale of assets may not be available to pay or refinance such debt. The terms of our debt, including Whiting Oil and Gas Corporation’s credit agreement, may also prohibit us from taking such actions. Factors that will affect our ability to raise cash through an offering of our capital stock, a refinancing of our debt or a sale of assets include financial market conditions and our market value and operating performance at the time of such offering or other financing. We may not be able to successfully complete any such offering, refinancing or sale of assets.

The instruments governing our indebtedness contain various covenants limiting the discretion of our management in operating our business.

The indentures governing the new notes, our outstanding senior notes and our senior subordinated notes and Whiting Oil and Gas Corporation’s credit agreement contain various restrictive covenants that may limit our management’s discretion in certain respects. In particular, these agreements will limit our and our subsidiaries’ ability to, among other things:

•

pay dividends on, redeem or repurchase our capital stock or redeem or repurchase the new notes, our outstanding senior notes or our subordinated debt;

•

make loans to others;

•

make investments;

•

incur additional indebtedness or issue preferred stock;

•

create certain liens;

•

sell assets;

•

enter into agreements that restrict dividends or other payments from our restricted subsidiaries to us;

•

consolidate, merge or transfer all or substantially all of our assets and those of our restricted subsidiaries taken as a whole;

•

engage in transactions with affiliates;

•

enter into hedging contracts;

•

create unrestricted subsidiaries; and

•

enter into sale and leaseback transactions.

In addition, Whiting Oil and Gas Corporation’s credit agreement requires us, as of the last day of any quarter, (i) to not exceed a total debt to the last four quarters’ EBITDAX ratio (as defined in the credit agreement) of 4.0 to 1.0 and (ii) to have a consolidated current assets to consolidated current liabilities ratio (as defined in the credit agreement and which includes an add back of the available borrowing capacity under the credit agreement) of not less than 1.0 to 1.0. Also, the indenture that will govern the new notes and the indentures under which we issued our outstanding senior notes and our senior subordinated notes restrict us from incurring additional indebtedness, subject to certain exceptions, unless our fixed charge coverage ratio (as defined in the indentures) is at least 2.0 to 1. If we were in violation of these covenants, then we may not be able to incur

additional indebtedness, including under Whiting Oil and Gas Corporation’s credit agreement. A substantial or extended decline in oil or natural gas prices may adversely affect our ability to comply with these covenants.

If we fail to comply with the restrictions in the indenture that will govern the new notes, the indentures governing our outstanding senior notes and our senior subordinated notes, Whiting Oil and Gas Corporation’s credit agreement or any other subsequent financing agreements, a default may allow the creditors, if the agreements so provide, to accelerate the related indebtedness as well as any other indebtedness to which a cross-acceleration or cross-default provision applies. In addition, lenders may be able to terminate any commitments they had made to make further funds available to us.

The new notes are effectively subordinated to our secured debt and the secured debt of the subsidiary guarantor of the new notes.

The new notes will be our senior unsecured obligations and will effectively be subordinated to any of our secured indebtedness and the secured indebtedness of Whiting Oil and Gas Corporation (which is a wholly-owned subsidiary of ours and a subsidiary guarantor of the new notes) to the extent of the value of the collateral securing such indebtedness. In the event of our or the guarantor’s bankruptcy, liquidation, reorganization or other winding up, our assets or the assets of the guarantor, as applicable, that secure our secured debt will be available to pay obligations on the new notes and guarantee only after the secured debt has been repaid in full from these assets. There may not be sufficient assets remaining to pay amounts due on any or all of the new notes and guarantees then outstanding.

As a holding company, we rely on payments from Whiting Oil and Gas Corporation in order for us to make payments on the new notes.

We are a holding company with no significant operations of our own. Because our operations are conducted through our wholly-owned subsidiary, Whiting Oil and Gas Corporation, we depend on dividends, advances and other payments from Whiting Oil and Gas Corporation in order to allow us to satisfy our financial obligations. Whiting Oil and Gas Corporation is a separate and distinct legal entity and has no obligation to pay any amounts to us, whether by dividends, advances or other payments. The ability of Whiting Oil and Gas Corporation to pay dividends and make other payments to us depends on its earnings, capital requirements and general financial conditions and is restricted by, among other things, Whiting Oil and Gas Corporation’s credit agreement, applicable corporate and other laws and regulations as well as agreements to which Whiting Oil and Gas Corporation may be a party. Specifically, Whiting Oil and Gas Corporation’s credit agreement allows it to make payments to us so that we may pay interest on the new notes, but does not allow for payments from it to us to pay principal on the new notes. Whiting Oil and Gas Corporation’s credit agreement also prohibits Whiting Oil and Gas Corporation from allowing us to make any principal payments on the new notes. Although Whiting Oil and Gas Corporation is guaranteeing the new notes, the guarantee is subordinated to all of its secured debt, including the indebtedness under the credit facility.

Servicing our debt requires a significant amount of cash, and we may not have sufficient cash flow from our business to pay our substantial debt.

Our ability to make scheduled payments of the principal of, to pay interest on or to refinance our indebtedness, including the new notes, depends on our future performance, which is subject to economic, financial, competitive and other factors beyond our control. Our business may not continue to generate cash flow from operations in the future sufficient to service our debt and make necessary capital expenditures. If we are unable to generate such cash flow, we may be required to adopt one or more alternatives, such as selling assets, restructuring debt or obtaining additional equity capital on terms that may be onerous or highly dilutive. Our ability to refinance our indebtedness will depend on the capital markets and our financial condition at such time. We may not be able to engage in any of these activities or engage in these activities on desirable terms, which could result in a default on our debt obligations.

Despite our current debt levels, we may still incur substantially more debt or take other actions which would intensify the risks discussed above.

Despite our current consolidated debt levels, we and our subsidiaries may be able to incur substantial additional debt in the future. Although the indenture that will govern the new notes, the indentures governing our outstanding senior notes and our senior subordinated notes and Whiting Oil and Gas Corporation’s credit facility contain restrictions on the incurrence of additional indebtedness, these restrictions are subject to a number of qualifications and exceptions, and the additional indebtedness incurred in compliance with these restrictions could be substantial. If we incur any additional indebtedness that ranks equally with the new notes, the holders of that debt will be entitled to share ratably with you in any proceeds distributed in connection with any insolvency, liquidation, reorganization, dissolution or other winding up of our company. This may have the effect of reducing the amount of proceeds paid to you. These restrictions also will not prevent us from incurring obligations that do not constitute indebtedness. In addition, as of September 30, 2013, Whiting Oil and Gas Corporation’s credit agreement had unused commitments of $1,197.0 million.

We may not be able to repurchase the new notes upon a change of control and your rights upon a change of control may be limited.

Upon the occurrence of certain change of control events followed by a rating decline within 90 days as specified in the indenture, holders of the new notes may require us to repurchase all or any part of their new notes. The occurrence of these same change of control events would also obligate us to offer to repurchase our outstanding senior notes and our outstanding 6.5% Senior Subordinated Notes due 2018, although the covenants governing the senior subordinated notes do not contain a requirement for a rating decline, and they could be entitled to be repurchased in circumstances where the new notes offered hereby do not have such a right. We may not have sufficient funds at the time of the change of control to make the required repurchases of the new notes. Additionally, certain events that would constitute a “change of control” (as defined in the indenture) would constitute an event of default under Whiting Oil and Gas Corporation’s credit agreement that would, if it should occur, permit the lenders to accelerate the debt outstanding under such credit agreement and that, in turn, would cause an event of default under the indenture governing the new notes. We would not be permitted to repurchase the new notes prior to termination of and payment in full of the obligations under Whiting Oil and Gas Corporation’s credit agreement.

The source of funds for any repurchase required as a result of any change of control will be our available cash or cash generated from oil and gas operations or other sources, including borrowings, sales of assets, sales of equity or funds provided by a new controlling entity. We cannot assure you, however, that sufficient funds would be available at the time of any change of control to make any required repurchases of the new notes and the 6.5% Senior Subordinated Notes due 2018 tendered and to repay debt under Whiting Oil and Gas Corporation’s credit agreement. Furthermore, using available cash to fund the potential consequences of a change of control may impair our ability to obtain additional financing in the future. Any future credit agreements or other agreements relating to debt to which we may become a party will most likely contain similar restrictions and provisions.

Recent Delaware court decisions have held that the “continuing director” element of the definition of change of control may be interpreted by the courts in a manner that permits the board of directors of a Delaware corporation to approve a slate of directors proposed by a third party in a hostile proxy contest for the purposes of avoiding triggering a change of control under an indenture, even where the board of directors has actively opposed the election of such directors. As such, the ability of holders to require us to offer to purchase their new notes as a result of a successful hostile proxy contest for our board of directors may be limited.

Any subsidiary guarantees of the new notes may be subordinated or avoided by a court.

Initially, Whiting Oil and Gas Corporation will guarantee the new notes on a senior basis and in the future, the new notes will be guaranteed by certain of our newly created or acquired subsidiaries and by certain restricted subsidiaries. See “Description of New Notes—Certain Covenants—Additional Subsidiary Guarantees.” These

guarantees will be joint and several obligations of the guarantors. Various applicable fraudulent conveyance laws have been enacted for the protection of creditors. A court may use those laws to subordinate or avoid any guarantee of the new notes issued by any of our subsidiaries.

A court could avoid or subordinate the guarantee of the new notes by any of our subsidiaries in favor of that subsidiary’s other debts or liabilities to the extent that the court determined either of the following were true at the time the subsidiary issued the guarantee:

•

that subsidiary incurred the guarantee with the intent to hinder, delay or defraud any of its present or future creditors or that such subsidiary contemplated insolvency with a design to favor one or more creditors to the total or partial exclusion of others; or

•

that subsidiary did not receive fair consideration or reasonably equivalent value for issuing the guarantee and, at the time it issued the guarantee, that subsidiary:

•

was insolvent or rendered insolvent by reason of the issuance of the guarantee;

•

was engaged or about to engage in a business or transaction for which the remaining assets of that subsidiary constituted unreasonably small capital; or

•

intended to incur, or believed that it would incur, debts beyond its ability to pay such debts as they matured.

Among other things, a legal challenge of a subsidiary’s guarantee of the new notes on fraudulent conveyance grounds may focus on the benefits, if any, realized by that subsidiary as a result of our issuance of the new notes. To the extent a subsidiary’s guarantee of the new notes is avoided as a result of fraudulent conveyance or held unenforceable for any other reason, the new note holders would cease to have any claim in respect of that guarantee and would be creditors solely of ours.

Claims of new note holders will be structurally subordinated to claims of creditors of any of our subsidiaries that do not guarantee the new notes.

We conduct all of our operations through our subsidiaries. Subject to certain limitations, the indenture governing the new notes permits us to form or acquire certain subsidiaries that are not guarantors of the new notes and to permit such non-guarantor subsidiaries to acquire assets and incur indebtedness, and new note holders would not have any claim as a creditor against any of our non-guarantor subsidiaries to the assets and earnings of those subsidiaries. The claims of the creditors of those subsidiaries, including their trade creditors, banks and other lenders, would have priority over any of our claims or those of our other subsidiaries as equity holders of the non-guarantor subsidiaries. Consequently, in any insolvency, liquidation, reorganization, dissolution or other winding-up of any of the non-guarantor subsidiaries, creditors of those subsidiaries would be paid before any amounts would be distributed to us or to the guarantor as equity, and thus be available to satisfy our obligations under the new notes and other claims against us or the guarantor.

Risks Related to the Oil and Gas Industry and Our Business

Oil and natural gas prices are very volatile. An extended period of low oil and natural gas prices may adversely affect our business, financial condition, results of operations or cash flows.

The oil and gas markets are very volatile, and we cannot predict future oil and natural gas prices. The price we receive for our oil, NGL and natural gas production heavily influences our revenue, profitability, access to capital and future rate of growth. The prices we receive for our production depend on numerous factors beyond our control. These factors include, but are not limited to, the following:

•

changes in regional, domestic and global supply and demand for oil and natural gas;

•

the actions of the Organization of Petroleum Exporting Countries;

•

the price and quantity of imports of foreign oil and natural gas;

•

political and economic conditions, including embargoes, in oil-producing countries or affecting other oil-producing activity, such as recent conflicts in the Middle East;

•

the level of global oil and natural gas exploration and production activity;

•

the effects of global credit, financial and economic issues;

•

the level of global oil and natural gas inventories;

•

developments of United States energy infrastructure, such as the approval to proceed with the Keystone XL pipeline from Hardesty, Alberta to Cushing, Oklahoma and the development of liquefied natural gas exporting facilities and the perceived timing thereof;

•

weather conditions;

•

technological advances affecting energy consumption;

•

domestic and foreign governmental regulations;

•

proximity and capacity of oil and natural gas pipelines and other transportation facilities;

•

the price and availability of competitors’ supplies of oil and natural gas in captive market areas;

•

the price and availability of alternative fuels; and

•

acts of force majeure.

Moreover, government regulations, such as regulation of oil and natural gas gathering and transportation, can adversely affect commodity prices in the long term.

Lower oil, NGL and natural gas prices may not only decrease our revenues on a per unit basis but also may ultimately reduce the amount of oil and natural gas that we can produce economically and therefore potentially lower our reserve quantities. A substantial or extended decline in oil, NGL or natural gas prices may result in impairments of our proved oil and gas properties and may materially and adversely affect our future business, financial condition, results of operations, liquidity or ability to finance planned capital expenditures. To the extent commodity prices received from production are insufficient to fund planned capital expenditures, we will be required to reduce spending or borrow any such shortfall. Lower oil, NGL and natural gas prices may also reduce the amount of our borrowing base under Whiting Oil and Gas Corporation’s credit facility, which is determined at the discretion of the lenders based on the collateral value of our proved reserves that have been mortgaged to the lenders, and is subject to regular redeterminations on May 1 and November 1 of each year, as well as special redeterminations described in the credit agreement.

Drilling for and producing oil and natural gas are high risk activities with many uncertainties that could adversely affect our business, financial condition or results of operations.

Our future success will depend on the success of our development, exploitation, production and exploration activities. Our oil and natural gas exploration and production activities are subject to numerous risks beyond our control, including the risk that drilling will not result in commercially viable oil or natural gas production. Our decisions to purchase, explore, develop or otherwise exploit prospects or properties will depend in part on the evaluation of data obtained through geophysical and geological analyses, production data and engineering studies, the results of which are often inconclusive or subject to varying interpretations. Please read “—Reserve estimates depend on many assumptions that may turn out to be inaccurate…” later in these Risk Factors for a discussion of the uncertainty involved in these processes. Our cost of drilling, completing and operating wells is often uncertain before drilling commences. Overruns in budgeted expenditures are common risks that can make a particular project uneconomical. Further, many factors may curtail, delay or cancel drilling, including the following:

•

delays imposed by or resulting from compliance with regulatory requirements;

•

delays or limits on the issuance of drilling permits on our federal leases, including as a result of government shutdowns;

•

pressure or irregularities in geological formations;

•

shortages of or delays in obtaining qualified personnel or equipment, including drilling rigs, completion services and CO₂;

•

equipment failures or accidents;

•

adverse weather conditions, such as freezing temperatures, hurricanes and storms;

•

reductions in oil, NGL and natural gas prices;

•

pipeline takeaway and refining and processing capacity; and

•

title problems.

Federal, state and local legislative and regulatory initiatives relating to hydraulic fracturing could result in increased costs and additional operating restrictions or delays.

Hydraulic fracturing is an important and common practice that is used to stimulate production of hydrocarbons from tight formations. The process involves the injection of water, sand and chemicals under pressure into formations to fracture the surrounding rock and stimulate production. Hydraulic fracturing has been utilized to complete wells in our most active areas located in the states of Colorado, Michigan, Montana, North Dakota and Texas, and we expect it will also be used in the future. Should our exploration and production activities expand to other states, it is likely that we will utilize hydraulic fracturing to complete or recomplete wells in those areas. The process is typically regulated by state oil and gas commissions. However, the U.S. Environmental Protection Agency (the “EPA”) has asserted federal regulatory authority over hydraulic fracturing involving diesel under the Safe Drinking Water Act’s Underground Injection Control Program and published draft permitting guidance in May 2012 regarding the process for obtaining a permit for hydraulic fracturing involving diesel.

At the same time, the EPA has commenced a study of the potential environmental impacts of hydraulic fracturing activities on drinking water resources. The EPA published a progress report of the study in December 2012 and expects to release a draft final report for public comment and peer review by 2014. Moreover, the EPA announced in October 2011 that it is also launching a study regarding wastewater resulting from hydraulic fracturing activities and currently plans to propose standards by 2014 that such wastewater must meet before being transported to a treatment plant. Other federal agencies are also examining hydraulic fracturing, including the U.S. Department of Energy, the U.S. Government Accountability Office and the White House Council for Environmental Quality. The U.S. Department of the Interior released a draft proposed rule in May 2012 governing hydraulic fracturing in federal and Indian oil and natural gas leases to require disclosure of information regarding the chemicals used in hydraulic fracturing, advance approval for well-stimulation activities, mechanical integrity testing of casing, and monitoring of well-stimulation operations, but on January 18, 2013 the agency announced that the Federal Bureau of Land Management will issue a revised draft of the proposed rule in 2013. In addition, legislation has been introduced in Congress from time to time to provide for federal regulation of hydraulic fracturing and to require disclosure of the chemicals used in the fracturing process. Also, some states have adopted, and other states are considering adopting, regulations that could restrict or impose additional requirements relating to hydraulic fracturing in certain circumstances. For example, on June 17, 2011, Texas enacted a law that requires the disclosure of information regarding the substances used in the hydraulic fracturing process to the Railroad Commission of Texas (the entity that regulates oil and natural gas production) and the public. Such federal or state legislation could require the disclosure of chemical constituents used in the fracturing process to state or federal regulatory authorities who could then make such information publicly available. Disclosure of chemicals used in the fracturing process could make it easier for third parties opposing hydraulic fracturing to pursue legal proceedings against producers and service providers based on allegations that specific chemicals used in the fracturing process could adversely affect human health or the environment including groundwater. In addition, if hydraulic fracturing is regulated at the federal level, our fracturing activities could become subject to additional permit requirements or operational restrictions and also to associated permitting delays, litigation risk and potential increases in costs. Further, local governments may seek to adopt ordinances within their jurisdictions regulating the time, place and manner of

drilling or hydraulic fracturing. No assurance can be given as to whether or not similar measures might be considered or implemented in the jurisdictions in which our properties are located. If new laws, regulations or ordinances that significantly restrict or otherwise impact hydraulic fracturing are passed by Congress or adopted in the states or local municipalities where our properties are located, such legal requirements could make it more difficult or costly for us to perform hydraulic fracturing activities and thereby could affect the determination of whether a well is commercially viable. In addition, restrictions on hydraulic fracturing could reduce the amount of oil and natural gas that we are ultimately able to produce in commercially paying quantities.

Our use of enhanced recovery methods creates uncertainties that could adversely affect our results of operations and financial condition.

One of our business strategies is to commercially develop oil reservoirs using enhanced recovery technologies. For example, we inject water and CO₂ into formations on some of our properties to increase the production of oil and natural gas. The additional production and reserves attributable to the use of these enhanced recovery methods are inherently difficult to predict. If our enhanced recovery programs do not allow for the extraction of oil and gas in the manner or to the extent that we anticipate, our future results of operations and financial condition could be materially adversely affected. Additionally, our ability to utilize CO₂ as an enhanced recovery technique is subject to our ability to obtain sufficient quantities of CO₂. Under our CO₂ contracts, if the supplier suffers an inability to deliver its contractually required quantities of CO₂ to us and other parties with whom it has CO₂ contracts, then the supplier may reduce the amount of CO₂ on a pro rata basis it provides to us and such other parties. If this occurs or if we are otherwise limited in the quantities of CO₂ available to us, we may not have sufficient CO₂ to produce oil and natural gas in the manner or to the extent that we anticipate, and our future oil and gas production volumes could be negatively impacted. These contracts are also structured as “take-or-pay” arrangements, which require us to continue to make payments even if we decide to terminate or reduce our use of CO₂ as part of our enhanced recovery techniques.

The development of the proved undeveloped reserves in the North Ward Estes field may take longer and may require higher levels of capital expenditures than we currently anticipate.

As of December 31, 2012, proved undeveloped reserves comprised 43% of the North Ward Estes field’s total estimated proved reserves. To fully develop these reserves, we expect to incur future development costs of $750.0 million at the North Ward Estes field as of December 31, 2012. At December 31, 2012, this field encompassed 28% of our total estimated future development costs related to proved undeveloped reserves. Development of these reserves may take longer and require higher levels of capital expenditures than we currently anticipate. In addition, the development of these reserves will require the use of enhanced recovery techniques, including water flood and CO₂ injection installations, the success of which is less predictable than traditional development techniques.

Prospects that we decide to drill may not yield oil or gas in commercially viable quantities.

We describe some of our current prospects and our plans to explore those prospects in our Quarterly Reports on Form 10-Q for the quarters ended March 31, 2013, June 30, 2013 and September 30, 2013 and our Annual Report on Form 10-K for the year ended December 31, 2012, which are incorporated by reference in this prospectus. A prospect is a property on which we have identified what our geoscientists believe, based on available seismic and geological information, to be indications of oil or gas. Our prospects are in various stages of evaluation, ranging from a prospect that is ready to drill to a prospect that will require substantial additional seismic data processing and interpretation. There is no way to predict in advance of drilling and testing whether any particular prospect will yield oil or gas in sufficient quantities to recover drilling or completion costs or to be economically viable. The use of seismic data and other technologies and the study of producing fields in the same area will not enable us to know conclusively prior to drilling whether oil or gas will be present or, if present, whether oil or gas will be present in commercial quantities. In addition, because of the wide variance that results from different equipment used to test the wells, initial flow rates may not be indicative of sufficient oil or gas quantities in a particular field. The analogies we draw from available data from other wells, from more

fully explored prospects, or from producing fields may not be applicable to our drilling prospects. We may terminate our drilling program for a prospect if results do not merit further investment.

If oil, NGL and natural gas prices decrease, we may be required to take write-downs of the carrying values of our oil and gas properties.

Accounting rules require that we periodically review the carrying value of our producing oil and gas properties for possible impairment. Based on specific market factors and circumstances at the time of prospective impairment reviews, which may include depressed oil, NGL and natural gas prices, and the continuing evaluation of development plans, production data, economics and other factors, we may be required to write down the carrying value of our oil and gas properties. For example, we recorded a $3.2 million impairment write-down during 2011 for the partial impairment of producing properties, primarily natural gas, in California and Michigan. A write-down constitutes a non-cash charge to earnings. We may incur additional impairment charges in the future, which could have a material adverse effect on our results of operations in the period recognized.

Reserve estimates depend on many assumptions that may turn out to be inaccurate. Any material inaccuracies in these reserve estimates or underlying assumptions will materially affect the quantities and present value of our reserves.

The process of estimating oil and natural gas reserves is complex. It requires interpretations of available technical data and many assumptions, including assumptions relating to economic factors. Any significant inaccuracies in these interpretations or assumptions could materially affect the estimated quantities and present value of reserves referred to in this prospectus and in our Annual Report on Form 10-K for the year ended December 31, 2012, which is incorporated by reference in this prospectus.

In order to prepare our estimates, we must project production rates and timing of development expenditures. We must also analyze available geological, geophysical, production and engineering data. The extent, quality and reliability of this data can vary. The process also requires economic assumptions about matters such as the following:

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historical production from the area compared with production rates from other producing areas;

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the assumed effect of governmental regulation; and

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assumptions about future prices of oil, NGLs and natural gas including differentials, production and development costs, gathering and transportation costs, severance and excise taxes, capital expenditures and availability of funds.

Therefore, estimates of oil and natural gas reserves are inherently imprecise. Actual future production; oil, NGL and natural gas prices; revenues; taxes; exploration and development expenditures; operating expenses; and quantities of recoverable oil and natural gas reserves, most likely will vary from our estimates. Any significant variance could materially affect the estimated quantities and present value of reserves referred to in this prospectus. In addition, we may adjust estimates of proved reserves to reflect production history, results of exploration and development, prevailing oil and natural gas prices and other factors, many of which are beyond our control.

You should not assume that the present value of future net revenues from our proved reserves, as referred to in this prospectus, is the current market value of our estimated proved oil and natural gas reserves. In accordance with SEC requirements, we base the estimated discounted future net cash flows from our proved reserves on 12-month average prices and current costs as of the date of the estimate. Actual future prices and costs may differ materially from those used in the estimate. If natural gas prices decline by $0.10 per Mcf, then the standardized measure of discounted future net cash flows of our estimated proved reserves as of December 31, 2012 would have decreased from $5,407.0 million to $5,398.9 million. If oil prices decline by $1.00 per Bbl, then the standardized measure of discounted future net cash flows of our estimated proved reserves as of December 31, 2012 would have decreased from $5,407.0 million to $5,312.0 million.

Risks associated with the production, gathering, transportation and sale of oil, NGLs and natural gas could adversely affect net income and cash flows.

Our net income and cash flows will depend upon, among other things, oil, NGL and natural gas production and the prices and costs incurred to exploit oil and natural gas reserves. Drilling, production or transportation accidents that temporarily or permanently halt the production and sale of oil, NGLs and natural gas will decrease revenues and increase expenditures. For example, accidents may occur that result in personal injuries, property damage, damage to productive formations or equipment and environmental damages. Any costs incurred in connection with any such accidents that are not insured against will have the effect of reducing net income. Also, we do not have insurance policies in effect that are intended to provide coverage for losses solely related to hydraulic fracturing operations. Please read “—Federal and state legislative and regulatory initiatives relating to hydraulic fracturing…” above in these Risk Factors for a discussion of the uncertainty involved in the practice of hydraulic fracturing. In addition, curtailments or damage to pipelines used to transport oil, NGLs and natural gas production to markets for sale could decrease revenues or increase transportation expenses. Any such curtailment or damage to the gathering systems could also require finding alternative means to transport the oil, NGLs and natural gas production, which alternative means could result in additional costs that will have the effect of increasing transportation expenses.

Also, drilling, production and transportation of hydrocarbons bear an inherent risk of loss of containment. Potential consequences include loss of reserves, loss of production, loss of economic value associated with the affected wellbore, contamination of soil, ground water, and surface water, as well as potential fines, penalties or damages associated with any of the foregoing consequences.

Our exploration and development operations require substantial capital, and we may be unable to obtain needed capital or financing on satisfactory terms, which could lead to a loss of properties and a decline in our oil and natural gas reserves.

The oil and gas industry is capital intensive. We make and expect to continue to make substantial capital expenditures in our business and operations for the exploration, development, production and acquisition of oil and natural gas reserves. To date, we have financed capital expenditures through a combination of equity and debt issuances, bank borrowings and internally generated cash flows. We intend to finance future capital expenditures with cash flow from operations, existing financing arrangements and certain oil and gas divestitures. Our cash flow from operations and access to capital is subject to a number of variables, including:

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our proved reserves;

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the level of oil and natural gas we are able to produce from existing wells;

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the prices at which oil and natural gas are sold;

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the costs of producing oil and natural gas; and

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our ability to acquire, locate and produce new reserves.

If our revenues or the borrowing base under Whiting Oil and Gas Corporation’s credit facility decreases as a result of lower oil and natural gas prices, operating difficulties, declines in reserves, or for any other reason, then we may have limited ability to obtain the capital necessary to sustain our operations at current levels.

We may, from time to time, need to seek additional financing. There can be no assurance as to the availability or terms of any additional financing. If additional capital is needed, we may not be able to obtain debt or equity financing on terms favorable to us, or at all. If cash generated by operations or available under our revolving credit facility is not sufficient to meet our capital requirements, the failure to obtain additional financing could result in a curtailment of our operations relating to the exploration and development of our prospects, which in turn could lead to a possible loss of properties and a decline in our oil and natural gas reserves.

Our acquisition activities may not be successful.

As part of our growth strategy, we have made and may continue to make acquisitions of businesses and properties. However, suitable acquisition candidates may not continue to be available on terms and conditions we find acceptable, and acquisitions pose substantial risks to our business, financial condition and results of operations. In pursuing acquisitions, we compete with other companies, many of which have greater financial and other resources to acquire attractive companies and properties. The following are some of the risks associated with acquisitions, including any completed or future acquisitions:

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some of the acquired businesses or properties may not produce revenues, reserves, earnings or cash flow at anticipated levels;

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we may assume liabilities that were not disclosed to us or that exceed our estimates;

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we may be unable to integrate acquired businesses successfully and realize anticipated economic, operational and other benefits in a timely manner, which could result in substantial costs and delays or other operational, technical or financial problems;

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acquisitions could disrupt our ongoing business, distract management, divert resources and make it difficult to maintain our current business standards, controls and procedures; and

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we may issue additional equity or debt securities related to future acquisitions.

Substantial acquisitions or other transactions could require significant external capital and could change our risk and property profile.

In order to finance acquisitions of additional producing or undeveloped properties, we may need to alter or increase our capitalization substantially through the issuance of debt or equity securities, the sale of production payments or other means. These changes in capitalization may significantly affect our risk profile. Additionally, significant acquisitions or other transactions can change the character of our operations and business. The character of the new properties may be substantially different in operating or geological characteristics or geographic location than our existing properties. Furthermore, we may not be able to obtain external funding for additional future acquisitions or other transactions or to obtain external funding on terms acceptable to us.

The unavailability or high cost of additional drilling rigs, equipment, supplies, personnel and oil field services could adversely affect our ability to execute our exploration and development plans on a timely basis or within our budget.

The demand for qualified and experienced field personnel to conduct field operations, geologists, geophysicists, engineers and other professionals in the oil and natural gas industry can fluctuate significantly, often in correlation with oil and natural gas prices, causing periodic shortages. Historically, there have been shortages of drilling rigs and other oilfield equipment as demand for rigs and equipment has increased along with the number of wells being drilled. These factors also cause significant increases in costs for equipment, services and personnel. Higher oil and natural gas prices generally stimulate demand and result in increased prices for drilling rigs, crews and associated supplies, equipment and services. Additionally, our operations in some instances require supply materials such as CO₂ for production which could become subject to shortage and increasing costs. Shortages of field personnel, drilling rigs, equipment, supplies or personnel or price increases could delay or adversely affect our exploration and development operations, which could have a material adverse effect on our business, financial condition, results of operations or cash flows, or restrict operations.

Our identified drilling locations are scheduled out over several years, making them susceptible to uncertainties that could materially alter the occurrence or timing of their drilling.

We have specifically identified and scheduled drilling locations as an estimation of our future multi-year drilling activities on our existing acreage. As of December 31, 2012, we had identified a drilling inventory of over 2,400 gross drilling locations. These scheduled drilling locations represent a significant part of our growth

strategy. Our ability to drill and develop these locations depends on a number of uncertainties, including oil and natural gas prices, the availability of capital, costs of oil field goods and services, drilling results, ability to extend drilling acreage leases beyond expiration, regulatory approvals and other factors. Because of these uncertainties, we do not know if the numerous potential drilling locations we have identified will ever be drilled or if we will be able to produce oil or gas from these or any other potential drilling locations. As such, our actual drilling activities may materially differ from those presently identified, which could adversely affect our business.

We have been an early entrant into new or emerging plays. As a result, our drilling results in these areas are uncertain, and the value of our undeveloped acreage may decline, and we may incur impairment charges if drilling results are unsuccessful.

While our costs to acquire undeveloped acreage in new or emerging plays have generally been less than those of later entrants into a developing play, our drilling results in these areas are more uncertain than drilling results in areas that are developed and producing. Since new or emerging plays have limited or no production history, we are unable to use past drilling results in those areas to help predict our future drilling results. Therefore, our cost of drilling, completing and operating wells in these areas may be higher than initially expected, and the value of our undeveloped acreage will decline if drilling results are unsuccessful. Furthermore, if drilling results are unsuccessful, we may be required to write down the carrying value of our undeveloped acreage in new or emerging plays. For example, during the fourth quarter of 2010, we recorded a $5.8 million non-cash charge for the impairment of unproved properties in the central Utah Hingeline play. We may also incur such impairment charges in the future, which could have a material adverse effect on our results of operations in the period taken. Additionally, our rights to develop a portion of our undeveloped acreage may expire if not successfully developed or renewed. See “Acreage” in Item 2 of our Annual Report on Form 10-K for the year ended December 31, 2012, which is incorporated by reference in this prospectus, for more information relating to the expiration of our rights to develop undeveloped acreage.

Properties that we acquire may not produce as projected, and we may be unable to identify liabilities associated with the properties or obtain indemnities from sellers for liabilities they may have created.

Our business strategy includes a continuing acquisition program. From 2004 through September 30, 2013, we completed 17 separate significant acquisitions of producing properties with a combined purchase price of $2,160.3 million for estimated proved reserves as of the effective dates of the acquisitions of 248.0 MMBOE. The successful acquisition of producing properties requires assessments of many factors, which are inherently inexact and may be inaccurate, including the following:

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the amount of recoverable reserves;

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future oil and natural gas prices;

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estimates of operating costs;

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estimates of future development costs;

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timing of future development costs;

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estimates of the costs and timing of plugging and abandonment; and

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the assumption of unknown potential environmental and other liabilities, losses or costs, including, for example, historical spills or releases for which we are not indemnified or for which our indemnity is inadequate.

Our assessment will not reveal all existing or potential problems, nor will it permit us to become familiar enough with the properties to assess fully their capabilities and deficiencies. In the course of our due diligence, we may not inspect every well, platform, facility or pipeline. Inspections may not reveal structural and environmental problems, such as pipeline corrosion or groundwater contamination, when they are made. We may

not be able to obtain contractual indemnities from the seller for liabilities that it created. We may be required to assume the risk of the physical condition of the properties in addition to the risk that the properties may not perform in accordance with our expectations.

Our use of oil and natural gas price hedging contracts involves credit risk and may limit higher revenues in the future in connection with commodity price increases and may result in significant fluctuations in our net income.

We enter into hedging transactions of our oil and natural gas production revenues to reduce our exposure to fluctuations in the price of oil and natural gas. Our hedging transactions to date have consisted of financially settled crude oil and natural gas forward sales contracts, primarily costless collars, placed with major financial institutions. As of October 1, 2013, we had contracts, which include our 10% share of the Whiting USA Trust II hedges, covering the sale of between 1,044,340 and 1,334,340 barrels of oil per month for the remainder of 2013. All of our oil hedges will expire by December 2014. See “Quantitative and Qualitative Disclosure about Market Risk” in Item 3 of our Quarterly Report on Form 10-Q for the quarter ended September 30, 2013, which is incorporated by reference in this prospectus, for pricing and a more detailed discussion of our hedging transactions.

We may in the future enter into these and other types of hedging arrangements to reduce our exposure to fluctuations in the market prices of oil and natural gas, or alternatively, we may decide to unwind or restructure the hedging arrangements we previously entered into. Hedging transactions expose us to risk of financial loss in some circumstances, including if production is less than expected, the other party to the contract defaults on its obligations or there is a change in the expected differential between the underlying price in the hedging agreement and actual prices received. Hedging transactions may limit the benefit we may otherwise receive from increases in the price for oil and natural gas. Furthermore, if we do not engage in hedging transactions or unwind hedging transactions we previously entered into, then we may be more adversely affected by declines in oil and natural gas prices than our competitors who engage in hedging transactions. Additionally, hedging transactions may expose us to cash margin requirements.

We recognize all gains and losses from changes in commodity derivative fair values immediately in earnings rather than deferring any such amounts in accumulated other comprehensive income. Consequently, we may experience significant net losses, on a non-cash basis, due to changes in the value of our hedges as a result of commodity price volatility.

Seasonal weather conditions and lease stipulations adversely affect our ability to conduct drilling activities in some of the areas where we operate.

Oil and gas operations in the Rocky Mountains are adversely affected by seasonal weather conditions and lease stipulations designed to protect various wildlife. In certain areas, drilling and other oil and gas activities can only be conducted during the spring and summer months. This limits our ability to operate in those areas and can intensify competition during those months for drilling rigs, oil field equipment, services, supplies and qualified personnel, which may lead to periodic shortages. Resulting shortages or high costs could delay our operations and materially increase our operating and capital costs.

An increase in the differential or decrease in the premium between the NYMEX or other benchmark prices of oil and natural gas and the wellhead price we receive could have a material adverse effect on our results of operations, financial condition and cash flows.

The prices that we receive for our oil and natural gas production generally trade at a discount, but sometimes at a premium, to the relevant benchmark prices such as NYMEX. A negative difference between the benchmark price and the price received is called a differential and a positive difference is called a premium. The differential and premium may vary significantly due to market conditions, the quality and location of production and other risk factors. We cannot accurately predict oil and natural gas differentials and premiums. Increases in

the differential and decreases in the premium between the benchmark price for oil and natural gas and the wellhead price we receive could have a material adverse effect on our results of operations, financial condition and cash flows.

We may incur substantial losses and be subject to substantial liability claims as a result of our oil and gas operations.

We are not insured against all risks. Losses and liabilities arising from uninsured and underinsured events could materially and adversely affect our business, financial condition or results of operations. Our oil and natural gas exploration and production activities are subject to all of the operating risks associated with drilling for and producing oil and natural gas, including the possibility of:

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environmental hazards, such as uncontrollable flows of oil, gas, brine, well fluids, toxic gas or other pollution into the environment, including groundwater and shoreline contamination;

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abnormally pressured formations;

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mechanical difficulties, such as stuck oil field drilling and service tools and casing collapse;

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fires and explosions;

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personal injuries and death; and

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natural disasters.

Any of these risks could adversely affect our ability to conduct operations or result in substantial losses to our company. We may elect not to obtain insurance if we believe that the cost of available insurance is excessive relative to the risks presented. In addition, pollution and environmental risks generally are not fully insurable. If a significant accident or other event occurs and is not fully covered by insurance, then it could adversely affect us.

We have limited control over activities on properties we do not operate, which could reduce our production and revenues and increase capital expenditures.

If we do not operate the properties in which we own an interest, we do not have control over normal operating procedures, expenditures or future development of our properties. The failure of an operator of our wells to adequately perform operations or an operator’s breach of the applicable agreements could reduce our production and revenues. The success and timing of our drilling and development activities on properties operated by others therefore depends upon a number of factors outside of our control, including the operator’s decisions with respect to the timing and amount of capital expenditures, the period of time over which the operator seeks to generate a return on capital expenditures, inclusion of other participants in drilling wells, and the use of technology, as well as the operator’s expertise and financial resources and the operator’s relative interest in the field. Operators may also opt to decrease operational activities following a significant decline in oil or natural gas prices. Because we do not have a majority interest in most wells we do not operate, we may not be in a position to remove the operator in the event of poor performance. Accordingly, while we use commercially reasonable efforts to cause the operator to act as a reasonably prudent operator, we are limited in our ability to do so.

Our use of 3-D seismic data is subject to interpretation and may not accurately identify the presence of oil and gas, which could adversely affect the results of our drilling operations.

Even when properly used and interpreted, 3-D seismic data and visualization techniques are only tools used to assist geoscientists in identifying subsurface structures and hydrocarbon indicators and do not enable the interpreter to know whether hydrocarbons are, in fact, present in those structures. In addition, the use of 3-D seismic and other advanced technologies requires greater predrilling expenditures than traditional drilling strategies, and we could incur losses as a result of such expenditures. Thus, some of our drilling activities may not be successful or economical, and our overall drilling success rate or our drilling success rate for activities in a

particular area could decline. We often gather 3-D seismic data over large areas. Our interpretation of seismic data delineates for us those portions of an area that we believe are desirable for drilling. Therefore, we may choose not to acquire option or lease rights prior to acquiring seismic data, and in many cases, we may identify hydrocarbon indicators before seeking option or lease rights in the location. If we are not able to lease those locations on acceptable terms, it would result in our having made substantial expenditures to acquire and analyze 3-D seismic data without having an opportunity to attempt to benefit from those expenditures.

Market conditions or operational impediments may hinder our access to oil and gas markets or delay our production.

In connection with our continued development of oil and gas properties, we may be disproportionately exposed to the impact of delays or interruptions of production from wells in these properties, caused by transportation capacity constraints, curtailment of production or the interruption of transporting oil and gas volumes produced. In addition, market conditions or a lack of satisfactory oil and gas transportation arrangements may hinder our access to oil and gas markets or delay our production. The availability of a ready market for our oil, NGL and natural gas production depends on a number of factors, including the demand for and supply of oil, NGLs and natural gas and the proximity of reserves to pipelines and terminal facilities. Our ability to market our production depends substantially on the availability and capacity of gathering systems, pipelines and processing facilities owned and operated by third-parties. Additionally, entering into arrangements for these services exposes us to the risk that third parties will default on their obligations under such arrangements. Our failure to obtain such services on acceptable terms or the default by a third party on their obligation to provide such services could materially harm our business. We may be required to shut in wells for a lack of a market or because access to gas pipelines, gathering systems or processing facilities may be limited or unavailable. If that were to occur, then we would be unable to realize revenue from those wells until production arrangements were made to deliver the production to market.

We are subject to complex laws that can affect the cost, manner or feasibility of doing business.

Exploration, development, production and sale of oil and natural gas are subject to extensive federal, state, local and international regulation. We may be required to make large expenditures to comply with governmental regulations. Matters subject to regulation include:

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discharge permits for drilling operations;

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drilling bonds;

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reports concerning operations;

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the spacing of wells;

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unitization and pooling of properties; and

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taxation.

Under these laws, we could be liable for personal injuries, property damage and other damages. Failure to comply with these laws also may result in the suspension or termination of our operations and subject us to administrative, civil and criminal penalties. Moreover, these laws could change in ways that could substantially increase our costs. Any such liabilities, penalties, suspensions, terminations or regulatory changes could materially and adversely affect our financial condition and results of operations.

Our operations may incur substantial costs and liabilities to comply with environmental laws and regulations.

Our oil and gas operations are subject to stringent federal, state and local laws and regulations relating to the release or disposal of materials into the environment or otherwise relating to environmental protection. These laws and regulations may require the acquisition of a permit before drilling commences; restrict the types,

quantities and concentration of materials that can be released into the environment in connection with drilling and production activities; limit or prohibit drilling activities on certain lands lying within wilderness, wetlands and other protected areas; and impose substantial liabilities for pollution resulting from our operations. Failure to comply with these laws and regulations may result in the assessment of administrative, civil and criminal penalties, incurrence of investigatory or remedial obligations, or the imposition of injunctive relief. Under these environmental laws and regulations, we could be held strictly liable for the removal or remediation of previously released materials or property contamination regardless of whether we were responsible for the release or if our operations were standard in the industry at the time they were performed. Private parties, including the surface owners of properties upon which we drill, may also have the right to pursue legal actions to enforce compliance as well as to seek damages for non-compliance with environmental laws and regulations or for personal injury or property damage. We may not be able to recover some or any of these costs from insurance. Moreover, federal law and some state laws allow the government to place a lien on real property for costs incurred by the government to address contamination on the property.

Changes in environmental laws and regulations occur frequently and may have a materially adverse impact on our business. For example, in August 2012, the EPA published final rules under the federal Clean Air Act that subject oil and natural gas production, processing, transmission and storage operations to regulation under the New Source Performance Standards and National Emission Standards for Hazardous Air Pollutants. With regards to production activities, these final rules require, among other things, the reduction of volatile organic compound emissions from certain fractured and refractured gas wells for which well completion operations are conducted and, in particular, requiring some of these wells to use reduced emission completions, also known as “green completions”, after January 1, 2015. These regulations also establish specific new requirements regarding emissions from production-related wet seal and reciprocating compressors, pneumatic controllers and storage vessels. Any increased governmental regulation or suspension of oil and natural gas exploration or production activities that arises out of these incidents could result in higher operating costs, which could, in turn, adversely affect our operating results. Also, for instance, any changes in laws or regulations that result in more stringent or costly material handling, storage, transport, disposal or cleanup requirements could require us to make significant expenditures to maintain compliance and may otherwise have a material adverse effect on our results of operations, competitive position or financial condition as well as those of the oil and gas industry in general.

Climate change legislation or regulations restricting emissions of “greenhouse gasses” could result in increased operating costs and reduced demand for oil and gas that we produce.

On December 15, 2009, the EPA published its findings that emissions of carbon dioxide, methane, and other greenhouse gases (“GHG”) present an endangerment to public health and the environment because emissions of such gases are, according to the EPA, contributing to the warming of the earth’s atmosphere and other climate changes. Based on these findings, the EPA has begun adopting and implementing regulations that restrict emissions of GHG under existing provisions of the federal Clean Air Act (the “CAA”), including one rule that limits emissions of GHG from motor vehicles beginning with the 2012 model year. The EPA has asserted that these final motor vehicle GHG emission standards trigger the CAA construction and operating permit requirements for stationary sources, commencing when the motor vehicle standards took effect on January 2, 2011. On June 3, 2010, the EPA published its final rule to address the permitting of GHG emissions from stationary sources under the Prevention of Significant Deterioration (“PSD”) and Title V permitting programs. This rule “tailors” these permitting programs to apply to certain stationary sources of GHG emissions in a multi-step process, with the largest sources first subject to permitting. Further, facilities required to obtain PSD permits for their GHG emissions are required to reduce those emissions consistent with guidance for determining “best available control technology” standards for GHG, which guidance was published by the EPA in November 2010. Also in November 2010, the EPA expanded its existing GHG reporting rule to include onshore oil and natural gas production, processing, transmission, storage, and distribution facilities. This rule requires reporting of GHG emissions from such facilities on an annual basis with reporting beginning in 2012 for emissions occurring in 2011.

In addition, both houses of Congress have actively considered legislation to reduce emissions of GHG, and many states have already taken legal measures to reduce emissions of GHG, primarily through the development of GHG inventories, greenhouse gas permitting and/or regional GHG cap and trade programs. Most of these cap and trade programs work by requiring either major sources of emissions or major producers of fuels to acquire and surrender emission allowances, with the number of allowances available for purchase reduced each year until the overall GHG emission reduction goal is achieved. In the absence of new legislation, the EPA is issuing new regulations that limit emissions of GHG associated with our operations which will require us to incur costs to inventory and reduce emissions of GHG associated with our operations and which could adversely affect demand for the oil, NGLs and natural gas that we produce. Finally, it should be noted that some scientists have concluded that increasing concentrations of GHG in the atmosphere may produce climate changes that have significant physical effects, such as increased frequency and severity of storms, droughts, floods and other climatic events; if any such effects were to occur, they could have an adverse effect on our assets and operations.

Unless we replace our oil and natural gas reserves, our reserves and production will decline, which would adversely affect our cash flows and results of operations.

Unless we conduct successful development, exploitation and exploration activities or acquire properties containing proved reserves, our proved reserves will decline as those reserves are produced. Producing oil and natural gas reservoirs generally are characterized by declining production rates that vary depending upon reservoir characteristics and other factors. Our future oil and natural gas reserves and production, and therefore our cash flow and income, are highly dependent on our success in efficiently developing and exploiting our current reserves and economically finding or acquiring additional recoverable reserves. We may not be able to develop, exploit, find or acquire additional reserves to replace our current and future production.

The loss of senior management or technical personnel could adversely affect us.

To a large extent, we depend on the services of our senior management and technical personnel. The loss of the services of our senior management or technical personnel, including James J. Volker, Chairman and Chief Executive Officer; James T. Brown, President and Chief Operating Officer; Mark R. Williams, Senior Vice President, Exploration and Development; Steven A. Kranker, Vice President, Reservoir Engineering/Acquisitions; Rick A. Ross, Vice President, Operations; David M. Seery, Vice President, Land; Michael J. Stevens, Vice President and Chief Financial Officer; or Peter W. Hagist, Vice President, Permian Operations, could have a material adverse effect on our operations. We do not maintain, nor do we plan to obtain, any insurance against the loss of any of these individuals.

Competition in the oil and gas industry is intense, which may adversely affect our ability to compete.

We operate in a highly competitive environment for acquiring properties, marketing oil and gas and securing trained personnel. Many of our competitors possess and employ financial, technical and personnel resources substantially greater than ours, which can be particularly important in the areas in which we operate. Those companies may be able to pay more for productive oil and gas properties and exploratory prospects and to evaluate, bid for and purchase a greater number of properties and prospects than our financial or personnel resources permit. Our ability to acquire additional prospects and to find and develop reserves in the future will depend on our ability to evaluate and select suitable properties and to consummate transactions in a highly competitive environment. Also, there is substantial competition for available capital for investment in the oil and gas industry. We may not be able to compete successfully in the future in acquiring prospective reserves, developing reserves, marketing hydrocarbons, attracting and retaining quality personnel and raising additional capital.

Certain federal income tax deductions currently available with respect to oil and gas exploration and development may be eliminated or deferred as a result of future legislation.

In April 2013, President Obama’s Administration released its proposed federal budget for fiscal year 2014 that would, if enacted into law, make significant changes to United States tax laws, including the elimination of

certain key U.S. federal income tax preferences currently available to oil and gas exploration and production companies. Such changes include, but are not limited to:

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the repeal of the percentage depletion allowance for oil and gas properties;

•

the elimination of current deductions for intangible drilling and development costs;

•

the elimination of the deduction for U.S. oil and gas production activities; and

•

an extension of the amortization period for certain geological and geophysical expenditures.

It is unclear, however, whether any such changes will be enacted or how soon such changes could be effective. The passage of any legislation containing these or similar changes in U.S. federal income tax law could eliminate or defer certain tax deductions that are currently available with respect to oil and gas exploration and development, and any such changes could negatively affect our financial condition and results of operations.

In connection with the passage of the Dodd-Frank Wall Street Reform and Consumer Protection Act, new regulations forthcoming in this area may result in increased costs and cash collateral requirements for the types of oil and gas derivative instruments we use to manage our risks related to oil and gas commodity price volatility.

On July 21, 2010, the Dodd-Frank Wall Street Reform and Consumer Protection Act was enacted into law. This financial reform legislation includes provisions that require over-the-counter derivative transactions to be executed through an exchange or centrally cleared. In addition, the legislation provides an exemption from mandatory clearing requirements based on regulations to be developed by the Commodity Futures Trading Commission (the “CFTC”) and the SEC for transactions by non-financial institutions to hedge or mitigate commercial risk. At the same time, the legislation includes provisions under which the CFTC may impose collateral requirements for transactions, including those that are used to hedge commercial risk. However, during drafting of the legislation, members of Congress adopted report language and issued a public letter stating that it was not their intention to impose margin and collateral requirements on counterparties that utilize transactions to hedge commercial risk. Final rules on major provisions in the legislation, like new margin requirements, will be established through rulemakings and will not take effect until 12 months after the date of enactment. Although we cannot predict the ultimate outcome of these rulemakings, new regulations in this area may result in increased costs and cash collateral requirements for the types of oil and gas derivative instruments we use to hedge and to otherwise manage our financial risks related to volatility in oil and gas commodity prices.

USE OF PROCEEDS

We will not receive any cash proceeds from the issuance of the new notes. In consideration for issuing the new notes contemplated by this prospectus, we will receive original notes in a like principal amount. We will cancel all original notes exchanged for new notes in the exchange offer.

CAPITALIZATION

The following table sets forth our capitalization as of September 30, 2013.

You should read this table in conjunction with our historical financial statements and related notes incorporated by reference in this prospectus.


	As of September 30, 2013
	(In thousands)

Cash and cash equivalents(1)	$	1,025,579

Long-term debt:
Credit facility(2)	$	—
5.000% Senior Notes due 2019		1,100,000
5.750% Senior Notes due 2021(3)		800,000
5.750% Senior Notes due 2021(4)		403,991
7.0% Senior Subordinated Notes due 2014(5)		250,000
6.5% Senior Subordinated Notes due 2018		350,000

Total long-term debt		2,903,991

Total Whiting shareholders’ equity(1)		3,881,917

Total capitalization	$	6,785,908

(1)

As a result of the redemption on October 31, 2013 of the 7.0% Senior Subordinated Notes due 2014, we made a cash payment of $4.0 million as the make-whole redemption premium, exclusive of principal and accrued and unpaid interest, and incurred a non-cash charge of $0.4 million related to unamortized debt issuance costs, which will result in a reduction in retained earnings of $4.4 million on a pre-tax basis.

(2)	As of September 30, 2013, we had no borrowings and $3.0 million in letters of credit outstanding under the credit facility with $1,197.0 million available borrowing capacity.

(3)	Issued on September 12, 2013.

(4)	Issued on September 26, 2013 and includes unamortized debt premium of $4.0 million.

(5)	The 7.0% Senior Subordinated Notes due 2014 are classified under current portion of long-term debt as of September 30, 2013. However, on October 31, 2013 we redeemed the 2014 notes. See “Prospectus Summary—Recent Developments—Redemption of Senior Subordinated Notes Due 2014.”

SELECTED HISTORICAL FINANCIAL DATA

The consolidated statements of income and statements of cash flows information for the years ended December 31, 2010, 2011 and 2012 and the consolidated balance sheet information at December 31, 2011 and 2012 are derived from, and are qualified by reference to, our audited financial statements incorporated by reference in this prospectus. The consolidated statements of income and statements of cash flows information for the years ended December 31, 2008 and 2009 and the consolidated balance sheet information at December 31, 2008, 2009 and 2010 are derived from, and are qualified by reference to, audited financial statements that are not included in this prospectus. The consolidated statements of income and statements of cash flows information for the nine months ended September 30, 2012 and 2013 and the consolidated balance sheet information at September 30, 2012 and 2013 are derived from, and are qualified by reference to, our unaudited consolidated financial statements and related notes incorporated by reference in this prospectus. Our historical results include the results from our recent acquisitions beginning on the following dates: proved properties in the Williston Basin, September 20, 2013; proved properties in Colorado, September 1, 2010; additional interests in North Ward Estes, November 1, 2009 and October 1, 2009; and Flat Rock natural gas field, May 30, 2008. This information is only a summary and you should read it in conjunction with our financial statements and related notes incorporated by reference in this prospectus. The consolidated financial data may not be indicative of future performance.


	Years ended December 31,															Nine Months Ended September 30,
	2008			2009			2010			2011			2012			2012			2013
	(in millions, except per share data)
Consolidated Statements of Income Information:
Revenues and other income:
Oil, NGL and natural gas sales	$	1,316.5		$	917.5		$	1,475.3		$	1,860.1		$	2,137.7		$	1,572.6		$	1,963.5
Gain (loss) on hedging activities		(107.6	)		38.8			23.2			8.8			2.3			2.3			(1.3	)
Amortization of deferred gain on sale		12.1			16.6			15.6			13.9			29.5			21.3			23.7
Gain (loss) on sale of properties		—			5.9			1.4			16.3			3.4			(0.2	)		119.7
Interest income and other		1.1			0.6			0.6			0.5			0.5			0.4			2.3

Total revenues and other income		1,222.1			979.4			1,516.1			1,899.6			2,173.4			1,596.4			2,107.9

Costs and expenses:
Lease operating		241.2			237.3			268.3			305.5			376.4			278.1			314.1
Production taxes		87.5			64.7			103.9			139.2			171.6			128.9			166.2
Depreciation, depletion and amortization		277.5			394.8			393.9			468.2			684.7			496.3			644.1
Exploration and impairment		55.3			73.0			59.4			84.6			167.0			79.4			127.8
General and administrative		61.7			42.3			64.7			85.0			108.6			84.6			108.5
Interest expense		65.1			64.6			59.1			62.5			75.2			55.1			69.6
Loss on early extinguishment of debt		—			—			6.2			—			—			—			—
Change in Production Participation Plan liability		32.1			3.3			12.1			(0.9	)		13.8			6.2			1.3
Commodity derivative (gain) loss, net		(7.1	)		262.2			7.1			(24.8	)		(85.9	)		(64.2	)		25.3

Total costs and expenses		813.3			1,142.2			974.7			1,119.3			1,511.4			1,064.4			1,456.9

Income (loss) before taxes		408.8			(162.8	)		541.4			780.3			662.0			532.0			651.0
Income tax expense (benefit)		156.7			(55.9	)		204.8			288.7			247.9			199.5			225.7

Net income (loss)		252.1			(106.9	)		336.7			491.6			414.1			332.4			425.3
Net loss attributable to noncontrolling interest		—			—			—			0.1			0.1			0.1			—

Net income (loss) available to shareholders		252.1			(106.9	)		336.7			491.7			414.2			332.5			425.3
Preferred stock dividends(1)		—			(10.3	)		(64.0	)		(1.1	)		(1.1	)		(0.8	)		(0.5	)

Net income (loss) available to common shareholders	$	252.1		$	(117.2	)	$	272.7		$	490.6		$	413.1		$	331.7		$	424.8

Earnings (loss) per common share, basic(2)	$	2.98		$	(1.18	)	$	2.57		$	4.18		$	3.51		$	2.82		$	3.60

Earnings (loss) per common share, diluted(2)	$	2.97		$	(1.18	)	$	2.55		$	4.14		$	3.48		$	2.79		$	3.56


Other Financial Information:
Net cash provided by operating activities	$	766.5		$	453.8		$	997.3		$	1,192.1		$	1,401.2		$	1,017.9		$	1,254.1
Net cash used in investing activities	$	(1,138.5	)	$	(523.5	)	$	(914.6	)	$	(1,760.0	)	$	(1,780.3	)	$	(1,221.2	)	$	(1,341.8	)
Net cash provided by (used in) financing activities	$	366.8		$	72.1		$	(75.7	)	$	564.8		$	408.1		$	213.5		$	1,068.4
Capital Expenditures	$	1,330.9		$	585.8		$	923.8		$	1,804.3		$	2,171.5		$	1,612.6		$	2,108.3
Consolidated Balance Sheet Information:
Total assets	$	4,029.1		$	4,029.5		$	4,648.8		$	6,045.6		$	7,272.4		$	6,929.5		$	9,127.0
Long-term debt	$	1,239.8		$	779.6		$	800.0		$	1,380.0		$	1,800.0		$	1,600.0		$	2,904.0
Total equity	$	1,808.8		$	2,270.1		$	2,531.3		$	3,029.1		$	3,453.2		$	3,367.1		$	3,890.1

(1)	The year ended December 31, 2010 includes a cash premium of $47.5 million for the induced conversion of our 6.25% convertible perpetual preferred stock.

(2)

On January 26, 2011, our Board of Directors approved a two-for-one split of the Company’s shares of common stock to be effected in the form of a stock dividend effective February 22, 2011. Earnings (loss) per common share, basic and diluted for periods prior to February 2011 have been retroactively adjusted to reflect the stock split.

THE EXCHANGE OFFER

Purpose and Effect; Registration Rights

We issued and sold the original notes on September 26, 2013 in transactions exempt from the registration requirements of the Securities Act. Therefore, the original notes are subject to significant restrictions on resale. In connection with the issuance of the original notes, we entered into a registration rights agreement, dated September 26, 2013 which required that we:

•

use our reasonable best efforts to cause to be filed with the SEC a registration statement with respect to the exchange offer to exchange the original notes for publicly registered 5.750% Senior Notes due 2021 (the “new notes”), which will be the same class as and fungible with the 5.750% Senior Notes due 2021 issued on September 12, 2013 (the “September 12 notes” and together with the new notes, the “notes”);

•

to use our reasonable best efforts to cause such registration statement to be declared effective by the SEC within 270 days after September 26, 2013; and

•

after the effectiveness of the registration statement with respect to the exchange offer, promptly commence the exchange offer and use our reasonable best efforts to complete the exchange offer not later than 60 days after such effective date.

If you participate in the exchange offer, then you will, with limited exceptions, receive new notes that are freely tradable and not subject to restrictions on transfer. You should read this prospectus under the heading “—Resales of New Notes” for more information relating to your ability to transfer new notes.

If you are eligible to participate in the exchange offer and do not tender your original notes, then you will continue to hold the untendered original notes, which will continue to be subject to restrictions on transfer under the Securities Act.

The exchange offer is intended to satisfy our exchange offer obligations under the registration rights agreement. The above summary of the registration rights agreement is not complete. You are encouraged to read the full text of the registration rights agreement, which has been filed as an exhibit to the registration statement that includes this prospectus.

Terms of the Exchange Offer

We are offering to exchange $400,000,000 aggregate principal amount of our original notes which have not been registered under the Securities Act for a like principal amount of our registered new notes.

Upon the terms and subject to the conditions set forth in this prospectus and in the accompanying letter of transmittal, we will accept all original notes validly tendered and not withdrawn before 5:00 p.m., New York City time, on the expiration date of the exchange offer. We will issue $1,000 principal amount of new notes in exchange for each $1,000 principal amount of outstanding original notes we accept in the exchange offer. Holders may tender some or all of their original notes pursuant to the exchange offer in denominations of $2,000 and integral multiples of $1,000 in excess thereof. The exchange offer is not conditioned upon any minimum amount of original notes being tendered.

The form and terms of the new notes will be the same as the form and terms of the original notes, except that:

•

the new notes will be part of the same series as, and be fully fungible with, the September 12 notes and have the same CUSIP number as the September 12 notes;

•

the new notes will be registered under the Securities Act and thus will not be subject to the restrictions on transfer or bear legends restricting their transfer;

•

the new notes will not be subject to the registration rights relating to the original notes; and

•

the new notes will not provide for the payment of additional interest under circumstances relating to the timing of the exchange offer.

The new notes will evidence the same debt as the original notes and will be issued under, and be entitled to the benefits of, the indenture governing the September 12 notes.

The new notes will accrue interest from September 12, 2013. Accordingly, registered holders of new notes on the record date for the first interest payment date following the completion of the exchange offer will receive interest accrued from September 12, 2013.

In connection with the exchange offer, you do not have any appraisal or dissenters’ rights under the indenture. We intend to conduct the exchange offer in accordance with the registration rights agreement and the applicable requirements of the Securities Act, the Securities Exchange Act of 1934, as amended (the “Exchange Act”), and the rules and regulations of the SEC. The exchange offer is not being made to, nor will we accept tenders for exchange from, a holder of the original notes in any jurisdiction in which the exchange offer or the acceptance of it would not be in compliance with the securities or blue sky laws of the jurisdiction.

We will be deemed to have accepted validly tendered original notes when we have given oral or written notice of our acceptance to the exchange agent. The exchange agent will act as agent for the tendering holders for the purpose of receiving the new notes from us.

If we do not accept any tendered original notes because of an invalid tender or for any other reason, then we will return certificates for any unaccepted original notes without expense to the tendering holder as promptly as practicable after the expiration date.

Expiration Date; Amendments

The exchange offer will expire at 5:00 p.m., New York City time, on December 13, 2013, unless we, in our sole discretion, extend the exchange offer.

If we determine to extend the exchange offer, then we will notify the exchange agent of any extension by oral or written notice and give each registered holder notice of the extension by means of a press release or other public announcement before 9:00 a.m., New York City time, on the next business day after the previously scheduled expiration date.

We reserve the right, in our sole discretion, to delay accepting any original notes, to extend the exchange offer, to amend or terminate the exchange offer if any of the conditions described below under “—Conditions” have not been satisfied or waived by giving oral or written notice to the exchange agent of the delay, extension, amendment or termination. Further, we reserve the right, in our sole discretion, to amend the terms of the exchange offer in any manner.

Any delay in acceptance for exchange, extension or amendment will be followed as promptly as practicable by a public announcement of the delay. If we amend the exchange offer in a manner we determine constitutes a material change, we will promptly disclose the amendment in a manner reasonably calculated to inform the holders of original notes of the amendment, and we will extend the exchange offer for a period of five to ten business days, depending upon the significance of the amendment and the manner of disclosure to the holders of the original notes, if the exchange offer would otherwise expire during that five to ten business day period. If we change the consideration being offered or the percentage of original notes being sought in the exchange offer, we will keep the exchange offer open for at least ten business days from the date on which we provide notice to holders of the original notes. The rights we have reserved in this paragraph are in addition to our rights set forth under “—Conditions.”

Procedures for Tendering Original Notes

Any tender of original notes that is not withdrawn prior to the expiration date will constitute a binding agreement between the tendering holder and us upon the terms and subject to the conditions set forth in this prospectus and in the accompanying letter of transmittal. A holder who wishes to tender original notes in the exchange offer must do either of the following:

•

properly complete, sign and date the letter of transmittal, including all other documents required by the letter of transmittal; have the signature on the letter of transmittal guaranteed if the letter of transmittal so requires; and deliver that letter of transmittal and other required documents to the exchange agent at the address listed below under “—Exchange Agent” on or before the expiration date; or

•

if the original notes are tendered under the book-entry transfer procedures described below, transmit to the exchange agent, on or before the expiration date, an agent’s message.

In addition, one of the following must occur:

•

the exchange agent must receive certificates representing your original notes along with the letter of transmittal on or before the expiration date;

•

the exchange agent must receive a timely confirmation of book-entry transfer of the original notes into the exchange agent’s account at The Depository Trust Company of New York City, or DTC, under the procedure for book-entry transfers described below along with the letter of transmittal or a properly transmitted agent’s message, on or before the expiration date; or

•

the holder must comply with the guaranteed delivery procedures described below.

The term “agent’s message” means a message, transmitted by a book-entry transfer facility to and received by the exchange agent and forming a part of the book-entry confirmation, which states that the book-entry transfer facility has received an express acknowledgement from the tendering DTC participant stating that the participant has received and agrees to be bound by the letter of transmittal and that we may enforce the letter of transmittal against the participant.

The method of delivery of original notes, the letter of transmittal and all other required documents to the exchange agent is at your election and risk. Rather than mail these items, we recommend that you use an overnight or hand delivery service. In all cases, you should allow sufficient time to assure timely delivery to the exchange agent before the expiration date. Do not send letters of transmittal or original notes to us.

Generally, an eligible institution must guarantee signatures on a letter of transmittal or a notice of withdrawal unless the original notes are tendered:

•

by a registered holder of the original notes who has not completed the box entitled “Special Issuance Instructions” or “Special Delivery Instructions” on the letter of transmittal; or

•

for the account of an eligible institution.

If signatures on a letter of transmittal or a notice of withdrawal are required to be guaranteed, the guarantee must be by a firm which is:

•

a member of a registered national securities exchange;

•

a commercial bank or trust company having an office or correspondent in the United States; or

•

another “eligible guarantor institution” within the meaning of Rule 17Ad-15 under the Exchange Act.

If the letter of transmittal is signed by a person other than the registered holder of any outstanding original notes, the original notes must be endorsed or accompanied by appropriate powers of attorney. The power of attorney must be signed by the registered holder exactly as the registered holder(s) name(s) appear(s) on the original notes and an eligible institution must guarantee the signature on the power of attorney.

If the letter of transmittal, or any original notes or powers of attorney are signed by trustees, executors, administrators, guardians, attorneys-in-fact, officers of corporations or others acting in a fiduciary or representative capacity, these persons should so indicate when signing. Unless waived by us, they should also submit evidence satisfactory to us of their authority to so act.

If you wish to tender original notes that are registered in the name of a broker, dealer, commercial bank, trust company or other nominee, you should promptly instruct the registered holder to tender on your behalf. If you wish to tender on your behalf, you must, before completing the procedures for tendering original notes, either register ownership of the original notes in your name or obtain a properly completed bond power from the registered holder. The transfer of registered ownership may take considerable time.

We will determine in our sole discretion all questions as to the validity, form, eligibility, including time of receipt, and acceptance of original notes tendered for exchange. Our determination will be final and binding on all parties. We reserve the absolute right to reject any and all tenders of original notes that are not properly tendered or original notes, our acceptance of which might, in the judgment of our counsel, be unlawful. We also reserve the absolute right to waive any defects, irregularities or conditions of tender as to any particular original notes. Our interpretation of the terms and conditions of the exchange offer, including the instructions in the letter of transmittal, will be final and binding on all parties. Unless waived, any defects or irregularities in connection with tenders of original notes must be cured within the time period we determine. Neither we, the exchange agent nor any other person will incur any liability for failure to give you notification of defects or irregularities with respect to tenders of your original notes.

By tendering, you will represent to us that:

•

any new notes that the holder receives will be acquired in the ordinary course of its business;

•

the holder has no arrangement or understanding with any person or entity to participate in the distribution (within the meaning of the Securities Act) of the new notes;

•

if the holder is not a broker-dealer, that it is not engaged in and does not intend to engage in the distribution (within the meaning of the Securities Act) of the new notes;

•

if the holder is a broker-dealer, that the holder’s original notes were acquired as a result of market-making activities or other trading activities;

•

the holder is not our “affiliate,” as defined in Rule 405 of the Securities Act, or, if the holder is our affiliate, it will comply with any applicable registration and prospectus delivery requirements of the Securities Act; and

•

the holder is not acting on behalf of any person who could not truthfully make the foregoing representations.

If any holder or any such other person is our “affiliate,” or is engaged in or intends to engage in or has an arrangement or understanding with any person to participate in a distribution of the new notes to be acquired in the exchange offer, then that holder or any such other person:

•

may not rely on the applicable interpretations of the staff of the SEC;

•

is not entitled and will not be permitted to tender original notes in the exchange offer; and

•

must comply with the registration and prospectus delivery requirements of the Securities Act in connection with any resale transaction.

Each broker-dealer that receives new notes for its own account in exchange for original notes, where the original notes were acquired by the broker-dealer as a result of market-making activities or other trading activities, must acknowledge that it will deliver a prospectus in connection with any resale of the new notes. The letter of transmittal states that by so acknowledging and by delivering a prospectus, a broker-dealer will not be deemed to admit that it is an “underwriter” within the meaning of the Securities Act.

Any broker-dealer that acquired original notes directly from us may not rely on the applicable interpretations of the staff of the SEC and must comply with the registration and delivery requirements of the Securities Act (including being named as a selling security holder) in connection with any resales of the original notes or the new notes.

Acceptance of Original Notes for Exchange; Delivery of New Notes

Upon satisfaction or waiver of all conditions to the exchange offer, we will accept, promptly after the expiration date, all original notes properly tendered and will issue the new notes promptly after acceptance of the original notes. For purposes of the exchange offer, we will be deemed to have accepted properly tendered original notes for exchange when we have given oral or written notice of that acceptance to the exchange agent. For each original note accepted for exchange, you will receive a new note having a principal amount equal to that of the surrendered original note.

In all cases, we will issue new notes for original notes that we have accepted for exchange under the exchange offer only after the exchange agent timely receives:

•

certificates for your original notes or a timely confirmation of book-entry transfer of your original notes into the exchange agent’s account at DTC; and

•

a properly completed and duly executed letter of transmittal and all other required documents or a properly transmitted agent’s message.

If we do not accept any tendered original notes for any reason set forth in the terms of the exchange offer or if you submit original notes for a greater principal amount than you desire to exchange, we will return the unaccepted or non-exchanged original notes without expense to you. In the case of original notes tendered by book-entry transfer into the exchange agent’s account at DTC under the book-entry procedures described below, we will credit the non-exchanged original notes to your account maintained with DTC.

Book-Entry Transfer

We understand that the exchange agent will make a request within two business days after the date of this prospectus to establish accounts for the original notes at DTC for the purpose of facilitating the exchange offer, and any financial institution that is a participant in DTC’s system may make book-entry delivery of original notes by causing DTC to transfer the original notes into the exchange agent’s account at DTC in accordance with DTC’s procedures for transfer. Although delivery of original notes may be effected through book-entry transfer at DTC, the exchange agent must receive a properly completed and duly executed letter of transmittal with any required signature guarantees, or an agent’s message instead of a letter of transmittal, and all other required documents at its address listed below under “— Exchange Agent” on or before the expiration date, or if you comply with the guaranteed delivery procedures described below, within the time period provided under those procedures.

Guaranteed Delivery Procedures

If you wish to tender your original notes and your original notes are not immediately available, or you cannot deliver your original notes, the letter of transmittal or any other required documents or comply with DTC’s procedures for transfer before the expiration date, then you may participate in the exchange offer if:

•

the tender is made through an eligible institution;

•

before the expiration date, the exchange agent receives from the eligible institution a properly completed and duly executed notice of guaranteed delivery, substantially in the form provided by us, by facsimile transmission, mail or hand delivery, containing:

•

the name and address of the holder and the principal amount of original notes tendered;

•

a statement that the tender is being made thereby; and

•

a guarantee that within three New York Stock Exchange trading days after the expiration date, the certificates representing the original notes in proper form for transfer or a book-entry confirmation and any other documents required by the letter of transmittal will be deposited by the eligible institution with the exchange agent; and

•

the exchange agent receives the properly completed and executed letter of transmittal as well as certificates representing all tendered original notes in proper form for transfer, or a book-entry confirmation, and all other documents required by the letter of transmittal within three New York Stock Exchange trading days after the expiration date.

Withdrawal Rights

You may withdraw your tender of original notes at any time before the exchange offer expires.

For a withdrawal to be effective, the exchange agent must receive a written notice of withdrawal at its address listed below under “—Exchange Agent.” The notice of withdrawal must:

•

specify the name of the person who tendered the original notes to be withdrawn;

•

identify the original notes to be withdrawn, including the principal amount, or, in the case of original notes tendered by book-entry transfer, the name and number of the DTC account to be credited, and otherwise comply with the procedures of DTC;

•

be signed in the same manner as the old signature on the letter of transmittal by which the original notes were tendered (including any required signature guarantees) or be accompanied by documents of transfer sufficient to have the trustee with respect to the original notes register the transfer of the original notes into the name of the person withdrawing the tender; and

•

if certificates for original notes have been transmitted, specify the name in which those original notes are registered if different from that of the withdrawing holder.

If certificates for original notes have been delivered or otherwise identified to the exchange agent in connection with the exchange offer and are to be withdrawn then, before the release of these certificates by the exchange agent, the holder must also submit the serial numbers of the particular certificates to be withdrawn and a signed notice of withdrawal with the signatures guaranteed by an eligible institution, unless the holder is an eligible institution.

We will determine in our sole discretion all questions as to the validity, form and eligibility, including time of receipt, of notices of withdrawal. Our determination will be final and binding on all parties. Any original notes so withdrawn will be deemed not to have been validly tendered for purposes of the exchange offer. We will return any original notes that have been tendered but that are not exchanged for any reason to the holder, without cost, as soon as practicable after withdrawal, rejection of tender or termination of the exchange offer. In the case of original notes tendered by book-entry transfer into the exchange agent’s account at DTC, the original notes will be credited to an account maintained with DTC for the original notes. You may retender properly withdrawn original notes by following one of the procedures described under “—Procedures for Tendering Original Notes” at any time on or before the expiration date.

Conditions

Notwithstanding any other term of the exchange offer, we will not be required to accept for exchange, or to exchange new notes for, any original notes if:

•

the exchange offer, or the making of any exchange by a holder of original notes, would violate any applicable law or applicable interpretation by the staff of the SEC; or

•

any action or proceeding is instituted or threatened in any court or by or before any governmental agency with respect to the exchange offer which, in our judgment, would reasonably be expected to impair our ability to proceed with the exchange offer.

The conditions listed above are for our sole benefit and we may assert them regardless of the circumstances giving rise to any condition. Subject to applicable law, we may waive these conditions in our discretion in whole or in part at any time and from time to time.

We expressly reserve the right, at any time or at various times, to extend the period of time during which the exchange offer is open. Consequently, we may delay acceptance of any original notes by giving oral or written notice of an extension to their holders. During an extension, all original notes previously tendered will remain subject to the exchange offer, and we may accept them for exchange.

Exchange Agent

The Bank of New York Mellon Trust Company, N.A. is the exchange agent for the exchange offer. You should direct any questions and requests for assistance and requests for additional copies of this prospectus, the letter of transmittal or the notice of guaranteed delivery to the exchange agent addressed as follows:

By Overnight or Hand Delivery or Mail:

The Bank of New York Mellon Trust Company, N.A.

Corporate Trust Operations

Reorganization Unit

111 Sanders Creek Parkway

East Syracuse, New York 13057

Attention: Dacia Brown

(315) 414-3349

By Facsimile:

(For Eligible Institutions Only)

(504) 212-1610

Attention: Corporate Trust Operations Reorganization Unit

Confirm by Telephone:

(315) 414-3349

Delivery of the letter of transmittal to an address other than as listed above or transmission via facsimile other than as listed above will not constitute a valid delivery of the letter of transmittal.

Fees and Expenses

We will bear the expenses of soliciting tenders pursuant to the exchange offer. The principal solicitation for tenders pursuant to the exchange offer is being made by mail; however, additional solicitation may be made by telephone, telecopy, in person or by other means by our officers and regular employees and by officers and employees of our affiliates.

We have not retained any dealer-manager in connection with the exchange offer and will not make any payments to brokers, dealers or others soliciting acceptances of the exchange offer. However, we will pay the exchange agent reasonable and customary fees for its services and will reimburse it for its reasonable out-of-pocket expenses. We may also pay brokerage houses and other custodians, nominees and fiduciaries the reasonable out-of-pocket expenses incurred by them in forwarding copies of this prospectus, letters of transmittal and related documents to the beneficial owners of the original notes and in handling or forwarding tenders for exchange. We will pay the other expenses incurred in connection with the exchange offer, including fees and expenses of the trustee, accounting and legal fees and printing costs.

Transfer Taxes

We will pay all transfer taxes, if any, applicable to the exchange of original notes pursuant to the exchange offer. If, however, certificates representing new notes or original notes for principal amounts not tendered or accepted for exchange are to be delivered to, or are to be issued in the name of, any person other than the registered holder of the original notes tendered, or if tendered original notes are registered in the name of any person other than the person signing the letter of transmittal, or if a transfer tax is imposed for any reason other than the exchange of original notes pursuant to the exchange offer, then the amount of any transfer taxes (whether imposed on the registered holder or any other persons) will be payable by the tendering holder. If satisfactory evidence of payment of any taxes or exemption therefrom is not submitted with the letter of transmittal, the amount of any transfer taxes will be billed directly to the tendering holder.

Accounting Treatment

We will record the new notes at the same carrying values as the original notes, as reflected in our accounting records on the date of exchange. Accordingly, we will not recognize any gain or loss on the exchange of notes. We will amortize the expenses of the exchange offer over the term of the new notes.

Consequences of Failure to Exchange Original Notes

If you are eligible to participate in the exchange offer but do not tender your original notes, you will not have any further registration rights, except in limited circumstances with respect to specific types of holders of original notes. Original notes that are not tendered or are tendered but not accepted will, following the consummation of the exchange offer, continue to be subject to the provisions in the indenture governing the original notes regarding the transfer and exchange of the original notes and the existing restrictions on transfer set forth in the legend on the original notes. Accordingly, you may resell the original notes that are not exchanged only:

•

to us;

•

so long as the original notes are eligible for resale under Rule 144A under the Securities Act, to a person whom you reasonably believe is a “qualified institutional buyer” within the meaning of Rule 144A purchasing for its own account or for the account of a qualified institutional buyer in a transaction meeting the requirements of Rule 144A;

•

for resales outside the United States, to non-U.S. persons in accordance with the requirements of Regulation S under the Securities Act;

•

in accordance with another exemption from the registration requirements of the Securities Act; or

•

under an effective registration statement under the Securities Act;

in each case in accordance with all other applicable securities laws. We do not intend to register the original notes under the Securities Act.

Original notes that are not exchanged in the exchange offer will remain outstanding and continue to accrue interest and will be entitled to the rights and benefits their holders have under the indenture relating to the original notes. Holders of any original notes that remain outstanding after consummation of the exchange offer will vote as a single class for purposes of determining whether holders of the requisite percentage of the class have taken certain actions or exercised certain rights under the indenture governing the original notes.

Resales of New Notes

Based on interpretations of the staff of the SEC, as set forth in no action letters to third parties, we believe that new notes issued under the exchange offer in exchange for original notes may be offered for resale, resold

and otherwise transferred by any original note holder without further registration under the Securities Act and without delivery of a prospectus that satisfies the requirements of Section 10 of the Securities Act if:

•

the holder is not our “affiliate” within the meaning of Rule 405 under the Securities Act;

•

the new notes are acquired in the ordinary course of the holder’s business; and

•

the holder does not intend to participate in a distribution (within the meaning of the Securities Act) of the new notes.

Any holder who exchanges original notes in the exchange offer with the intention of participating in any manner in a distribution of the new notes must comply with the registration and prospectus delivery requirements of the Securities Act in connection with a secondary resale transaction.

This prospectus may be used for an offer to resell, resale or other retransfer of new notes. With regard to broker-dealers, only broker-dealers that acquire the original notes as a result of market-making activities or other trading activities may participate in the exchange offer. Each broker-dealer that receives new notes for its own account in exchange for original notes, where the original notes were acquired by the broker-dealer as a result of market-making activities or other trading activities, must acknowledge that it will deliver a prospectus in connection with any resale of the new notes. Please see “Plan of Distribution” for more details regarding the transfer of new notes.

DESCRIPTION OF NEW NOTES

You can find the definitions of certain terms used in this description under the subheading “—Certain Definitions.” In this description, the term “Company,” “us” or “we” refers only to Whiting Petroleum Corporation and not to any of its subsidiaries. The term “new notes” refers to the Company’s 5.750% Senior Notes due 2021 offered hereby, which will be part of, and form a single series with, the Company’s 5.750% Senior Notes due 2021 issued on September 12, 2013 (the “September 12 notes”, and together with the new notes, the “notes”).

The Company will issue the new notes under a senior indenture, dated as of September 12, 2013, among itself, the Guarantor and The Bank of New York Mellon Trust Company, N.A., as trustee, as supplemented by a second supplemental indenture, dated as of September 12, 2013, among itself, the Guarantor and The Bank of New York Mellon Trust Company, N.A, as trustee. We refer to the senior indenture, as so supplemented, as the “indenture.” The terms of the new notes include those stated in the indenture and those made part of the indenture by reference to the Trust Indenture Act of 1939.

The following description are summaries of the material provisions of the new notes and the indenture. These descriptions do not restate these documents in their entirety. We urge you to read the indenture because it, and not these descriptions, define your rights as holders of the new notes. A copy of the indenture is incorporated by reference into the registration statement of which this prospectus forms a part. See “Where You Can Find More Information.” Certain defined terms used in this description but not defined below under “—Certain Definitions” have the meanings assigned to them in the indenture.

The registered Holder of a new note will be treated as the owner of it for all purposes. Only registered Holders will have rights under the indenture.

Brief Description of the New Notes and the Subsidiary Guarantees

The New Notes. The new notes:

•

will be fully fungible with, and form a single series voting together as one class as, the $800.0 million aggregate principal amount of September 12 notes;

•

will be general unsecured obligations of the Company;

•

will rank equally in right of payment to our outstanding senior notes and any future senior indebtedness of the Company;

•

will rank senior in right of payment to our outstanding senior subordinated notes and any future subordinated indebtedness of the Company;

•

will effectively be subordinated to all secured indebtedness of the Company, including under the senior secured credit facility of our wholly-owned subsidiary, Whiting Oil and Gas Corporation (the “credit facility”), to the extent of the value of the collateral securing such indebtedness; and

•

will be unconditionally guaranteed by the Guarantor on a senior basis.

The Subsidiary Guarantees. Initially, the new notes will be guaranteed by the Company’s only Material Domestic Subsidiary, Whiting Oil and Gas Corporation.

Each guarantee of the new notes:

•

will be general unsecured obligations of the Guarantor;

•

will rank equally in right of payment to the Guarantor’s guarantee of our outstanding senior notes and any future senior indebtedness of the Guarantor;

•

will rank senior in right of payment to the Guarantor’s guarantee of our outstanding senior subordinated notes and any subordinated indebtedness of the Guarantor; and

•

will effectively be subordinated to all secured indebtedness of the Guarantor, including under the credit facility, to the extent of the value of the collateral securing such indebtedness.

As of September 30, 2013, the Company and the Guarantor had:

•

no secured debt (with availability to borrow under the credit facility of $1,197.0 million, subject to the terms thereof);

•

total senior debt of approximately $2,300.0 million, consisting of the original notes and senior notes issued in the offering that closed on September 12, 2013; and

•

$600.0 million of outstanding senior subordinated notes that are contractually subordinated to the new notes and the Subsidiary Guarantee. However, on October 31, 2013 we redeemed all $250.0 million aggregate principal amount of our 7.0% Senior Subordinated Notes due 2014.

Initially, not all of our existing subsidiaries will guarantee the new notes. Furthermore, under the circumstances described below under the subheading “—Certain Covenants—Additional Subsidiary Guarantees,” in the future one or more of our newly created or acquired subsidiaries may not guarantee the new notes. In the event of a bankruptcy, liquidation or reorganization of any of these non-Guarantor subsidiaries, the non-Guarantor subsidiaries will pay the holders of their debt and their trade creditors before they will be able to distribute any of their assets to us. The non-Guarantor subsidiaries have no outstanding Indebtedness (other than intercompany Indebtedness). They generated less than 0.1% of our consolidated revenues in the fiscal year ended December 31, 2012 and held less than 0.5% of our consolidated assets as of September 30, 2013.

As of the closing of this offering, all of our subsidiaries will be “Restricted Subsidiaries.” However, under the circumstances described below under the subheading “—Certain Covenants—Designation of Restricted and Unrestricted Subsidiaries,” we will be permitted to designate certain of our subsidiaries as “Unrestricted Subsidiaries.” Our Unrestricted Subsidiaries will not be subject to many of the restrictive covenants in the indenture. Our Unrestricted Subsidiaries will not guarantee the new notes.

Principal, Maturity and Interest

The Company will issue new notes in this offering with a maximum aggregate principal amount of $400,000,000. The Company may issue additional notes from time to time after this offering. Any offering of additional notes is subject to the covenant described below under the caption “—Certain Covenants—Incurrence of Indebtedness and Issuance of Preferred Stock.” The September 12 notes, the new notes and any additional notes subsequently issued under the indenture will be treated as a single class for all purposes under the indenture, including, without limitation, waivers, amendments, redemptions and offers to purchase. The Company will issue new notes in minimum denominations of $2,000 and any integral multiple of $1,000 in excess thereof.

The new notes will mature on March 15, 2021.

Interest on the new notes will accrue at the rate of 5.750% per annum. Interest on the new notes will be payable semi-annually in arrears on each March 15 and September 15, commencing on March 15, 2014. The Company will make each interest payment to the Holders of record on the March 1 and September 1 immediately preceding each interest payment date.

Interest on the new notes offered hereby will accrue from September 12, 2013 or, if interest has already been paid, from the date it was most recently paid. Interest will be computed on the basis of a 360-day year comprised of twelve 30-day months.

Methods of Receiving Payments on the New Notes

If a Holder has given wire transfer instructions to the trustee, the Company will pay all principal, interest and premium, if any, on that Holder’s new notes in accordance with those instructions. All other payments on new notes will be made at the office or agency of the paying agent and registrar within the City and State of New York unless the Company elects to make interest payments by check mailed to the Holders at their address set forth in the register of Holders.

Paying Agent and Registrar for the New Notes

The trustee will initially act as paying agent and registrar. The Company may change the paying agent or registrar without prior notice to the Holders of the new notes, and the Company or any of its Domestic Subsidiaries may act as paying agent.

Transfer and Exchange

A Holder may transfer or exchange new notes in accordance with the indenture. The Company or the trustee may require a Holder to furnish appropriate endorsements and transfer documents in connection with a transfer of new notes. No service charge will be imposed for any registration of transfer or exchange of new notes, but the Company may require Holders to pay all taxes due on transfer. The Company is not required to transfer or exchange any new note selected for redemption. Also, the Company is not required to transfer or exchange any new note for a period of 15 days before mailing a notice of redemption of the new notes.

Subsidiary Guarantees

Initially, our wholly-owned Subsidiary, Whiting Oil and Gas Corporation, will guarantee the new notes. In the future, the new notes will be guaranteed by each of the Company’s newly created or acquired Material Domestic Subsidiaries and by any other Restricted Subsidiary of the Company that guarantees any other Indebtedness of the Company in excess of $1.0 million. See “—Certain Covenants—Additional Subsidiary Guarantees.” These Subsidiary Guarantees will be joint and several obligations of the Guarantors. The obligations of each Guarantor under its Subsidiary Guarantee will be limited as necessary to prevent that Subsidiary Guarantee from constituting a fraudulent conveyance under applicable law. See “Risk Factors—Risks Relating to the Exchange Offer and New Notes—Any subsidiary guarantees of the new notes may be subordinated or avoided by a court.”

A Guarantor may not sell or otherwise dispose of all or substantially all of its properties or assets to, or consolidate with or merge with or into (whether or not such Guarantor is the surviving Person), another Person, other than the Company or another Guarantor, unless:

(1)

immediately after giving effect to such transaction, no Default or Event of Default exists; and

(2)

either:

(a)

the Person acquiring the properties or assets in any such sale or other disposition or the Person formed by or surviving any such consolidation or merger (if other than the Guarantor) unconditionally assumes all the obligations of that Guarantor, pursuant to a supplemental indenture substantially in the form specified in the indenture, under the new notes, the indenture and its Subsidiary Guarantee on terms set forth therein; or

(b)

the Net Proceeds of such sale or other disposition are applied in accordance with the “Asset Sale” provisions of the indenture.

The Subsidiary Guarantee of a Guarantor will be released:

(1)

in connection with any sale or other disposition of all or substantially all of the properties or assets of that Guarantor (including by way of merger or consolidation) to a Person that is not (either before or

after giving effect to such transaction) a Subsidiary of the Company, if the sale or other disposition complies with the “Asset Sale” provisions of the indenture; or

(2)

in connection with any sale or other disposition of all of the Capital Stock of that Guarantor to a Person that is not (either before or after giving effect to such transaction) a Subsidiary of the Company, if the sale or other disposition complies with the “Asset Sale” provisions of the indenture; or

(3)

if such Guarantor ceases to be a Material Domestic Subsidiary and is not a guarantor of Indebtedness of the Company in excess of $1.0 million; or

(4)

if the Company designates any Restricted Subsidiary that is a Guarantor as an Unrestricted Subsidiary in accordance with the applicable provisions of the indenture; or

(5)

upon Legal Defeasance or Covenant Defeasance as described below under the caption “—Legal Defeasance and Covenant Defeasance” or upon satisfaction and discharge of the indenture as described below under the caption “—Satisfaction and Discharge.”

See “—Repurchase at the Option of Holders—Asset Sales.”

Optional Redemption

On or after December 15, 2020, the Company may on any one or more occasions redeem all or part of the new notes upon not less than 30 nor more than 60 days’ prior notice at a redemption price equal to 100% of the principal amount thereof plus accrued and unpaid interest, if any, to the date of redemption (subject to the right of Holders of record on the relevant record date to receive interest due on an interest payment date that is on or prior to the redemption date).

Prior to December 15, 2020, the Company may on any one or more occasions redeem all or a part of the new notes upon not less than 30 nor more than 60 days’ prior notice at a redemption price equal to 100% of the principal amount thereof plus the Applicable Premium as of, and accrued and unpaid interest, if any, to, the date of redemption (subject to the right of Holders of record on the relevant record date to receive interest due on an interest payment date that is on or prior to the redemption date).

“Applicable Premium” means, with respect to a new note at any redemption date, the greater of (x) 1.0% of the principal amount of such new note or (y) the excess of (A) the present value at such redemption date of (1) the principal amount of such note plus (2) all required interest payments due on such new note through the final maturity date (without regard to accrued and unpaid interest), computed using a discount rate equal to the Treasury Rate plus 50 basis points, over (B) the principal amount of such new note.

“Treasury Rate” means the yield to maturity at the time of computation of United States Treasury securities with a constant maturity (as compiled and published in the most recent Federal Reserve Statistical Release H.15 (519) that has become publicly available at least two business days prior to the redemption date (or, if such Statistical Release is no longer published, any publicly available source or similar market data)) most nearly equal to the period from the redemption date to the final maturity date of the new notes being redeemed; provided, however, that if the period from the redemption date to such final maturity date is not equal to the constant maturity of a United States Treasury security for which a weekly average yield is given, the Treasury Rate shall be obtained by linear interpolation (calculated to the nearest one-twelfth of a year) from the weekly average yields of United States Treasury securities for which such yields are given, except that if the period from the redemption date to such final maturity is less than one year, the weekly average yield on actually traded United States Treasury securities adjusted to a constant maturity of one year shall be used.

Except as provided above or under “—Repurchase at the Option of Holders—Change of Control,” the new notes will not be redeemable at the Company’s option prior to their final maturity.

The Company may acquire new notes by means other than a redemption, whether by tender offer, open market purchases, negotiated transactions or otherwise, as long as such acquisition does not otherwise violate the terms of the indenture.

Selection and Notice

If less than all of the notes are to be redeemed at any time, the trustee will select notes for redemption as follows:

(1)

if the notes are listed on any national securities exchange, in compliance with the requirements of the principal national securities exchange on which the notes are listed; or

(2)

if the notes are not listed on any national securities exchange, on a pro rata basis.

No notes of $2,000 or less can be redeemed in part. Notices of redemption will be mailed by first class mail at least 30 but not more than 60 days before the redemption date to each Holder of notes to be redeemed at its registered address, except that redemption notices may be mailed more than 60 days prior to a redemption date if the notice is issued in connection with a defeasance of the notes or a satisfaction and discharge of the indenture. Notices of redemption may not be conditional.

If any note is to be redeemed in part only, the notice of redemption that relates to that note will state the portion of the principal amount of that note that is to be redeemed. A new note in principal amount equal to the unredeemed portion of the original note will be issued in the name of the Holder of notes upon cancellation of the original note. Notes called for redemption become due on the date fixed for redemption. On and after the redemption date, interest ceases to accrue on notes or portions of them called for redemption.

Mandatory Redemption

Except as set forth below under “—Repurchase at the Option of Holders,” the Company is not required to make mandatory redemption or sinking fund payments with respect to the new notes or to repurchase the new notes at the option of the Holders.

Repurchase at the Option of Holders

Change of Control

If a Change of Control occurs, each Holder of notes will have the right to require the Company to repurchase all or any part (equal to $2,000 or any integral multiple of $1,000 in excess thereof) of that Holder’s notes pursuant to a Change of Control Offer on the terms set forth in the indenture. In the Change of Control Offer, the Company will offer a Change of Control Payment in cash equal to 101% of the aggregate principal amount of notes repurchased plus accrued and unpaid interest, if any, on the notes repurchased, to the date of settlement (the “Change of Control Settlement Date”), subject to the right of Holders of record on the relevant record date to receive interest due on an interest payment date that is on or prior to the Change of Control Settlement Date. Within 30 days following any Change of Control, the Company will mail a notice to each Holder and the trustee describing the transaction or transactions that constitute the Change of Control and offering to repurchase notes as of the Change of Control Settlement Date specified in the notice, which date will be no earlier than 30 days and no later than 60 days from the date such notice is mailed (or, in the case of a notice mailed in advance of a Change of Control, no earlier than 30 days and no later than 60 days from the date of such Change of Control), pursuant to the procedures required by the indenture and described in such notice.

The Company will comply with the requirements of Rule 14e-1 under the Exchange Act and any other securities laws and regulations thereunder to the extent those laws and regulations are applicable in connection with the repurchase of the notes as a result of a Change of Control. To the extent that the provisions of any securities laws or regulations conflict with the Change of Control provisions of the indenture, the Company will comply with the applicable securities laws and regulations and will not be deemed to have breached its obligations under the Change of Control provisions of the indenture by virtue of such compliance.

On the Change of Control Settlement Date, the Company will, to the extent lawful, accept for payment all notes or portions of notes properly tendered pursuant to the Change of Control Offer. Promptly thereafter on the Change of Control Settlement Date the Company will:

(1) deposit with the paying agent an amount equal to the Change of Control Payment in respect of all notes or portions of notes properly tendered; and

(2) deliver or cause to be delivered to the trustee the notes properly accepted together with an officers’ certificate stating the aggregate principal amount of notes or portions of notes being purchased by the Company.

On the Change of Control Settlement Date, the paying agent will mail to each Holder of notes properly tendered the Change of Control Payment for such notes (or, if all the notes are then in global form, make such payment through the facilities of DTC), and the trustee will authenticate and mail (or cause to be transferred by book entry) to each Holder a separate note equal in principal amount to any unpurchased portion of the notes surrendered, if any; provided that each separate note will be in a principal amount of $2,000 or any integral multiple of $1,000 in excess thereof. The Company will publicly announce the results of the Change of Control Offer on or as soon as practicable after the Change of Control Settlement Date.

The provisions described above that require the Company to make a Change of Control Offer following a Change of Control will be applicable whether or not any other provisions of the indenture are applicable. Except as described above with respect to a Change of Control, the indenture does not contain provisions that permit the Holders of the notes to require that the Company repurchase or redeem the notes in the event of a takeover, recapitalization or similar transaction.

The Company will not be required to make a Change of Control Offer upon a Change of Control (1) if a third party makes the Change of Control Offer in the manner, at the time and otherwise in compliance with the requirements set forth in the indenture applicable to a Change of Control Offer made by the Company and purchases all notes properly tendered and not withdrawn under the Change of Control Offer or (2) notice of redemption has been given pursuant to the indenture as described above under the caption “—Optional Redemption”), unless and until there is a default in payment of the applicable redemption price. Notwithstanding anything to the contrary contained herein, a Change of Control Offer by the Company or a third party may be made in advance of a Change of Control, and conditioned upon the occurrence of a Change of Control, if a definitive agreement is in place for the Change of Control at the time the Change of Control Offer is made.

Notes purchased by the Company pursuant to a Change of Control Offer will have the status of notes issued but not outstanding or will be retired and cancelled, at the Company’s option. Notes purchased by a third party pursuant to the preceding paragraph will have the status of notes issued and outstanding.

The definition of Change of Control includes a phrase relating to the direct or indirect sale, lease, transfer, conveyance or other disposition of “all or substantially all” of the properties or assets of the Company and its Restricted Subsidiaries taken as a whole. The indenture is governed by New York law and although there is a limited body of case law interpreting the phrase “substantially all,” there is no precise established definition under New York law of “substantially all” the assets of a corporation. Accordingly, the ability of a Holder of notes to require the Company to repurchase its notes as a result of a sale, lease, transfer, conveyance or other disposition of less than all of the assets of the Company and its Subsidiaries taken as a whole to another Person or group may be uncertain. In the event that Holders of notes of not less than 90% of the aggregate principal amount of the outstanding notes accept a Change of Control Offer and the Company purchases all of the notes held by such holders, the Company will have the right to, upon not less than 30 nor more than 60 days’ prior notice, given not more than 30 days following the purchase pursuant to the Change of Control Offer described above, to redeem all of the notes that remain outstanding following such purchase at a purchase price equal to the Change of Control Payment plus, to the extent not included in the Change of Control Payment, accrued and unpaid interest on the notes that remain outstanding, if any, to the Change of Control Settlement Date, subject to

the right of Holders of record on the relevant record date to receive interest due on an interest payment date that is on or prior to the Change of Control Settlement Date.

The Credit Agreement limits the ability of the Company to purchase any notes, and also provides that certain change of control events with respect to the Company would constitute an event of default requiring, at the option of the lenders, repayment of the debt arising under the Credit Agreement. Any future credit agreements or other agreements relating to indebtedness to which the Company becomes a party may contain similar or additional restrictions and provisions. In the event a Change of Control occurs at a time when the Company is prohibited from purchasing notes, the Company could seek the consent of its senior lenders to the purchase of notes or could attempt to refinance the borrowings that contain such prohibition. If the Company does not obtain such a consent or repay such borrowings, the Company will remain prohibited from purchasing notes. In such case, the Company’s failure to purchase tendered notes would constitute an Event of Default under the indenture which would, in turn, constitute an event of default under such debt.

Asset Sales

The Company will not, and will not permit any of its Restricted Subsidiaries to, consummate an Asset Sale unless:

(1)

the Company (or the Restricted Subsidiary, as the case may be) receives consideration at the time of the Asset Sale at least equal to the fair market value of the assets or Equity Interests issued or sold or otherwise disposed of;

(2)

the fair market value is determined by the Company’s Board of Directors and evidenced by a resolution of the Board of Directors set forth in an officers’ certificate delivered to the trustee; and

(3)

at least 75% of the consideration received in the Asset Sale by the Company or such Restricted Subsidiary is in the form of cash or Cash Equivalents. For purposes of this clause (3) only, each of the following will be deemed to be Cash Equivalents:

(a)

any liabilities, as shown on the Company’s or such Restricted Subsidiary’s most recent balance sheet, of the Company or any Subsidiary (other than contingent liabilities and liabilities that are by their terms subordinated to the notes or any Subsidiary Guarantee) that are assumed by the transferee of any such assets pursuant to a novation agreement that releases the Company or such Subsidiary from further liability;

(b)

any securities, notes or other obligations received by the Company or any such Restricted Subsidiary from such transferee that are converted by the Company or such Subsidiary into cash within 180 days of the receipt thereof, to the extent of the cash received in that conversion; and

(c)

with respect to any Asset Sale of oil and natural gas properties where the Company or such Restricted Subsidiary retains an interest in such property, the aggregate costs and expenses of the Company or such Restricted Subsidiary related to the exploration, development, completion or production of such properties and activities related thereto which the transferee (or an Affiliate thereof) agrees to pay.

Within 360 days after the receipt of any Net Proceeds from an Asset Sale, the Company or any such Restricted Subsidiary may apply those Net Proceeds at its option to any combination of the following:

(1)

to prepay, repay, redeem or repurchase any Indebtedness of the Company or a Guarantor (other than intercompany Indebtedness, Capital Stock or Indebtedness that is subordinated to the notes or the Subsidiary Guarantees) or any Indebtedness of a Restricted Subsidiary that is not a Guarantor (other than intercompany Indebtedness);

(2)

to acquire all or substantially all of the properties or assets of one or more other Persons primarily engaged in the Oil and Gas Business, and, for this purpose, a division or line of business of a Person shall be treated as a separate Person;

(3)

to acquire a majority of the Voting Stock of one or more other Persons primarily engaged in the Oil and Gas Business;

(4)

to make one or more capital expenditures; or

(5)

to acquire other long-term assets that are used or useful in the Oil and Gas Business.

Pending the final application of any Net Proceeds, the Company or any such Restricted Subsidiary may temporarily reduce revolving credit borrowings or otherwise invest the Net Proceeds in any manner that is not prohibited by the indenture. Any Net Proceeds from Asset Sales that are not applied or invested as provided in the preceding paragraph will constitute “Excess Proceeds.”

On the 361st day after the Asset Sale (or, at the Company’s option, any earlier date), if the aggregate amount of Excess Proceeds then exceeds $50.0 million, the Company will make an Asset Sale Offer to all Holders of notes, and all holders of other Indebtedness that is pari passu with the notes containing provisions similar to those set forth in the indenture with respect to offers to purchase or redeem with the proceeds of sales of assets, to purchase the maximum principal amount of notes and such other pari passu Indebtedness that may be purchased out of the Excess Proceeds. The offer price in any Asset Sale Offer will be equal to 100% of the principal amount plus accrued and unpaid interest, if any, to the date of settlement, subject to the right of Holders of record on the relevant record date to receive interest due on an interest payment date that is on or prior to the date of settlement, and will be payable in cash. If any Excess Proceeds remain after consummation of an Asset Sale Offer, the Company may use those Excess Proceeds for any purpose not otherwise prohibited by the indenture. If the aggregate principal amount of notes and other pari passu Indebtedness tendered in such Asset Sale Offer exceeds the amount of Excess Proceeds, the trustee will select the notes and such other pari passu Indebtedness to be purchased on a pro rata basis (with such adjustments as may be deemed appropriate by the Company so that only notes in denominations of $2,000 or any integral multiple of $1,000 in excess thereof will be purchased). Upon completion of each Asset Sale Offer, the amount of Excess Proceeds will be reset at zero.

The Company will comply with the requirements of Rule 14e-1 under the Exchange Act and any other securities laws and regulations thereunder to the extent those laws and regulations are applicable in connection with each repurchase of notes pursuant to an Asset Sale Offer. To the extent that the provisions of any securities laws or regulations conflict with the Asset Sale provisions of the indenture, the Company will comply with the applicable securities laws and regulations and will not be deemed to have breached its obligations under the Asset Sale provisions of the indenture by virtue of such compliance.

Certain Covenants

Restricted Payments

The Company will not, and will not permit any of its Restricted Subsidiaries to, directly or indirectly:

(1)

declare or pay any dividend or make any other payment or distribution on account of the Company’s or any of its Restricted Subsidiaries’ Equity Interests (including, without limitation, any payment in connection with any merger or consolidation to which the Company or any of its Restricted Subsidiaries is a party) or to the direct or indirect holders of the Company’s or any of its Restricted Subsidiaries’ Equity Interests in their capacity as such (other than dividends or distributions payable in Equity Interests (other than Disqualified Stock) of the Company or payable to the Company or a Restricted Subsidiary of the Company);

(2)

purchase, redeem or otherwise acquire or retire for value (including, without limitation, in connection with any merger or consolidation to which the Company is a party) any Equity Interests of the Company or any direct or indirect parent of the Company;

(3)

make any principal payment on or with respect to, or purchase, redeem, defease or otherwise acquire or retire for value any Indebtedness that is subordinated to the notes or the Subsidiary Guarantees prior to

any scheduled repayment or scheduled maturity, except a payment, purchase, redemption, defeasance or other acquisition of any such Indebtedness in anticipation of satisfying a sinking fund obligation, principal installment or the Stated Maturity thereof, in each case, due within one year of the date of such payment, purchase, redemption, defeasance or other acquisition; or

(4)

make any Restricted Investment (all such payments and other actions set forth in these clauses (1) through (4) above being collectively referred to as “Restricted Payments”),

unless, at the time of and after giving effect to such Restricted Payment:

(1)

no Default or Event of Default has occurred and is continuing or would occur as a consequence of such Restricted Payment;

(2)

the Company would, at the time of such Restricted Payment and after giving pro forma effect thereto as if such Restricted Payment had been made at the beginning of the applicable four-quarter period, have been permitted to incur at least $1.00 of additional Indebtedness pursuant to the Fixed Charge Coverage Ratio test set forth in the first paragraph of the covenant described below under the caption “—Incurrence of Indebtedness and Issuance of Preferred Stock;” and

(3)

such Restricted Payment, together with the aggregate amount of all other Restricted Payments made by the Company and its Restricted Subsidiaries after May 11, 2004 (excluding Restricted Payments permitted by clauses (2), (3), (4), (6), (7) and (8) of the next succeeding paragraph), is less than the sum, without duplication, of:

(a)

50% of the Consolidated Net Income of the Company for the period (taken as one accounting period) from April 1, 2004 to the end of the Company’s most recently ended fiscal quarter for which internal financial statements are available at the time of such Restricted Payment (or, if such Consolidated Net Income for such period is a deficit, less 100% of such deficit), plus

(b)

100% of the aggregate net cash proceeds received by the Company (including the fair market value of any Additional Assets to the extent acquired in consideration of Equity Interests of the Company (other than Disqualified Stock)) since May 11, 2004 as a contribution to its common equity capital or from the issue or sale of Equity Interests of the Company (other than Disqualified Stock) or from the issue or sale of convertible or exchangeable Disqualified Stock or convertible or exchangeable debt securities of the Company that have been converted into or exchanged for such Equity Interests (other than Equity Interests (or Disqualified Stock or debt securities) sold to a Subsidiary of the Company), plus

(c)

to the extent that any Restricted Investment that was made after May 11, 2004 is sold for cash or otherwise liquidated or repaid for cash, the lesser of (i) the cash return of capital with respect to such Restricted Investment (less the cost of disposition, if any) and (ii) the initial amount of such Restricted Investment, plus

(d)

to the extent that any Unrestricted Subsidiary of the Company is redesignated as a Restricted Subsidiary after May 11, 2004, the lesser of (i) the fair market value of the Company’s Investment in such Subsidiary as of the date of such redesignation or (ii) such fair market value as of the date on which such Subsidiary was originally designated as an Unrestricted Subsidiary.

As of September 30, 2013, the amount available for Restricted Payments under the foregoing totaled approximately $2.5 billion.

The preceding provisions will not prohibit:

(1)

the payment of any dividend or distribution or the consummation of any irrevocable redemption of debt that is subordinate to the notes, within 60 days after the date of declaration of such dividend or the delivery of any irrevocable notice of redemption, as the case may be, if the dividend, distribution or

redemption payment on the date of declaration or the date of the notice of redemption, as the case may be, would have complied with the provisions of the indenture;

(2)

the redemption, repurchase, retirement, defeasance or other acquisition of any subordinated Indebtedness of the Company or any Guarantor or of any Equity Interests of the Company in exchange for, or out of the net cash proceeds of the substantially concurrent sale (other than to a Subsidiary of the Company) of, Equity Interests of the Company (other than Disqualified Stock), with a sale being deemed substantially concurrent if such redemption, repurchase, retirement, defeasance or acquisition occurs not more than 120 days after such sale; provided that the amount of any such net cash proceeds that are utilized for any such redemption, repurchase, retirement, defeasance or other acquisition will be excluded from clause (3)(b) of the preceding paragraph;

(3)

the defeasance, redemption, repurchase, retirement or other acquisition of subordinated Indebtedness of the Company or any Guarantor with the net cash proceeds from an incurrence of, or in exchange for, Permitted Refinancing Indebtedness;

(4)

the payment of any dividend or distribution by a Restricted Subsidiary of the Company to the holders of its Equity Interests on a pro rata basis;

(5)

the repurchase, redemption or other acquisition or retirement for value of any Equity Interests of the Company or any Restricted Subsidiary of the Company held by any current or former director, officer, employee or consultant of the Company or any of its Restricted Subsidiaries pursuant to any equity subscription agreement or plan, stock option agreement or similar agreement or plan; provided that the aggregate price paid for all such repurchased, redeemed, acquired or retired Equity Interests may not exceed $2.0 million in any twelve-month period;

(6)

the acquisition of Equity Interests by the Company in connection with the exercise of stock options or stock appreciation rights by way of cashless exercise;

(7)

the purchase, repurchase, redemption, defeasance or other acquisition or retirement for value of subordinated Indebtedness of the Company or any Restricted Subsidiary (a) at a purchase price not greater than 101.0% of the principal amount thereof (plus accrued and unpaid interest) in the event of a Change of Control in accordance with provisions similar to the covenant described under “—Repurchase at the Option of Holders—Change of Control” or (b) at a purchase price not greater than 100.0% of the principal amount thereof (plus accrued and unpaid interest) in accordance with provisions similar to the covenant described under “—Repurchase at the Option of Holders—Asset Sales”; provided that, prior to or simultaneously with such purchase, repurchase, redemption, defeasance or other acquisition or retirement, the Company has made the Change of Control Offer or Asset Sale Offer, as applicable, as provided in such covenants with respect to the notes and has completed the repurchase or redemption of all notes validly tendered for payment in connection with such Change of Control Offer or Asset Sale Offer;

(8)

the payment of cash in lieu of fractional shares of Capital Stock in connection with any transaction otherwise permitted under this covenant; or

(9)

other Restricted Payments in an aggregate amount since May 11, 2004 not to exceed $25.0 million;

provided, however, that at the time of, and after giving effect to, any Restricted Payment permitted under clause (9), no Default or Event of Default shall have occurred and be continuing or would be caused thereby.

The amount of all Restricted Payments (other than cash) will be the fair market value on the date of the Restricted Payment of the asset(s) or securities proposed to be transferred or issued by the Company or such Restricted Subsidiary, as the case may be, pursuant to the Restricted Payment. The fair market value of any assets or securities that are required to be valued by this covenant will be determined, in the case of amounts under $50.0 million, by an officer of the Company and, in the case of amounts of $50.0 million or more, by the Board of Directors of the Company, whose determination shall be evidenced by a Board Resolution. Not later

than the date of making any Restricted Payment (excluding any Restricted Payment described in the preceding clause (2), (3), (4), (6), (7) or (8)) the Company will deliver to the trustee an officers’ certificate stating that such Restricted Payment is permitted and setting forth the basis upon which the calculations required by this “Restricted Payments” covenant were computed. For purposes of determining compliance with this “Restricted Payments” covenant, in the event that a Restricted Payment meets the criteria of more than one of the categories of Restricted Payments described in the preceding clauses (1) through (9), or is entitled to be made pursuant to the first paragraph of this covenant, the Company will be permitted to divide or classify (or later divide, classify or reclassify in whole or in part in its sole discretion) such Restricted Payment in any manner that complies with this covenant.

Incurrence of Indebtedness and Issuance of Preferred Stock

The Company will not, and will not permit any of its Restricted Subsidiaries to, directly or indirectly, create, incur, issue, assume, guarantee or otherwise become directly or indirectly liable, contingently or otherwise, with respect to (collectively, “incur”) any Indebtedness (including Acquired Debt), neither the Company nor any Guarantor will issue any Disqualified Stock, and the Company will not permit any of its other Restricted Subsidiaries to issue any shares of preferred stock; provided, however, that the Company and any Guarantor may incur Indebtedness (including Acquired Debt) or issue Disqualified Stock, if the Fixed Charge Coverage Ratio for the Company’s most recently ended four full fiscal quarters for which internal financial statements are available immediately preceding the date on which such additional Indebtedness is incurred or such Disqualified Stock is issued would have been at least 2.0 to 1.0, determined on a pro forma basis (including a pro forma application of the net proceeds therefrom), as if the additional Indebtedness had been incurred or Disqualified Stock had been issued, as the case may be, at the beginning of such four-quarter period.

The first paragraph of this covenant will not prohibit the incurrence of any of the following items of Indebtedness (collectively, “Permitted Debt”):

(1)

the incurrence by the Company or any of its Restricted Subsidiaries of additional Indebtedness (including letters of credit) under one or more Credit Facilities in an aggregate principal amount at any one time outstanding under this clause (1) (with letters of credit being deemed to have a principal amount equal to the maximum potential liability of the Company and its Subsidiaries thereunder) not to exceed an amount equal to the greater of (a) $1.25 billion or (b) 30% of ACNTA as of the date of such incurrence;

(2)

the incurrence by the Company or any of its Restricted Subsidiaries of the Existing Indebtedness;

(3)

the incurrence by the Company and the Guarantors of Indebtedness represented by the September 12 notes and the related Subsidiary Guarantees;

(4)

the incurrence by the Company or any of its Restricted Subsidiaries of Indebtedness represented by Capital Lease Obligations, mortgage financings or purchase money obligations, in each case, incurred for the purpose of financing all or any part of the purchase price or cost of design, construction, installation or improvement of property, plant or equipment used in the business of the Company or such Restricted Subsidiary, in an aggregate principal amount at any time outstanding, including all Permitted Refinancing Indebtedness incurred to renew, refund, refinance or replace, defease or discharge any Indebtedness incurred pursuant to this clause (4), not to exceed the greater of (a) $75.0 million or (b) 1.0% of ACNTA as of the date of such incurrence at any time outstanding;

(5)

the incurrence by the Company or any of its Restricted Subsidiaries of Permitted Refinancing Indebtedness in exchange for, or the net proceeds of which are used to refund, refinance or replace Indebtedness (other than intercompany Indebtedness) that was permitted by the indenture to be incurred under the first paragraph of this covenant or clause (2) or (3) of this paragraph or this clause (5);

(6)

the incurrence by the Company or any of its Restricted Subsidiaries of intercompany Indebtedness between or among the Company and any of its Restricted Subsidiaries; provided, however, that:

(a)

if the Company is the obligor on such Indebtedness and a Guarantor is not the obligee, such Indebtedness must be expressly subordinated to the prior payment in full in cash of all Obligations with respect to the notes, or if a Guarantor is the obligor on such Indebtedness and neither the Company nor another Guarantor is the obligee, such Indebtedness must be expressly subordinated to the prior payment in full in cash of all Obligations with respect to the Subsidiary Guarantee of such Guarantor; and

(b)

(i) any subsequent issuance or transfer of Equity Interests that results in any such Indebtedness being held by a Person other than the Company or a Restricted Subsidiary of the Company and (ii) any sale or other transfer of any such Indebtedness to a Person that is neither the Company nor a Restricted Subsidiary of the Company will be deemed, in each case, to constitute an incurrence of such Indebtedness by the Company or such Restricted Subsidiary, as the case may be, that was not permitted by this clause (6);

(7)

the incurrence by the Company or any of its Restricted Subsidiaries of Hedging Obligations;

(8)

the guarantee by the Company or any of the Guarantors of Indebtedness of the Company or any Guarantor that was permitted to be incurred by another provision of this covenant;

(9)

the incurrence by the Company or any of its Restricted Subsidiaries of obligations relating to net gas balancing positions arising in the ordinary course of business and consistent with past practice;

(10)

the incurrence by the Company’s Unrestricted Subsidiaries of Non-Recourse Debt; provided, however, that if any such Indebtedness ceases to be Non-Recourse Debt of an Unrestricted Subsidiary, such event will be deemed to constitute an incurrence of Indebtedness by a Restricted Subsidiary of the Company that was not permitted by this clause (10);

(11)

the incurrence by the Company or any of its Restricted Subsidiaries of Indebtedness in respect of bid, performance, surety and similar bonds issued for the account of the Company and any of its Restricted Subsidiaries in the ordinary course of business, including guarantees and obligations of the Company and any of its Restricted Subsidiaries with respect to letters of credit supporting such obligations (in each case other than an obligation for money borrowed);

(12)

the incurrence by the Company or any of its Restricted Subsidiaries of Indebtedness arising from agreements of the Company or any of its Restricted Subsidiaries providing for indemnification, adjustment of purchase price or similar obligations, in each case, incurred or assumed in connection with the disposition of any business, assets or Capital Stock of a Subsidiary, provided that the maximum aggregate liability in respect of all such Indebtedness shall at no time exceed the gross proceeds actually received by the Company and its Restricted Subsidiaries in connection with such disposition;

(13)

Indebtedness arising from the honoring by a bank or other financial institution of a check, draft or similar instrument inadvertently (except in the case of daylight overdrafts) drawn against insufficient funds in the ordinary course of business; provided, however, that such Indebtedness is promptly extinguished;

(14)

Indebtedness arising in connection with endorsement of instruments for deposit in the ordinary course of business;

(15)

Indebtedness owed on a short-term basis to banks and other financial institutions incurred in the ordinary course of business of the Company and any Restricted Subsidiary with such banks or financial institutions that arises in connection with ordinary banking arrangements to manage cash balances of the Company and any Restricted Subsidiary;

(16)

the incurrence by the Company or any of its Restricted Subsidiaries of Acquired Debt in connection with a transaction meeting either one of the financial tests set forth in clause (4) under “—Merger, Consolidation or Sale of Asset Sales;” and

(17)

the incurrence by the Company or any of its Restricted Subsidiaries of additional Indebtedness in an aggregate principal amount (or accreted value, as applicable) at any time outstanding, not to exceed the greater of (a) $250.0 million or (b) 2.5% of ACNTA as of the date of incurrence.

For purposes of determining compliance with this “Incurrence of Indebtedness and Issuance of Preferred Stock” covenant, in the event that an item of Indebtedness (including Acquired Debt) meets the criteria of more than one of the categories of Permitted Debt described in clauses (1) through (17) above, or is entitled to be incurred pursuant to the first paragraph of this covenant, the Company will be permitted to divide and classify (or later divide, classify, reclassify or re-divide in whole or in part in its sole discretion) such item of Indebtedness in any manner that complies with this covenant, except that any indebtedness under Credit Facilities on the Issue Date (after giving effect to this offering and the use of proceeds thereof) shall be considered incurred under the first paragraph of this covenant.

The accrual of interest, the accretion or amortization of original issue discount, the payment of interest on any Indebtedness in the form of additional Indebtedness with the same terms, and the payment of dividends on Disqualified Stock in the form of additional shares of the same class of Disqualified Stock will not be deemed to be an incurrence of Indebtedness or an issuance of Disqualified Stock for purposes of this covenant; provided, in each such case, that the amount thereof is included in Fixed Charges of the Company as accrued. Notwithstanding any other provision of this covenant, the maximum amount of Indebtedness that the Company or any Restricted Subsidiary may incur pursuant to this covenant shall not be deemed exceeded solely as a result of fluctuations in exchange rates or currency values.

Liens

The Company will not and will not permit any of its Restricted Subsidiaries to, create, incur, assume or otherwise cause or suffer to exist or become effective any Lien of any kind (other than Permitted Liens) securing Indebtedness or Attributable Debt upon any of their property or assets, now owned or hereafter acquired, unless the notes or any Subsidiary Guarantee of such Restricted Subsidiary, as applicable, is secured on an equal and ratable basis (or on a senior basis to, in the case of obligations subordinated in right of payment to the notes or such Subsidiary Guarantee, as the case may be) with the obligations so secured until such time as such obligations are no longer secured by a Lien.

Dividend and Other Payment Restrictions Affecting Subsidiaries

The Company will not, and will not permit any of its Restricted Subsidiaries to, directly or indirectly, create or permit to exist or become effective any consensual encumbrance or restriction on the ability of any Restricted Subsidiary to:

(1)

pay dividends or make any other distributions on its Capital Stock to the Company or any of its Restricted Subsidiaries, or pay any Indebtedness or other obligations owed to the Company or any of its Restricted Subsidiaries;

(2)

make loans or advances to the Company or any of its Restricted Subsidiaries; or

(3)

transfer any of its properties or assets to the Company or any of its Restricted Subsidiaries.

However, the preceding restrictions will not apply to encumbrances or restrictions existing under or by reason of:

(1)

agreements governing Existing Indebtedness and Credit Facilities as in effect on the Issue Date and any amendments, modifications, restatements, renewals, increases, supplements, refundings, replacements or refinancings of those agreements, provided that the amendments, modifications, restatements, renewals, increases, supplements, refundings, replacements or refinancings are not materially more

restrictive, taken as a whole, with respect to such encumbrances and restrictions than those contained in those agreements on the Issue Date as determined in good faith by the Company;

(2)

the indenture, the notes and the Subsidiary Guarantees;

(3)

applicable law, rule, regulation, order, approval, license, permit or similar restriction;

(4)

any instrument governing Indebtedness or Capital Stock of a Person acquired by the Company or any of its Restricted Subsidiaries as in effect at the time of such acquisition, which encumbrance or restriction is not applicable to any Person, or the properties or assets of any Person, other than the Person, or the property or assets of the Person, so acquired, provided that, in the case of Indebtedness, such Indebtedness was permitted by the terms of the indenture to be incurred, and any amendments, restatements, modifications, renewals, supplements, refundings, replacements or refinancings of those agreements; provided that the amendments, restatements, modifications, renewals, supplements, refundings, replacements or refinancings are not materially more restrictive, taken as a whole, with respect to such encumbrances and restrictions than those contained in those agreements on the date of such acquisition as determined in good faith by the Company;

(5)

customary non-assignment provisions in leases entered into in the ordinary course of business and consistent with past practices;

(6)

Capital Lease Obligations or purchase money obligations, in each case for property acquired in the ordinary course of business that impose restrictions on that property of the nature described in clause (3) of the preceding paragraph;

(7)

any agreement for the sale or other disposition of a Restricted Subsidiary of the Company that restricts distributions and/or transfers of properties and assets by that Restricted Subsidiary pending its sale or other disposition;

(8)

Permitted Refinancing Indebtedness, provided that the restrictions contained in the agreements governing such Permitted Refinancing Indebtedness are not materially more restrictive, taken as a whole, than those contained in the agreements governing the Indebtedness being refinanced as determined in good faith by the Company;

(9)

Liens securing Indebtedness otherwise permitted to be incurred under the provisions of the covenant described above under the caption “—Liens” that limit the right of the debtor to dispose of the assets subject to such Liens;

(10)

provisions with respect to the disposition or distribution of assets or property in joint venture agreements, asset sale agreements, stock sale agreements, agreements respecting Permitted Business Investments and other similar agreements entered into (a) in the ordinary course of business or (b) with the Company’s approval by its Board of Directors, which limitation is applicable only to property or capital stock that are subject to such agreements;

(11)

restrictions on cash, Cash Equivalents or other deposits or net worth imposed by customers or suppliers under contracts entered into in the ordinary course of business;

(12)

restrictions on the sale, lease or transfer of property or assets arising or agreed to in the ordinary course of business, not relating to any Indebtedness, and that do not, individually or in the aggregate, detract from the value of property or assets of the Company or any Restricted Subsidiary in any manner material to the Company and the Restricted Subsidiaries taken as a whole; and

(13)

Hedging Obligations permitted to be incurred under the covenant described under the caption “—Certain Covenants—Incurrence of Indebtedness and Issuance of Preferred Stock.”

Merger, Consolidation or Sale of Assets

The Company may not, directly or indirectly: (1) consolidate or merge with or into another Person (whether or not the Company is the surviving entity); or (2) sell, assign, transfer, lease, convey or otherwise dispose of all

or substantially all of the properties or assets of the Company and its Restricted Subsidiaries taken as a whole, in one or more related transactions, to another Person, unless:

(1)

either: (a) the Company is the surviving corporation; or (b) the Person formed by or surviving any such consolidation or merger (if other than the Company) or to which such sale, assignment, transfer, lease, conveyance or other disposition has been made is an entity organized or existing under the laws of the United States, any state of the United States or the District of Columbia; provided that if the Company or such other Person is not a corporation, a Restricted Subsidiary of the Company that is a corporation shall assume by supplemental indenture all obligations of the Company under the notes and the indenture as a co-issuer of the notes;

(2)

the Person formed by or surviving any such consolidation or merger (if other than the Company) or the Person to which such sale, assignment, transfer, lease, conveyance or other disposition has been made assumes all the obligations of the Company under the notes and the indenture pursuant to agreements reasonably satisfactory to the trustee;

(3)

immediately after such transaction no Default or Event of Default exists;

(4)

the Company or the Person formed by or surviving any such consolidation or merger (if other than the Company), or to which such sale, assignment, transfer, lease, conveyance or other disposition has been made will, on the date of such transaction after giving pro forma effect thereto and any related financing transactions as if the same had occurred at the beginning of the applicable four-quarter period, either (a) be permitted to incur at least $1.00 of additional Indebtedness pursuant to the Fixed Charge Coverage Ratio test set forth in the first paragraph of the covenant described above under the caption “—Incurrence of Indebtedness and Issuance of Preferred Stock” or (b) have a Fixed Charge Coverage Ratio that is equal to or greater than the Fixed Charge Coverage Ratio of the Company immediately prior to such consolidation, merger, sale, assignment, transfer, lease, conveyance or other disposition; and

(5)

the Company shall have delivered to the trustee an officers’ certificate and an opinion of counsel, each stating that such consolidation, merger or disposition and such supplemental indenture (if any) comply with the indenture.

This “Merger, Consolidation or Sale of Assets” covenant will not apply to any sale, assignment, transfer, lease, conveyance or other disposition of assets between or among the Company and its Restricted Subsidiaries. Clauses (3) and (4) of the first paragraph of this covenant will not apply to any merger or consolidation of the Company (a) with or into one of its Restricted Subsidiaries for any purpose or (b) with or into an Affiliate solely for the purpose of reincorporation of the Company in another jurisdiction.

Although there is a limited body of case law interpreting the phrase “substantially all,” there is no precise established definition of the phrase under applicable law. Accordingly, in certain circumstances there may be a degree of uncertainty as to whether a particular transaction would involve “all or substantially all” of the properties or assets of a Person.

Transactions with Affiliates

The Company will not, and will not permit any of its Restricted Subsidiaries to, make any payment to, or sell, lease, transfer or otherwise dispose of any of its properties or assets to, or purchase any property or assets from, or enter into or make or amend any transaction, contract, agreement, understanding, loan, advance or guarantee with, or for the benefit of, any Affiliate (each, an “Affiliate Transaction”) involving aggregate consideration in excess of $1.0 million, unless:

(1)

the Affiliate Transaction is on terms that are not materially less favorable to the Company or the relevant Restricted Subsidiary than those that would have been obtained in a comparable transaction by the Company or such Restricted Subsidiary with an unrelated Person or, if in the good faith judgment

of the Company’s Board of Directors, no comparable transaction is available with which to compare such Affiliate Transaction, such Affiliate Transaction is otherwise fair to the Company or the relevant Restricted Subsidiary from a financial point of view; and

(2)

the Company delivers to the trustee:

(a)

with respect to any Affiliate Transaction or series of related Affiliate Transactions involving aggregate consideration in excess of $20.0 million, an officers’ certificate certifying that such Affiliate Transaction complies with this covenant; and

(b)

with respect to any Affiliate Transaction or series of related Affiliate Transactions involving aggregate consideration in excess of $50.0 million, an officer’s certificate certifying that such Affiliate Transaction has been approved by a majority of the disinterested members of the Board of Directors.

The following items will not be deemed to be Affiliate Transactions and, therefore, will not be subject to the provisions of the prior paragraph:

(1)

any employment, severance or consulting agreement or other compensation agreement, arrangement or plan, or any amendment thereto, entered into by the Company or any of its Restricted Subsidiaries in the ordinary course of business;

(2)

transactions between or among any of the Company and its Restricted Subsidiaries;

(3)

transactions with a Person that is an Affiliate of the Company solely because the Company owns an Equity Interest in such Person;

(4)

payment of reasonable directors’ fees, consulting fees and other benefits to persons who are not otherwise Affiliates of the Company;

(5)

provision of officers’ and directors’ indemnification and insurance in the ordinary course of business to the extent permitted by law;

(6)

sales of Equity Interests (other than Disqualified Stock) to Affiliates of the Company;

(7)

Permitted Investments and Restricted Payments that are permitted by the provisions of the indenture described above under the caption “—Restricted Payments;”

(8)

any transaction in which the Company or its Restricted Subsidiaries, as the case may be, deliver to the trustee a letter from an accounting, appraisal or investment banking firm of national standing stating that such transaction is fair to the Company or its Restricted Subsidiary from a financial point of view or that such transaction meets the requirements of clause (1) of the initial paragraph above;

(9)

transactions with Unrestricted Subsidiaries, Affiliates, customers, clients, suppliers or purchasers or sellers of goods or services, or lessors or lessees of property, in each case in the ordinary course of business and otherwise in compliance with the terms of the indenture which are, in the aggregate (taking into account all the costs and benefits associated with such transactions) materially no less favorable to the Company or its Restricted Subsidiaries than those that would have been obtained in a comparable transaction by the Company or such Restricted Subsidiary with an unrelated person, in the good faith determination of the Company’s Board of Directors, or are on terms at least as favorable as might reasonably have been obtained at such time from an unaffiliated party; and

(10)

transactions between the Company or any of its Restricted Subsidiaries and any Person, a director of which is also a director of the Company or any direct or indirect parent of the Company; provided, however, that such director abstains from voting as a director of the Company or such direct or indirect parent, as the case may be, on any matter involving such other Person.

Designation of Restricted and Unrestricted Subsidiaries

The Board of Directors of the Company may designate any Restricted Subsidiary of the Company to be an Unrestricted Subsidiary if that designation would not cause a Default. If a Restricted Subsidiary of the Company is designated as an Unrestricted Subsidiary, the aggregate fair market value of all outstanding Investments owned by the Company and its Restricted Subsidiaries in the Subsidiary properly designated will be deemed to be an Investment made as of the time of the designation and will reduce the amount available for Restricted Payments under the first paragraph of the covenant described above under the caption “—Restricted Payments” or represent Permitted Investments, as determined by the Company. That designation will only be permitted if the Investment would be permitted at that time and if the Subsidiary so designated otherwise meets the definition of an Unrestricted Subsidiary.

The Board of Directors of the Company may at any time designate any Unrestricted Subsidiary to be a Restricted Subsidiary of the Company; provided that such designation will be deemed to be an incurrence of Indebtedness by a Restricted Subsidiary of the Company of any outstanding Indebtedness of such Unrestricted Subsidiary and such designation will only be permitted if (1) such Indebtedness is permitted under the covenant described above under the caption “—Incurrence of Indebtedness and Issuance of Preferred Stock,” calculated on a pro forma basis as if such designation had occurred at the beginning of the four-quarter reference period, and (2) no Default or Event of Default would be in existence following such designation.

Additional Subsidiary Guarantees

If the Company or any of its Restricted Subsidiaries acquires or creates another Material Domestic Subsidiary after the Issue Date, or if any Restricted Subsidiary that is not already a Guarantor guarantees any other Indebtedness of the Company in a principal amount in excess of $1.0 million after such date, then in either case that Subsidiary will become a Guarantor by executing a supplemental indenture and delivering it to the trustee within 20 Business Days of the date on which it was acquired or created or guaranteed such Indebtedness of the Company, as the case may be; provided, however, that (a) the foregoing shall not apply to Subsidiaries of the Company that have properly been designated as Unrestricted Subsidiaries in accordance with the indenture for so long as they continue to constitute Unrestricted Subsidiaries, and (b) Whiting Programs, Inc. shall not be required to become a Guarantor unless it guarantees Indebtedness of the Company in a principal amount in excess of $1.0 million.

Reports

Whether or not required by the Commission, so long as any notes are outstanding, the Company will file with the Commission for public availability within the time period specified in the Commission’s rules and regulations (unless the Commission will not accept such a filing), and the Company will furnish to the trustee and, upon its request, to any of the Holders of notes, within 10 Business Days of filing, or attempting to file, the same with the Commission:

(1)

all quarterly and annual financial and other information with respect to the Company and its Subsidiaries that would be required to be contained in a filing with the Commission on Forms 10-Q and 10-K if the Company were required to file such Forms, including a “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and, with respect to the annual information only, a report on the annual financial statements by the Company’s certified independent accountants; and

(2)

all current reports that would be required to be filed with the Commission on Form 8-K if the Company were required to file such reports.

The Company’s filing of any such information, document or report with the Commission pursuant to its Electronic Data Gathering, Analysis and Retrieval (or EDGAR) system or any successor thereto shall satisfy the reporting obligations described above.

If the Company has designated any of its Subsidiaries as Unrestricted Subsidiaries, then the quarterly and annual financial information required by the preceding paragraph will include a reasonably detailed presentation, either on the face of the financial statements or in the footnotes thereto, and in Management’s Discussion and Analysis of Financial Condition and Results of Operations, of the financial condition and results of operations of the Company and its Restricted Subsidiaries separate from the financial condition and results of operations of the Unrestricted Subsidiaries of the Company.

Covenant Termination

If at any time (a) the rating assigned to the notes by both S&P and Moody’s is an Investment Grade Rating and (b) no Default has occurred and is continuing under the indenture, then upon delivery by the Company to the trustee of an officers’ certificate to the foregoing effect, the Company and its Restricted Subsidiaries will no longer be subject to the provisions of the indenture described above under the caption “—Repurchase at the Option of Holders—Asset Sales” and the following provisions of the indenture described above under the caption “—Certain Covenants”:

•

“Restricted Payments,”

•

“Incurrence of Indebtedness and Issuance of Preferred Stock,”

•

“Dividend and Other Payment Restrictions Affecting Subsidiaries,”

•

Clause (4) of the second paragraph of “Merger, Consolidation or Sale of Assets,” and

•

“Transactions with Affiliates.”

However, the Company and its Restricted Subsidiaries will remain subject to the provisions of the indenture described above under the caption “Repurchase at the Option of Holders—Change of Control,” and the following provisions of the indenture described above under the caption “—Covenants”:

•

“Liens,”

•

“Merger, Consolidation or Sale of Assets” (other than clause (4) of such covenant),

•

“Designation of Restricted and Unrestricted Subsidiaries,”

•

Additional Subsidiary Guarantees,” and

•

“Reports.”

Events of Default and Remedies

Each of the following is an Event of Default with respect to the notes:

(1)

default for 30 days in the payment when due of interest on the notes;

(2)

default in payment when due of the principal of, or premium, if any, on the notes, whether upon maturity, redemption or otherwise;

(3)

failure by the Company to comply with the provisions described under the captions “—Certain Covenants—Restricted Payments,” “—Certain Covenants—Incurrence of Indebtedness and Issuance of Preferred Stock” or “—Certain Covenants—Merger, Consolidation or Sale of Assets;”

(4)

failure by the Company to comply with the provisions described under the captions “—Repurchase at the Option of Holders—Asset Sales” or “—Repurchase at the Option of Holders—Change of Control” with respect to the notes;

(5)

failure by the Company for 60 days (or 180 days in the case of a Reporting Failure) after notice by the trustee or Holders of 25% of the outstanding principal amount of the notes to comply with any of the other agreements in the indenture;

(6)

default under any mortgage, indenture or instrument under which there may be issued or by which there may be secured or evidenced any Indebtedness for money borrowed by the Company or any of its Restricted Subsidiaries (or the payment of which is guaranteed by the Company or any of its Restricted Subsidiaries), whether such Indebtedness or guarantee now exists, or is created after the Issue Date, if that default:

(a)

is caused by a failure to pay principal of, or interest or premium, if any, on such Indebtedness prior to the expiration of the grace period provided in such Indebtedness (a “Payment Default”); or

(b)

results in the acceleration of such Indebtedness prior to its Stated Maturity,

and, in each case, the principal amount of any such Indebtedness, together with the principal amount of any other such Indebtedness under which there has been a Payment Default or the maturity of which has been so accelerated, aggregates $50.0 million or more; provided, that if any such default is cured or waived or any such acceleration is rescinded, or such Indebtedness is repaid, within a period of 10 days from the continuation of such default beyond the applicable grace period or the occurrence of such acceleration, as the case may be, such Event of Default under the indenture and any consequential acceleration of the notes shall be automatically rescinded;

(7)

failure by the Company or any of its Significant Subsidiaries to pay final judgments aggregating in excess of $50.0 million, which judgments are not paid, discharged or stayed (including a stay pending appeal) for a period of 60 days after the date of such final judgment (or, if later, the date when payment is due pursuant to such judgment);

(8)

except as permitted by the indenture, any Subsidiary Guarantee shall be held in any judicial proceeding to be unenforceable or invalid or shall cease for any reason to be in full force and effect or any Guarantor, or any Person acting on behalf of any Guarantor, shall deny or disaffirm its obligations under its Subsidiary Guarantee (other than by reason of release of a Guarantor from its Subsidiary Guarantee in accordance with the terms of the indenture); and

(9)

certain events of bankruptcy, insolvency or reorganization described in the indenture with respect to the Company or any of its Significant Subsidiaries or any group of Subsidiaries of the Company that, taken as a whole, would constitute a Significant Subsidiary.

In the case of an Event of Default arising from certain events of bankruptcy, insolvency or reorganization, with respect to the Company, any Subsidiary of the Company that is a Significant Subsidiary or any group of Subsidiaries of the Company that, taken together, would constitute a Significant Subsidiary, all outstanding notes will become due and payable immediately without further action or notice. If any other Event of Default occurs and is continuing, the trustee or the Holders of at least 25% in aggregate principal amount of the then outstanding notes may declare all the notes to be due and payable immediately. An Event of Default for the notes will not necessarily constitute an Event of Default for any other series of debt securities that may be issued under the indenture in the future and vice versa.

Holders of the notes may not enforce the indenture or the notes except as provided in the indenture. Subject to certain limitations, Holders of a majority in principal amount of the then outstanding notes may direct the trustee in its exercise of any trust or power. The trustee may withhold from Holders notice of any continuing Default or Event of Default with respect to the notes if it determines that withholding notice is in their interest, except a Default or Event of Default relating to the payment of principal of, or interest or premium, if any, on, the notes.

The Holders of a majority in principal amount of the notes then outstanding by notice to the trustee may on behalf of the Holders of all of the notes waive any past Default or Event of Default with respect to such notes and its consequences under the indenture except a continuing Default or Event of Default in the payment of principal of, or interest or premium, if any, on such notes or in respect of a covenant that cannot be amended without the consent of each Holder of such notes.

The Company is required to deliver to the trustee annually a statement regarding compliance with the indenture. Upon becoming aware of any Default or Event of Default with respect to the notes, the Company is required to deliver to the trustee a statement specifying such Default or Event of Default.

No Personal Liability of Directors, Officers, Employees and Stockholders

No director, officer, employee, incorporator or stockholder or other owner of Capital Stock of the Company or any Guarantor, as such, will have any liability for any obligations of the Company or any Guarantor under the notes, the indenture or the Subsidiary Guarantees, or for any claim based on, in respect of, or by reason of, such obligations or their creation. Each Holder of notes by accepting a note waives and releases all such liability. The waiver and release are part of the consideration for issuance of the notes. The waiver may not be effective to waive liabilities under the federal securities laws.

Legal Defeasance and Covenant Defeasance

The Company may, at its option and at any time, elect to have all of its obligations discharged with respect to the outstanding notes and all obligations of the Guarantors discharged with respect to their Subsidiary Guarantees of such notes (“Legal Defeasance”) except for:

(1)

the rights of Holders of outstanding notes to receive payments in respect of the principal of, and interest or premium, if any, on such notes when such payments are due from the trust referred to below;

(2)

the Company’s obligations with respect to the notes concerning issuing temporary notes, registration of notes, mutilated, destroyed, lost or stolen notes and the maintenance of an office or agency for payment and money for security payments held in trust;

(3)

the rights, powers, trusts, duties and immunities of the trustee, and the Company’s obligations in connection therewith; and

(4)

the Legal Defeasance provisions of the indenture.

In addition, the Company may, at its option and at any time, elect to have its obligations released with respect to certain covenants (including the obligation to make a Change of Control Offer and Asset Sale Offer) that are described in the indenture (“Covenant Defeasance”) and thereafter any omission to comply with those covenants will not constitute a Default or Event of Default with respect to the notes. In the event Covenant Defeasance occurs, certain events (not including non-payment, bankruptcy, insolvency or reorganization events) described under “—Events of Default and Remedies” will no longer constitute an Event of Default with respect to the notes. If the Company exercises either its Legal Defeasance or Covenant Defeasance option, each Guarantor will be released and relieved of any obligations under its Subsidiary Guarantee with respect to the notes and any security for such notes (other than the trust) will be released.

In order to exercise either Legal Defeasance or Covenant Defeasance:

(1)

the Company must irrevocably deposit with the trustee, in trust, for the benefit of the Holders of such notes, cash in U.S. dollars, non-callable Government Securities, or a combination of cash in U.S. dollars and non-callable Government Securities, in amounts as will be sufficient, in the opinion of a nationally recognized investment bank, appraisal firm or firm of independent public accountants, to pay the principal of, and interest and premium, if any, on the outstanding notes on the date of fixed maturity or on the applicable redemption date, as the case may be, and the Company must specify whether such notes are being defeased to the date of fixed maturity or to a particular redemption date;

(2)

in the case of Legal Defeasance, the Company has delivered to the trustee an opinion of counsel reasonably acceptable to the trustee confirming that:

(a)

the Company has received from, or there has been published by, the Internal Revenue Service a ruling; or

(b)

since the Issue Date, there has been a change in the applicable federal income tax law,

in either case to the effect that, and based thereon such opinion of counsel will confirm that, the Holders of the outstanding notes will not recognize income, gain or loss for federal income tax purposes as a result of such Legal Defeasance and will be subject to federal income tax on the same amounts, in the same manner and at the same times as would have been the case if such Legal Defeasance had not occurred;

(3)

in the case of Covenant Defeasance, the Company has delivered to the trustee an opinion of counsel reasonably acceptable to the trustee confirming that the Holders of the outstanding notes will not recognize income, gain or loss for federal income tax purposes as a result of such Covenant Defeasance and will be subject to federal income tax on the same amounts, in the same manner and at the same times as would have been the case if such Covenant Defeasance had not occurred;

(4)

no Default or Event of Default has occurred and is continuing on the date of such deposit (other than a Default or Event of Default resulting from the borrowing of funds to be applied to such deposit and any similar concurrent deposit relating to other Indebtedness, and the granting of Liens to secure such borrowing);

(5)

such Legal Defeasance or Covenant Defeasance will not result in a breach or violation of, or constitute a default under, any material agreement or instrument (other than the indenture and the agreements governing any other Indebtedness being defeased, discharged or replaced) to which the Company or any of its Subsidiaries is a party or by which the Company or any of its Subsidiaries is bound;

(6)

the Company must deliver to the trustee an officers’ certificate stating that the deposit was not made by the Company with the intent of preferring the Holders of such notes over the other creditors of the Company or with the intent of defeating, hindering, delaying or defrauding creditors of the Company or others; and

(7)

the Company must deliver to the trustee an officers’ certificate and an opinion of counsel, each stating that all conditions precedent relating to the Legal Defeasance or the Covenant Defeasance have been complied with.

Amendment, Supplement and Waiver

Except as provided in the next three succeeding paragraphs, the indenture, the notes or the Subsidiary Guarantees may be amended or supplemented with the consent of the Holders of at least a majority in aggregate principal amount of the notes then outstanding (including, without limitation, consents obtained in connection with a purchase of, or tender offer or exchange offer for, notes), and any existing default or compliance with any provision of the indenture, the notes or the Subsidiary Guarantees may be waived with the consent of the Holders of at least a majority in aggregate principal amount of the then outstanding notes (including, without limitation, consents obtained in connection with a purchase of, or tender offer or exchange offer for, notes).

Without the consent of each Holder affected, an amendment, supplement or waiver may not (with respect to any notes held by a non-consenting Holder):

(1)

reduce the principal amount of notes whose Holders must consent to an amendment, supplement or waiver;

(2)

reduce the principal of or change the fixed maturity of any note or alter the provisions with respect to the redemption or repurchase of the notes (other than provisions relating to the covenants described above under the caption “—Repurchase at the Option of Holders”);

(3)

reduce the rate of or change the time for payment of interest on any note;

(4)

waive a Default or Event of Default in the payment of principal of, or interest or premium, if any, on the notes (except a rescission of acceleration of the notes by the Holders of at least a majority in principal amount of the notes and a waiver of the payment default that resulted from such acceleration);

(5)

make any note payable in currency other than that stated in the notes;

(6)

make any change in the provisions of the indenture relating to waivers of past Defaults or the rights of Holders of notes to receive payments of principal of, or interest or premium, if any, on the notes (other than as permitted in clause (7) below);

(7)

waive a redemption or repurchase payment with respect to any note (other than a payment required by one of the covenants described above under the caption “—Repurchase at the Option of Holders”);

(8)

release any Guarantor from any of its obligations under its Subsidiary Guarantee or the indenture, except in accordance with the terms of the indenture; or

(9)

make any change in the preceding amendment, supplement and waiver provisions.

The consent of the Holders of notes is not necessary under the indenture to approve the particular form of any proposed amendment. It is sufficient if such consent approves the substance of the proposed amendment.

Notwithstanding the preceding, without the consent of any Holder of notes, the Company, the Guarantors and the trustee may amend or supplement the indenture, the notes or Subsidiary Guarantees:

(1)

to cure any ambiguity, defect or inconsistency;

(2)

to provide for uncertificated notes in addition to or in place of certificated notes;

(3)

to provide for the assumption of the Company’s or a Guarantor’s obligations to Holders of notes in the case of a merger or consolidation or sale of all or substantially all of the Company’s or such Guarantor’s properties or assets;

(4)

to make any change that would provide any additional rights or benefits to the Holders of notes or that does not adversely affect the legal rights under the indenture of any Holder, provided that any change to conform the indenture to this prospectus will not be deemed to adversely affect the legal rights under the indenture of any holder;

(5)

to secure the notes or the Subsidiary Guarantees pursuant to the requirements of the covenant described above under the subheading “—Certain Covenants—Liens;”

(6)

to provide for the issuance of additional notes in accordance with the limitations set forth in the indenture;

(7)

to add any additional Guarantor or to evidence the release of any Guarantor from its Subsidiary Guarantee, in each case as provided in the indenture;

(8)

to comply with requirements of the Commission in order to effect or maintain the qualification of the indenture under the Trust Indenture Act;

(9)

to evidence or provide for the acceptance of appointment under the indenture of a successor trustee;

(10)

to add to, change or eliminate any provisions of the indenture in respect of one or more other series of debt securities; or

(11)

to establish the forms or terms of debt securities of any other series as permitted by the indenture.

Neither the Company nor any of its Subsidiaries shall, directly or indirectly, pay or cause to be paid any consideration, whether by way of interest, fee or otherwise, to any Beneficial Owner or Holder of any notes for or as an inducement to any consent to any waiver, supplement or amendment of any terms or provisions of the indenture or the notes, unless such consideration is offered to be paid or agreed to be paid to all Beneficial Owners and Holders of the notes which so consent in the time frame set forth in solicitation documents relating to such consent.

Satisfaction and Discharge

The indenture will be discharged and will cease to be of further effect as to all notes issued thereunder when:

(1)

either:

(a)

all outstanding notes issued that have been authenticated (except lost, stolen or destroyed notes that have been replaced or paid and notes for whose payment money has theretofore been deposited in trust and thereafter repaid to us) have been delivered to the trustee for cancellation; or

(b)

all outstanding notes that have not been delivered to the trustee for cancellation have become due and payable or will become due and payable at their maturity within one year or are to be called for redemption within one year under arrangements satisfactory to the trustee and in any case we have irrevocably deposited with the trustee as trust funds money in an amount sufficient, without consideration of any reinvestment of interest, to pay the entire indebtedness of such notes not delivered to the trustee for cancellation, for principal, premium, if any, and accrued interest to the maturity or redemption date;

(2)

we have paid or caused to be paid all other sums payable by us under the indenture with respect to the notes;

(3)

we have delivered an Officers’ Certificate and an Opinion of Counsel to the trustee stating that all conditions precedent to satisfaction and discharge of the indenture with respect to the notes have been satisfied; and

(4)

we have delivered to the trustee an Officer’s Certificate stating that the payments of principal and interest when due and without reinvestment of the deposited U.S. Government Obligations plus any deposited money without reinvestment will provide cash at such times and in such amounts as will be sufficient to pay principal and interest when due on all the notes to maturity or redemption, as the case may be.

Concerning the Trustee

The trustee, The Bank of New York Mellon Trust Company, N.A., also acts as trustee under the indentures for our outstanding senior subordinated notes and our outstanding senior notes.

If the trustee becomes a creditor of the Company or any Guarantor, the indenture limits its right to obtain payment of claims in certain cases, or to realize on certain property received in respect of any such claim as security or otherwise. The trustee will be permitted to engage in other transactions; however, if it acquires any conflicting interest (as defined in the Trust Indenture Act) after a Default has occurred and is continuing, it must eliminate such conflict within 90 days, apply to the Commission for permission to continue or resign.

The Holders of a majority in principal amount of the then outstanding notes will have the right to direct the time, method and place of conducting any proceeding for exercising any remedy available to the trustee with respect to the notes, subject to certain exceptions. The indenture provides (by reference to the Trust Indenture Act) that in case an Event of Default occurs and is continuing, the trustee will be required, in the exercise of its power, to use the degree of care of a prudent man in the conduct of his own affairs. Subject to such provisions, the trustee will be under no obligation to exercise any of its rights or powers under the indenture at the request of any Holder of notes, unless such Holder has offered to the trustee reasonable security or indemnity against any cost, expense or liability the trustee might incur.

Governing Law

The indenture, the notes and the Subsidiary Guarantees will be governed by, and construed in accordance with, the laws of the State of New York.

Book-Entry, Delivery and Form

Except as set forth below, new notes will be issued only in registered, global form. New notes will be issued at the closing of this exchange offer only in exchange for properly tendered and accepted original notes.

Initially, the new notes will be represented by one or more permanent global notes in registered form without interest coupons (collectively, the “Global Notes”). The Global Notes will be deposited upon issuance with the trustee as custodian for The Depository Trust Company (“DTC”), in New York, New York, and registered in the name of DTC’s nominee, Cede & Co., in each case for credit to an account of a direct or indirect participant in DTC as described below. Beneficial interests in the Global Notes may be held through the Euroclear System (“Euroclear”) and Clearstream Banking, S.A. (“Clearstream”) (as indirect participants in DTC).

Except as set forth below, the Global Notes may be transferred, in whole but not in part, only to another nominee of DTC or to a successor of DTC or its nominee. Beneficial interests in the Global Notes may not be exchanged for definitive notes in registered, certificated form (“Certificated Notes”), except in the limited circumstances described below. See “—Exchange of Global Notes for Certificated Notes.” In addition, transfers of beneficial interests in the Global Notes will be subject to the applicable rules and procedures of DTC and its direct or indirect participants (including, if applicable, those of Euroclear and Clearstream), which may change from time to time.

Depository Procedures

The following description of the operations and procedures of DTC, Euroclear and Clearstream are provided solely as a matter of convenience. These operations and procedures are solely within the control of the respective settlement systems and are subject to changes by them. We take no responsibility for these operations and procedures and urge investors to contact the system or their participants directly to discuss these matters.

DTC has advised us that DTC is a limited-purpose trust company created to hold securities for its participating organizations (collectively, the “Participants”) and to facilitate the clearance and settlement of transactions in those securities between Participants through electronic book-entry changes in accounts of its Participants. The Participants include securities brokers and dealers (including the initial purchasers), banks, trust companies, clearing corporations and certain other organizations. Access to DTC’s system is also available to other entities such as banks, brokers, dealers and trust companies that clear through or maintain a custodial relationship with a Participant, either directly or indirectly (collectively, the “Indirect Participants”). Persons who are not Participants may beneficially own securities held by or on behalf of DTC only through the Participants or the Indirect Participants. The ownership interests in, and transfers of ownership interests in, each security held by or on behalf of DTC are recorded on the records of the Participants and Indirect Participants.

DTC has also advised us that, pursuant to procedures established by it:

(1)

upon deposit of the Global Notes, DTC will credit the accounts of Participants designated by the initial purchasers with portions of the principal amount of the Global Notes; and

(2)

ownership of these interests in the Global Notes will be shown on, and the transfer of ownership of these interests will be effected only through, records maintained by DTC (with respect to the Participants) or by the Participants and the Indirect Participants (with respect to other owners of beneficial interests in the Global Notes).

Investors in the Global Notes who are Participants in DTC’s system may hold their interests therein directly through DTC. Investors in the Global Notes who are not Participants may hold their interests therein indirectly through organizations (including Euroclear and Clearstream) which are Participants in such system. Euroclear and Clearstream may hold interests in the Global Notes on behalf of their participants through customers’

securities accounts in their respective names on the books of their respective depositories, which are Euroclear Bank S.A./N.V., as operator of Euroclear, and Citibank, N.A., as operator of Clearstream. All interests in a Global Note, including those held through Euroclear or Clearstream, may be subject to the procedures and requirements of DTC. Those interests held through Euroclear or Clearstream may also be subject to the procedures and requirements of such systems.

The laws of some states require that certain Persons take physical delivery in definitive form of securities that they own. Consequently, the ability to transfer beneficial interests in a Global Note to such Persons will be limited to that extent. Because DTC can act only on behalf of Participants, which in turn act on behalf of Indirect Participants, the ability of a Person having beneficial interests in a Global Note to pledge such interests to Persons that do not participate in the DTC system, or otherwise take actions in respect of such interests, may be affected by the lack of a physical certificate evidencing such interests.

Except as described below, owners of an interest in the Global Notes will not have new notes registered in their names, will not receive physical delivery of Certificated Notes and will not be considered the registered owners or “Holders” thereof under the indenture for any purpose.

Payments in respect of the principal of, and interest and premium, if any, on a Global Note registered in the name of DTC or its nominee will be payable to DTC in its capacity as the registered Holder under the indenture. Under the terms of the indenture, the Company and the trustee will treat the Persons in whose names the new notes, including the Global Notes, are registered as the owners of the new notes for the purpose of receiving payments and for all other purposes. Consequently, neither the Company, the trustee nor any agent of the Company or the trustee has or will have any responsibility or liability for:

(1)

any aspect of DTC’s records or any Participant’s or Indirect Participant’s records relating to or payments made on account of beneficial ownership interests in the Global Notes or for maintaining, supervising or reviewing any of DTC’s records or any Participant’s or Indirect Participant’s records relating to the beneficial ownership interests in the Global Notes; or

(2)

any other matter relating to the actions and practices of DTC or any of its Participants or Indirect Participants.

DTC has advised us that its current practice, at the due date of any payment in respect of securities such as the new notes, is to credit the accounts of the relevant Participants with the payment on the payment date unless DTC has reason to believe it will not receive payment on such payment date. Each relevant Participant is credited with an amount proportionate to its beneficial ownership of an interest in the principal amount of the new notes as shown on the records of DTC. Payments by the Participants and the Indirect Participants to the beneficial owners of new notes will be governed by standing instructions and customary practices and will be the responsibility of the Participants or the Indirect Participants and will not be the responsibility of DTC, the trustee or the Company. Neither the Company nor the trustee will be liable for any delay by DTC or any of its Participants in identifying the beneficial owners of the new notes, and the Company and the trustee may conclusively rely on and will be protected in relying on instructions from DTC or its nominee for all purposes.

Transfers between Participants in DTC will be effected in accordance with DTC’s procedures, and will be settled in same-day funds, and transfers between participants in Euroclear and Clearstream will be effected in accordance with their respective rules and operating procedures.

Cross-market transfers between the Participants in DTC, on the one hand, and Euroclear or Clearstream participants, on the other hand, will be effected through DTC in accordance with DTC’s rules on behalf of Euroclear or Clearstream, as the case may be, by its depositary; however, such cross-market transactions will require delivery of instructions to Euroclear or Clearstream, as the case may be, by the counterparty in such system in accordance with the rules and procedures and within the established deadlines (Brussels time) of such system. Euroclear or Clearstream, as the case may be, will, if the transaction meets its settlement requirements,

deliver instructions to its respective depositary to take action to effect final settlement on its behalf by delivering or receiving interests in the relevant Global Note in DTC, and making or receiving payment in accordance with normal procedures for same-day funds settlement applicable to DTC. Euroclear participants and Clearstream participants may not deliver instructions directly to the depositories for Euroclear or Clearstream.

DTC has advised us that it will take any action permitted to be taken by a Holder of new notes only at the direction of one or more Participants to whose account DTC has credited the interests in the Global Notes and only in respect of such portion of the aggregate principal amount of the new notes as to which such Participant or Participants has or have given such direction. However, if there is an Event of Default under the new notes, DTC reserves the right to exchange the Global Notes for Certificated Notes and to distribute such new notes to its Participants.

Although DTC, Euroclear and Clearstream have agreed to the foregoing procedures to facilitate transfers of interests in the Global Notes among participants in DTC, Euroclear and Clearstream, they are under no obligation to perform or to continue to perform such procedures, and may discontinue such procedures at any time. None of the Company, the trustee or any of their respective agents will have any responsibility for the performance by DTC, Euroclear or Clearstream or their respective participants or indirect participants of their respective obligations under the rules and procedures governing their operations.

Exchange of Global Notes for Certificated Notes

A Global Note is exchangeable for Certificated Notes in minimum denominations of $2,000 and in integral multiples of $1,000, if:

(1)

DTC (a) notifies us that it is unwilling or unable to continue as depositary for the Global Notes or (b) has ceased to be a clearing agency registered under the Exchange Act and in either event the Company fails to appoint a successor depositary within 90 days; or

(2)

there has occurred and is continuing an Event of Default and DTC notifies the trustee of its decision to exchange the Global Note for Certificated Notes.

Certificated Notes delivered in exchange for any Global Note or beneficial interests in Global Notes will be registered in the names, and issued in any approved denominations, requested by or on behalf of the depositary (in accordance with its customary procedures).

Same Day Settlement and Payment

The Company will make payments in respect of the new notes represented by the Global Notes (including principal, premium, if any, and interest) by wire transfer of immediately available funds to the accounts specified by the Global Note Holder. The Company will make all payments of principal, interest and premium, if any, with respect to Certificated Notes by wire transfer of immediately available funds to the accounts specified by the Holders of the Certificated Notes or, if no such account is specified, by mailing a check to each such Holder’s registered address. The new notes represented by the Global Notes are expected to trade in DTC’s Same-Day Funds Settlement System, and any permitted secondary market trading activity in such new notes will, therefore, be required by DTC to be settled in immediately available funds. The Company expects that secondary trading in any Certificated Notes will also be settled in immediately available funds.

Because of time zone differences, the securities account of a Euroclear or Clearstream participant purchasing an interest in a Global Note from a Participant in DTC will be credited, and any such crediting will be reported to the relevant Euroclear or Clearstream participant, during the securities settlement processing day (which must be a business day for Euroclear and Clearstream) immediately following the settlement date of DTC. DTC has advised us that cash received in Euroclear or Clearstream as a result of sales of interests in a Global Note by or through a Euroclear or Clearstream participant to a Participant in DTC will be received with

value on the settlement date of DTC but will be available in the relevant Euroclear or Clearstream cash account only as of the business day for Euroclear or Clearstream following DTC’s settlement date.

Certain Definitions

Set forth below are certain defined terms used with respect to the notes in the indenture. Reference is made to the indenture for a full disclosure of all such terms, as well as any other capitalized terms used herein for which no definition is provided.

“ACNTA” (Adjusted Consolidated Net Tangible Assets) means (without duplication), as of the date of determination:

(1)

the sum of:

(a)

discounted future net revenue from proved crude oil and natural gas reserves of the Company and its Restricted Subsidiaries calculated in accordance with SEC guidelines before any state or federal income taxes, as estimated in a reserve report prepared as of the end of the Company’s most recently completed fiscal year, which reserve report is prepared or reviewed by independent petroleum engineers as to reserves accounting for at least 80% of all such discounted future net revenue and by the Company’s petroleum engineers with respect to any other such reserves covered by such report, as increased by, as of the date of determination, the discounted future net revenue from:

(i)

estimated proved crude oil and natural gas reserves of the Company and its Restricted Subsidiaries attributable to acquisitions consummated since the date of such year-end reserve report; and

(ii)

estimated crude oil and natural gas reserves of the Company and its Restricted Subsidiaries attributable to extensions, discoveries and other additions and upward determinations of estimates of proved crude oil and natural gas reserves (including previously estimated development costs incurred during the period and the accretion of discount since the prior year end) due to exploration, development or exploitation, production or other activities which reserves were not reflected in such year-end reserve report,

in each case calculated in accordance with SEC guidelines (utilizing the prices utilized in such year-end reserve report), and decreased by, as of the date of determination, the discounted future net revenue attributable to:

(iii)

estimated proved crude oil and natural gas reserves of the Company and its Restricted Subsidiaries reflected in such year-end reserve report produced or disposed of since the date of such year-end reserve report; and

(iv)

reductions in the estimated proved crude oil and natural gas reserves of the Company and its Restricted Subsidiaries reflected in such year-end reserve report since the date of such year-end reserve report attributable to downward determinations of estimates of proved crude oil and natural gas reserves due to exploration, development or exploitation, production or other activities conducted or otherwise occurring since the date of such year-end reserve report,

in each case calculated in accordance with SEC guidelines (utilizing the prices utilized in such year-end reserve report); provided, however, that, in the case of each of the determinations made pursuant to clauses (i) through (iv), such increases and decreases shall be as estimated by the Company’s engineers, except that if as a result of such acquisitions, dispositions, discoveries, extensions or revisions, there is a Material Change, then such increases and decreases in the discounted future net revenue shall be confirmed in writing by an independent petroleum engineer;

(b)

the capitalized costs that are attributable to crude oil and natural gas properties of the Company and its Restricted Subsidiaries to which no proved crude oil and natural gas reserves are attributed,

based on the Company’s books and records as of a date no earlier than the date of the Company’s latest annual or quarterly financial statements;

(c)

the Net Working Capital on a date no earlier than the date of the Company’s latest annual or quarterly financial statements; and

(d)

the greater of (I) the net book value on a date no earlier than the date of the Company’s latest annual or quarterly financial statements or (II) the appraised value, as estimated by independent appraisers, of other tangible assets of the Company and its Restricted Subsidiaries as of a date no earlier than the date of the Company’s latest audited financial statements;

(2)

minus, to the extent not otherwise taken into account in the immediately preceding clause (1), the sum of:

(a)

minority interests;

(b)

any net gas balancing liabilities of the Company and its Restricted Subsidiaries reflected in the Company’s latest audited financial statements;

(c)

the discounted future net revenue, calculated in accordance with SEC guidelines (utilizing the same prices utilized in the Company’s year-end reserve report), attributable to reserves subject to participation interests, overriding royalty interests or other interests of third parties, pursuant to participation, partnership, vendor financing or other agreements then in effect, or which otherwise are required to be delivered to third parties;

(d)

the discounted future net revenue, calculated in accordance with SEC guidelines (utilizing the same prices utilized in the Company’s year-end reserve report), attributable to reserves that are required to be delivered to third parties to fully satisfy the obligations of the Company and its Restricted Subsidiaries with respect to Volumetric Production Payments on the schedules specified with respect thereto; and

(e)

the discounted future net revenue, calculated in accordance with SEC guidelines, attributable to reserves subject to Dollar-Denominated Production Payments that, based on the estimates of production included in determining the discounted future net revenue specified in the immediately preceding clause (1)(a) (utilizing the same prices utilized in the Company’s year-end reserve report), would be necessary to satisfy fully the obligations of the Company and its Restricted Subsidiaries with respect to Dollar-Denominated Production Payments on the schedules specified with respect thereto.

If the Company changes its method of accounting for its oil and gas properties from the successful efforts method to the full cost method or a similar method of accounting, ACNTA will continue to be calculated as if the Company were still using the successful efforts method of accounting.

“Acquired Debt” means, with respect to any specified Person:

(1)

Indebtedness of any other Person existing at the time such other Person was merged with or into or became a Subsidiary of such specified Person, whether or not such Indebtedness is incurred in connection with, or in contemplation of, such other Person merging with or into, or becoming a Subsidiary of, such specified Person; provided, however, that Indebtedness of such acquired person which is redeemed, defeased, retired or otherwise repaid at the time of or substantially contemporaneously with the consummation of the transactions by which such Person merges with or into or becomes a Subsidiary of such Person shall not be Acquired Debt; and

(2)

Indebtedness secured by a Lien encumbering any asset acquired by such specified Person.

“Additional Assets” means:

(1)

any assets used or useful in the Oil and Gas Business;

(2)

the Capital Stock of a Person that becomes a Restricted Subsidiary as a result of the acquisition of such Capital Stock by the Company or another Restricted Subsidiary; or

(3)

Capital Stock constituting a minority in any Person that at such time is a Restricted Subsidiary;

provided, however, that any such Restricted Subsidiary described in clause (2) or (3) is primarily engaged in the Oil and Gas Business.

“Affiliate” of any specified Person means any other Person directly or indirectly controlling or controlled by or under direct or indirect common control with such specified Person. For purposes of this definition, “control,” as used with respect to any Person, means the possession, directly or indirectly, of the power to direct or cause the direction of the management or policies of such Person, whether through the ownership of voting securities, by agreement or otherwise. For purposes of this definition, the terms “controlling,” “controlled by” and “under common control with” have correlative meanings.

“Asset Sale” means:

(1)

the sale, lease, conveyance or other disposition of any properties or assets (including by way of a Production Payment or sale and leaseback transaction); provided that the sale, lease, conveyance or other disposition of all or substantially all of the properties or assets of the Company and its Restricted Subsidiaries taken as a whole will be governed by the provisions of the indenture described above under the caption “—Repurchase at the Option of Holders—Change of Control” and/or the provisions described above under the caption “—Certain Covenants—Merger, Consolidation or Sale of Assets” and not by the provisions of the Asset Sale covenant; and

(2)

the issuance of Equity Interests in any of the Company’s Restricted Subsidiaries or the sale by the Company or any of the Company’s Restricted Subsidiaries of Equity Interests in any of the Company’s Restricted Subsidiaries (other than directors’ qualifying shares or shares required by applicable law to be held by a Person other than the Company or a Restricted Subsidiary).

Notwithstanding the preceding, the following items will not be deemed to be Asset Sales:

(1)

any single transaction or series of related transactions that involves properties or assets having a fair market value of less than $15.0 million;

(2)

a transfer of assets between or among any of the Company and its Restricted Subsidiaries;

(3)

an issuance or sale of Equity Interests by a Restricted Subsidiary to the Company or to another Restricted Subsidiary;

(4)

the sale, lease or other disposition of equipment, inventory, accounts receivable or other properties or assets in the ordinary course of business, including, without limitation, any abandonment, farm-in, farm-out, lease or sublease of any oil and gas properties or the forfeiture or other disposition of such properties pursuant to standard form operating agreements, in each case in the ordinary course of business in a manner customary in the Oil and Gas Business;

(5)

the sale or other disposition of cash or Cash Equivalents;

(6)

a Restricted Payment that is permitted by the covenant described above under the caption ‘‘—Certain Covenants—Restricted Payments” or a Permitted Investment;

(7)

any trade or exchange by the Company or any Restricted Subsidiary of oil and gas properties or other properties or assets for oil and gas properties or other properties or assets owned or held by another Person, provided that the fair market value of the properties or assets traded or exchanged by the Company or such Restricted Subsidiary (together with any cash) is reasonably equivalent to the fair market value of the properties or assets (together with any cash) to be received by the Company or such Restricted Subsidiary, and provided further that any net cash received must be applied in accordance

with the provisions described above under the caption “—Repurchase at the Option of Holders—Asset Sales;”

(8)

the creation or perfection of a Lien (but not the sale or other disposition of the properties or assets subject to such Lien);

(9)

surrender or waiver of contract rights or the settlement, release or surrender of contract, tort or other claims of any kind; and

(10)

any sale or other disposition of damaged, worn-out or obsolete assets in the ordinary course of business (including the assignment, cancellation or abandonment or other disposition of intellectual property that is, in the reasonable judgment of the Company, no longer economically practicable to maintain or useful in any material respect in the conduct of the business of the Company and its Restricted Subsidiaries taken as whole).

“Attributable Debt” in respect of a sale and leaseback transaction means, at the time of determination, the present value of the obligation of the lessee for net rental payments during the remaining term of the lease included in such sale and leaseback transaction including any period for which such lease has been extended or may, at the option of the lessor, be extended. Such present value shall be calculated using a discount rate equal to the rate of interest implicit in such transaction, determined in accordance with GAAP.

“Beneficial Owner” has the meaning assigned to such term in Rule 13d-3 and Rule 13d-5 under the Exchange Act, except that in calculating the beneficial ownership of any particular “person” (as that term is used in Section 13(d)(3) of the Exchange Act), such “person” will be deemed to have beneficial ownership of all securities that such “person” has the right to acquire by conversion or exercise of other securities, whether such right is currently exercisable or is exercisable only upon the occurrence of a subsequent condition. The terms “Beneficially Owns” and “Beneficially Owned” have correlative meanings.

“Board of Directors” means:

(1)

with respect to a corporation, the board of directors of the corporation or any committee thereof duly authorized to act on behalf of such board;

(2)

with respect to a partnership, the Board of Directors of the general partner of the partnership;

(3)

with respect to a limited liability company, the Board of Directors of the managing member, if the managing member is an entity, or the managing member or members or any controlling committee of managing members thereof, if the managing members are individuals; and

(4)

with respect to any other Person, the board or committee of such Person serving a similar function.

“Board Resolution” means a copy of a resolution certified by the Secretary or an Assistant Secretary of the applicable Person to have been duly adopted by the Board of Directors of such Person and to be in full force and effect on the date of such certification, and delivered to the trustee.

“Business Day” means each day that is not a Saturday, Sunday or other day on which banking institutions in Chicago, Illinois, Denver, Colorado or New York, New York or another place of payment are authorized or required by law to close.

“Capital Lease Obligation” means, at the time any determination is to be made, the amount of the liability in respect of a capital lease that would at that time be required to be capitalized on a balance sheet in accordance with GAAP.

“Capital Stock” means:

(1)

in the case of a corporation, corporate stock;

(2)

in the case of an association or business entity, any and all shares, interests, participations, rights or other equivalents (however designated) of corporate stock;

(3)

in the case of a partnership or limited liability company, partnership or membership interests (whether general or limited); and

(4)

any other interest or participation that confers on a Person the right to receive a share of the profits and losses of, or distributions of assets of, the issuing Person.

“Cash

Equivalents” means:

(1)

United States dollars;

(2)

securities issued or directly and fully guaranteed or insured by the United States government or any agency or instrumentality of the United States government (provided that the full faith and credit of the United States is pledged in support of those securities) having maturities of not more than one year from the date of acquisition;

(3)

certificates of deposit and eurodollar time deposits with maturities of one year or less from the date of acquisition, bankers’ acceptances with maturities not exceeding one year and overnight bank deposits, in each case, with any lender party to the Credit Agreement or with any domestic commercial bank;

(4)

repurchase obligations with a term of not more than seven days for underlying securities of the types described in clauses (2) and (3) above entered into with any financial institution meeting the qualifications specified in clause (3) above;

(5)

commercial paper having one of the two highest ratings obtainable from Moody’s or S&P and in each case maturing within one year after the date of acquisition;

(6)

money market funds the assets of which primarily constitute Cash Equivalents of the kinds described in clauses (1) through (5) of this definition; and

(7)

repurchase obligations with a term of not more than seven days for underlying securities of the types described in clause (1) above entered into with any financial institution meeting the qualifications specified in clause (3) above.

“Change of Control” means the occurrence of any of the following:

(1)

the direct or indirect sale, lease, transfer, conveyance or other disposition (other than by way of merger or consolidation), in one or a series of related transactions, of all or substantially all of the properties or assets (including Capital Stock of the Restricted Subsidiaries) of the Company and its Restricted Subsidiaries taken as a whole, to any “person” (as that term is used in Section 13(d)(3) of the Exchange Act), which occurrence is followed by a Rating Decline within 90 days thereof;

(2)

the adoption of a plan relating to the liquidation or dissolution of the Company;

(3)

the consummation of any transaction (including, without limitation, any merger or consolidation) the result of which is that any “person” (as that term is used in Section 13(d)(3) of the Exchange Act) becomes the Beneficial Owner, directly or indirectly, of more than 50% of the Voting Stock of the Company, measured by voting power rather than number of shares, which occurrence is followed by a Rating Decline within 90 days thereof; or

(4)

the first day on which a majority of the members of the Board of Directors of the Company are not Continuing Directors, which occurrence is followed by a Rating Decline within 90 days thereof.

“Commission” or “SEC” means the Securities and Exchange Commission.

“Consolidated Cash Flow” means, with respect to any specified Person for any period, the Consolidated Net Income of such Person for such period plus:

(1)

an amount equal to any extraordinary loss plus any net loss realized by such Person or any of its Restricted Subsidiaries in connection with an Asset Sale, to the extent such losses were deducted in computing such Consolidated Net Income; plus

(2)

provision for taxes based on income or profits of such Person and its Restricted Subsidiaries for such period, to the extent that such provision for taxes was deducted in computing such Consolidated Net Income; plus

(3)

consolidated interest expense of such Person and its Restricted Subsidiaries for such period, whether paid or accrued and whether or not capitalized (excluding any interest attributable to Dollar-Denominated Production Payments but including, without limitation, amortization of debt issuance costs and original issue discount, non-cash interest payments, the interest component of any deferred payment obligations, the interest component of all payments associated with Capital Lease Obligations, imputed interest with respect to Attributable Debt, commissions, discounts and other fees and charges incurred in respect of letter of credit or bankers’ acceptance financings), and net of the effect of all payments made or received pursuant to Hedging Obligations, to the extent that any such expense was deducted in computing such Consolidated Net Income; plus

(4)

depreciation, depletion and amortization (including amortization of intangibles but excluding amortization of prepaid cash expenses that were paid in a prior period), impairment and other non-cash expenses (excluding any such non-cash expense to the extent that it represents an accrual of or reserve for cash expenses in any future period or amortization of a prepaid cash expense that was paid in a prior period) of such Person and its Restricted Subsidiaries for such period to the extent that such depreciation, depletion and amortization, impairment and other non-cash expenses were deducted in computing such Consolidated Net Income; plus

(5)

unrealized non-cash losses resulting from foreign currency balance sheet adjustments required by GAAP to the extent such losses were deducted in computing such Consolidated Net Income; minus

(6)

non-cash items increasing such Consolidated Net Income for such period, other than items that were accrued in the ordinary course of business; minus (to the extent included in determining Consolidated Net Income); and

(7)

the sum of (x) the amount of deferred revenues that are amortized during such period and are attributable to reserves that are subject to Volumetric Production Payments and (y) amounts recorded in accordance with GAAP as repayments of principal and interest pursuant to Dollar-Denominated Production Payments,

in each case, on a consolidated basis and determined in accordance with GAAP.

“Consolidated Net Income” means, with respect to any specified Person for any period, the aggregate of the Net Income of such Person and its Restricted Subsidiaries for such period, on a consolidated basis, determined in accordance with GAAP; provided that:

(1)

the Net Income (but not loss) of any Person that is not a Restricted Subsidiary or that is accounted for by the equity method of accounting will be included, but only to the extent of the amount of dividends or distributions paid in cash to the specified Person or a Restricted Subsidiary of the Person;

(2)

the Net Income of any Restricted Subsidiary will be excluded to the extent that the declaration or payment of dividends or similar distributions by that Restricted Subsidiary of that Net Income is not at the date of determination permitted without any prior governmental approval (that has not been obtained) or, directly or indirectly, by operation of the terms of its charter or any agreement, instrument, judgment, decree, order, statute, rule or governmental regulation applicable to that Restricted Subsidiary or its stockholders, partners or members;

(3)

the cumulative effect of a change in accounting principles will be excluded;

(4)

income resulting from transfers of assets (other than cash) between the Company or any of its Restricted Subsidiaries, on the one hand, and an Unrestricted Subsidiary, on the other hand, will be excluded;

(5)

any write-downs of non-current assets will be excluded; provided that any ceiling limitation write-downs under Commission guidelines shall be treated as capitalized costs, as if such write-downs had not occurred; and

(6)

any unrealized non-cash gains or losses or charges in respect of hedge or non-hedge derivatives (including those resulting from the application of FAS 133 (now codified as FASB Accounting Standards Codification Topic 815)) will be excluded.

In addition, notwithstanding the preceding, for the purposes of the covenant described under “—Certain Covenants—Restricted Payments” only, there shall be excluded from Consolidated Net Income any nonrecurring charges relating to any premium or penalty paid, write off of deferred finance costs or other charges in connection with redeeming or retiring any Indebtedness prior to its Stated Maturity.

“Continuing Directors” means, as of any date of determination, any member of the Board of Directors of the Company who:

(1)

was a member of such Board of Directors on the Issue Date; or

(2)

was nominated for election or elected to such Board of Directors with the approval of a majority of the Continuing Directors who were members of such Board at the time of such nomination or election.

“Credit Agreement” means that certain Fifth Amended and Restated Credit Agreement, dated as of October 15, 2010, as amended, among Whiting Oil and Gas Corporation, the Company, the financial institutions parties thereto, providing for revolving credit borrowings, including any related notes, guarantees, collateral documents, instruments and agreements executed in connection therewith, and in each case as amended, restated, modified, renewed, refunded, replaced or refinanced from time to time.

“Credit Facilities” means one or more debt facilities (including, without limitation, the Credit Agreement), commercial paper facilities or secured capital markets financings, in each case with banks or other institutional lenders or institutional investors providing for revolving credit loans, term loans, receivables financing (including through the sale of receivables to such lenders or to special purpose entities formed to borrow from (or sell receivables to) such lenders against such receivables), letters of credit or secured capital markets financings, in each case, as amended, restated, modified, renewed, refunded, replaced or refinanced (including refinancing with any capital markets transaction) in whole or in part from time to time.

“Default” means any event that is, or with the passage of time or the giving of notice or both would be, an Event of Default.

“Disqualified Stock” means any Capital Stock that, by its terms (or by the terms of any security into which it is convertible, or for which it is exchangeable, in each case at the option of the holder of the Capital Stock), or upon the happening of any event, matures or is mandatorily redeemable, pursuant to a sinking fund obligation or otherwise, or redeemable at the option of the holder of the Capital Stock, in whole or in part, on or prior to the date that is 91 days after the date on which the notes mature. Notwithstanding the preceding sentence, any Capital Stock that would constitute Disqualified Stock solely because the holders of the Capital Stock have the right to require the Company to repurchase or redeem such Capital Stock upon the occurrence of a change of control or an asset sale will not constitute Disqualified Stock if the terms of such Capital Stock provide that the Company may not repurchase or redeem any such Capital Stock pursuant to such provisions unless such repurchase or redemption complies with the covenant described above under the caption “—Certain Covenants—Restricted Payments.”

“Dollar-Denominated Production Payments” means production payment obligations recorded as liabilities in accordance with GAAP, together with all undertakings and obligations in connection therewith.

“Domestic Subsidiary” means any Restricted Subsidiary of the Company other than a Foreign Subsidiary.

“Equity Interests” means Capital Stock and all warrants, options or other rights to acquire Capital Stock (but excluding any debt security that is convertible into, or exchangeable for, Capital Stock).

“Existing Indebtedness” means the aggregate principal amount of Indebtedness of the Company and its Restricted Subsidiaries (other than Indebtedness under the Credit Agreement which is considered incurred under the first paragraph under the covenant entitled “Incurrence of Indebtedness and Issuance of Preferred Stock”) in existence on the Issue Date, until such amounts are repaid.

“Fixed Charge Coverage Ratio” means with respect to any specified Person for any four-quarter reference period, the ratio of the Consolidated Cash Flow of such Person for such period to the Fixed Charges of such Person for such period. In the event that the specified Person or any of its Restricted Subsidiaries incurs, assumes, guarantees, repays, repurchases or redeems any Indebtedness (other than ordinary working capital borrowings) or issues, repurchases or redeems preferred stock subsequent to the commencement of the applicable four-quarter reference period and on or prior to the date on which the event for which the calculation of the Fixed Charge Coverage Ratio is made (the “Calculation Date”), then the Fixed Charge Coverage Ratio will be calculated giving pro forma effect to such incurrence, assumption, guarantee, repayment, repurchase or redemption of Indebtedness, or such issuance, repurchase or redemption of preferred stock, and the use of the proceeds therefrom as if the same had occurred at the beginning of such period.

In addition, for purposes of calculating the Fixed Charge Coverage Ratio:

(1)

acquisitions that have been made by the specified Person or any of its Restricted Subsidiaries, including through mergers or consolidations and including any related financing transactions, subsequent to the commencement of the applicable four-quarter reference period and on or prior to the Calculation Date will be given pro forma effect as if they had occurred on the first day of such period, including any Consolidated Cash Flow and any pro forma expense and cost reductions that have occurred or are reasonably expected to occur, in the reasonable judgment of the chief financial or accounting officer of the Company (regardless of whether those cost savings or operating improvements could then be reflected in pro forma financial statements in accordance with Regulation S-X promulgated under the Securities Act or any other regulation or policy of the Commission related thereto);

(2)

the Consolidated Cash Flow attributable to discontinued operations, as determined in accordance with GAAP, and operations or businesses disposed of prior to the Calculation Date, will be excluded; and

(3)

the Fixed Charges attributable to discontinued operations, as determined in accordance with GAAP, and operations or businesses disposed of prior to the Calculation Date, will be excluded, but only to the extent that the obligations giving rise to such Fixed Charges will not be obligations of the specified Person or any of its Restricted Subsidiaries following the Calculation Date.

“Fixed Charges” means, with respect to any specified Person for any period, the sum, without duplication, of:

(1)

the consolidated interest expense of such Person and its Restricted Subsidiaries for such period, whether paid or accrued (excluding any interest attributable to Dollar-Denominated Production Payments but including, without limitation, amortization of debt issuance costs and original issue discount, non-cash interest payments, the interest component of any deferred payment obligations, the interest component of all payments associated with Capital Lease Obligations, imputed interest with respect to Attributable Debt, commissions, discounts and other fees and charges incurred in respect of letter of credit or bankers’ acceptance financings), and net of the effect of all payments made or received pursuant to Hedging Obligations; plus

(2)

the consolidated interest expense of such Person and its Restricted Subsidiaries that was capitalized during such period; plus

(3)

any interest expense on Indebtedness of another Person that is guaranteed by such Person or one of its Restricted Subsidiaries or secured by a Lien on assets of such Person or one of its Restricted Subsidiaries, whether or not such guarantee or Lien is called upon; plus

(4)

all dividends, whether paid or accrued and whether or not in cash, on any series of preferred stock of such Person or any of its Restricted Subsidiaries, other than dividends on Equity Interests payable solely in Equity Interests of the Company (other than Disqualified Stock) or to the Company or a Restricted Subsidiary of the Company,

in each case, on a consolidated basis and in accordance with GAAP.

“Foreign Subsidiary” means any Restricted Subsidiary of the Company that was not formed under the laws of the United States or any state of the United States or the District of Columbia and that conducts substantially all of its operations outside the United States.

“GAAP” means generally accepted accounting principles in the United States, which are in effect on the Issue Date.

The term “guarantee” means a guarantee other than by endorsement of negotiable instruments for collection in the ordinary course of business, direct or indirect, in any manner including, without limitation, by way of a pledge of assets or through letters of credit or reimbursement agreements in respect thereof, of all or any part of any Indebtedness. When used as a verb, “guarantee” has a correlative meaning.

“Guarantors” means each of:

(1)

Whiting Oil and Gas Corporation, a Delaware corporation; and

(2)

any other Restricted Subsidiary of the Company that becomes a Guarantor in accordance with the provisions of the indenture;

and their respective successors and assigns.

“Hedging Obligations” means, with respect to any specified Person, the obligations of such Person incurred in the normal course of business and consistent with past practices and not for speculative purposes under:

(1)

interest rate swap agreements, interest rate cap agreements and interest rate collar agreements entered into with one of more financial institutions and designed to protect the Person or any of its Restricted Subsidiaries entering into the agreement against fluctuations in interest rates with respect to Indebtedness incurred and not for purposes of speculation;

(2)

foreign exchange contracts and currency protection agreements entered into with one of more financial institutions and designed to protect the Person or any of its Restricted Subsidiaries entering into the agreement against fluctuations in currency exchanges rates with respect to Indebtedness incurred and not for purposes of speculation;

(3)

any commodity futures contract, commodity option or other similar agreement or arrangement designed to protect against fluctuations in the price of oil, natural gas or other commodities used, produced, processed or sold by that Person or any of its Restricted Subsidiaries at the time; and

(4)

other agreements or arrangements designed to protect such Person or any of its Restricted Subsidiaries against fluctuations in interest rates, commodity prices or currency exchange rates.

“Holder” means a Person in whose name a note is registered.

“Indebtedness” means, with respect to any specified Person, any indebtedness of such Person, whether or not contingent:

(1)

in respect of borrowed money;

(2)

evidenced by bonds, notes, debentures or similar instruments or letters of credit (or reimbursement agreements in respect thereof);

(3)

in respect of bankers’ acceptances;

(4)

representing Capital Lease Obligations;

(5)

representing the balance deferred and unpaid of the purchase price of any property, except any such balance that constitutes an accrued expense or trade payable; or

(6)

representing any Hedging Obligations,

if and to the extent any of the preceding items (other than letters of credit and Hedging Obligations) would appear as a liability upon a balance sheet of the specified Person prepared in accordance with GAAP. In addition, the term “Indebtedness” includes all Indebtedness of others secured by a Lien on any asset of the specified Person (whether or not such Indebtedness is assumed by the specified Person) and, to the extent not otherwise included, the guarantee by the specified Person of any Indebtedness of any other Person (including, with respect to any Production Payment, any warranties or guarantees of production or payment by such Person with respect to such Production Payment, but excluding other contractual obligations of such Person with respect to such Production Payment). Subject to the preceding sentence, neither Dollar-Denominated Production Payments nor Volumetric Production Payments shall be deemed to be Indebtedness.

The amount of any Indebtedness outstanding as of any date will be:

(1)

the accreted value of the Indebtedness, in the case of any Indebtedness issued with original issue discount;

(2)

in the case of any Hedging Obligation, the termination value of the agreement or arrangement giving rise to such Hedging Obligation that would be payable by such Person at such date; and

(3)

the principal amount of the Indebtedness, together with any interest on the Indebtedness that is more than 30 days past due, in the case of any other Indebtedness.

“Investment Grade Rating” means a rating equal to or higher than “Baa3” (or the equivalent) by Moody’s and “BBB-” (or the equivalent) by S&P.

“Issue Date” means September 12, 2013.

“Investments” means, with respect to any Person, all direct or indirect investments by such Person in other Persons (including Affiliates) in the forms of loans (including guarantees or other obligations), advances or capital contributions (excluding commission, travel and similar advances to officers and employees made in the ordinary course of business), purchases or other acquisitions for consideration of Indebtedness, Equity Interests or other securities, together with all items that are or would be classified as investments on a balance sheet prepared in accordance with GAAP. If the Company or any Restricted Subsidiary of the Company sells or otherwise disposes of any Equity Interests of any direct or indirect Restricted Subsidiary of the Company such that, after giving effect to any such sale or disposition, such Person is no longer a Restricted Subsidiary of the Company, the Company will be deemed to have made an Investment on the date of any such sale or disposition in an amount equal to the fair market value of the Equity Interests of such Restricted Subsidiary not sold or disposed of in an amount determined as provided in the final paragraph of the covenant described above under the caption “—Certain Covenants—Restricted Payments.” The acquisition by the Company or any Subsidiary of the Company of a Person that holds an Investment in a third Person will be deemed to be an Investment made by the Company or such Subsidiary in such third Person in an amount equal to the fair market value of the Investment held by the acquired Person in such third Person on the date of any such acquisition in an amount determined as provided in the final paragraph of the covenant described above under the caption “—Certain Covenants—Restricted Payments.”

“Lien” means, with respect to any asset, any mortgage, lien, pledge, charge, security interest or encumbrance of any kind in respect of such asset, whether or not filed, recorded or otherwise perfected under

applicable law, including any conditional sale or other title retention agreement, any lease in the nature thereof, any option or other agreement to sell or give a security interest in and any filing of or agreement to give any financing statement under the Uniform Commercial Code (or equivalent statutes) of any jurisdiction other than a precautionary financing statement not intended as a security agreement.

“Material Change” means an increase or decrease (excluding changes that result solely from changes in prices and changes resulting from the incurrence of previously estimated future development costs) of more than 25% during a fiscal quarter in the discounted future net revenues from proved crude oil and natural gas reserves of the Company and its Restricted Subsidiaries, calculated in accordance with clause (1)(a) of the definition of ACNTA; provided, however, that the following will be excluded from the calculation of Material Change:

(1)

any acquisitions during the fiscal quarter of oil and gas reserves that have been estimated by independent petroleum engineers and with respect to which a report or reports of such engineers exist; and

(2)

any disposition of properties existing at the beginning of such fiscal quarter that have been disposed of in compliance with the covenant described under “—Repurchase at the Option of Holders—Assets Sales.”

“Material Domestic Subsidiary” means any one Domestic Subsidiary, or any group of two or more Domestic Subsidiaries, that is not a Guarantor at the time of determination and that at such time has either assets or quarterly revenues in excess of 3.0% of the consolidated assets or quarterly revenues of the Company and its Restricted Subsidiaries, in each case based upon the most recent quarterly financial statements available to the Company.

“Moody’s” means Moody’s Investors Service, Inc. or any successor to the rating agency business thereof.

“Net Income” means, with respect to any specified Person, the net income (loss) of such Person, determined in accordance with GAAP and before any reduction in respect of preferred stock dividends, excluding, however:

(1)

any gain (but not loss), together with any related provision for taxes on such gain (but not loss), realized in connection with: (a) any Asset Sale; or (b) the disposition of any securities by such Person or any of its Subsidiaries or the extinguishment of any Indebtedness of such Person or any of its Subsidiaries; and

(2)

any extraordinary gain (but not loss), together with any related provision for taxes on such extraordinary gain (but not loss).

“Net Proceeds” means the aggregate cash proceeds and Cash Equivalents received by the Company or any of its Restricted Subsidiaries in respect of any Asset Sale (including, without limitation, any cash or Cash Equivalents received upon the sale or other disposition of any non-cash consideration received in any Asset Sale), net of:

(1)

the direct costs relating to such Asset Sale, including, without limitation, legal, accounting and investment banking fees, and sales commissions, and any relocation expenses incurred as a result of the Asset Sale;

(2)

taxes paid or payable as a result of the Asset Sale, in each case, after taking into account any available tax credits or deductions and any tax sharing arrangements;

(3)

amounts required to be applied to the repayment of Indebtedness, other than under the Credit Facilities, secured by a Lien on the properties or assets that were the subject of such Asset Sale; and

(4)

any reserve for adjustment in respect of the sale price of such properties or assets established in accordance with GAAP.

“Net Working Capital” means:

(1)

all current assets of the Company and its Restricted Subsidiaries; minus

(2)

all current liabilities of the Company and its Restricted Subsidiaries, except current liabilities included in Indebtedness;

in each case, on a consolidated basis and determined in accordance with GAAP.

“Non-Recourse Debt” means Indebtedness:

(1)

as to which neither the Company nor any of its Restricted Subsidiaries (a) provides credit support of any kind (including any undertaking, agreement or instrument that would constitute Indebtedness), (b) is directly or indirectly liable as a guarantor or otherwise, or (c) is the lender;

(2)

no default with respect to which (including any rights that the holders of the Indebtedness may have to take enforcement action against an Unrestricted Subsidiary) would permit upon notice, lapse of time or both any holder of any other Indebtedness (other than the notes) of the Company or any of its Restricted Subsidiaries to declare a default on such other Indebtedness or cause the payment of the Indebtedness to be accelerated or payable prior to its Stated Maturity; and

(3)

as to which the lenders have been notified in writing that they will not have any recourse to the stock or assets of the Company or any of its Restricted Subsidiaries.

“Obligations” means any principal, premium, if any, interest (including interest accruing on or after the filing of any petition in bankruptcy or for reorganization, whether or not a claim for post-filing interest is allowed in such proceeding), penalties, fees, charges, expenses, indemnifications, reimbursement obligations, damages, guarantees, and other liabilities or amounts payable under the documentation governing any Indebtedness or in respect thereto.

“Oil and Gas Business” means:

(1)

the acquisition, exploration, development, operation and disposition of interests in oil, natural gas and other hydrocarbon properties;

(2)

the gathering, marketing, treating, processing (but not refining), storage, selling and transporting of any production from those interests; and

(3)

any activity necessary, appropriate or incidental to the activities described above.

“Permitted Business Investments” means Investments made in the ordinary course of, and of a nature that is or shall have become customary in, the Oil and Gas Business, including through agreements, transactions, interests or arrangements that permit one to share risk or costs, comply with regulatory requirements regarding local ownership or satisfy other objectives customarily achieved through the conduct of the Oil and Gas Business jointly with third parties, including without limitation:

(1)

direct or indirect ownership of crude oil, natural gas, other related hydrocarbon and mineral properties or any interest therein or gathering, transportation, processing, storage or related systems; and

(2)

the entry into operating agreements, joint ventures, processing agreements, working interests, royalty interests, mineral leases, farm-in agreements, farm-out agreements, development agreements, production sharing agreements, area of mutual interest agreements, contracts for the sale, transportation or exchange of crude oil and natural gas and related hydrocarbons and minerals, unitization agreements, pooling arrangements, joint bidding agreements, service contracts, partnership agreements (whether general or limited), or other similar or customary agreements, transactions, properties, interests or arrangements and Investments and expenditures in connection therewith or pursuant thereto, in each case made or entered into in the ordinary course of the Oil and Gas Business.

“Permitted Investments” means:

(1)

any Investment in the Company or in a Restricted Subsidiary of the Company;

(2)

any Investment in Cash Equivalents;

(3)

any Investment by the Company or any Restricted Subsidiary of the Company in a Person, if as a result of such Investment:

(a)

such Person becomes a Restricted Subsidiary of the Company; or

(b)

such Person is merged, consolidated or amalgamated with or into, or transfers or conveys substantially all of its properties or assets to, or is liquidated into, the Company or a Restricted Subsidiary of the Company;

(4)

any Investment made as a result of the receipt of non-cash consideration from an Asset Sale that was made pursuant to and in compliance with the covenant described above under the caption “—Repurchase at the Option of Holders—Asset Sales;”

(5)

any Investment in any Person solely in exchange for the issuance of Equity Interests (other than Disqualified Stock) of the Company;

(6)

any Investments received in compromise of obligations of trade creditors or customers that were incurred in the ordinary course of business, including pursuant to any plan of reorganization or similar arrangement upon the bankruptcy or insolvency of any trade creditor or customer, or as a result of foreclosure by the Company or any of its Restricted Subsidiaries with respect to any secured Investment in default;

(7)

Hedging Obligations permitted to be incurred under the covenant described under the caption “—Certain Covenants—Incurrence of Indebtedness and Issuance of Preferred Stock;”

(8)

Permitted Business Investments;

(9)

Investments of a Restricted Subsidiary of the Company acquired after the Issue Date or of an entity merged or consolidated with or into the Company or such Restricted Subsidiary in a transaction that is not prohibited by the covenant described under the caption “— Certain Covenants—Merger, Consolidation or Sale of Assets” after the Issue Date to the extent that such Investments were not made in contemplation of such acquisition, merger or consolidation and were in existence on the date of such acquisition, merger or consolidation; and

(10)

other Investments in any Person having an aggregate fair market value (measured on the date each such Investment was made and without giving effect to subsequent changes in value), when taken together with all other Investments made pursuant to this clause (10) that are at the time outstanding, not to exceed the greater of (a) $250.0 million or (b) 2.5% of ACNTA.

“Permitted Liens” means:

(1)

Liens securing any Indebtedness under any Credit Facility;

(2)

Liens in favor of the Company or the Guarantors;

(3)

Liens on property of a Person existing at the time such Person is merged with or into or consolidated with the Company or any Restricted Subsidiary of the Company, provided that such Liens were in existence prior to the contemplation of such merger or consolidation and do not extend to any assets other than those of the Person merged into or consolidated with the Company or the Restricted Subsidiary;

(4)

Liens on property (including Capital Stock) existing at the time of acquisition of the property by the Company or any Restricted Subsidiary of the Company, provided that such Liens were in existence prior to the contemplation of such acquisition;

(5)

Liens securing Indebtedness (including Capital Lease Obligations) incurred in connection with the acquisition by the Company or any Restricted Subsidiary of assets used in the Oil and Gas Business

(including the office buildings and other real property used by the Company or such Restricted Subsidiary in conducting its operations), provided that (i) such Liens attach only to the assets acquired with the proceeds of such Indebtedness, and (ii) such Indebtedness is not in excess of the purchase price of such fixed assets;

(6)

Liens existing on the Issue Date (other than under the Credit Agreement);

(7)

Liens securing Hedging Obligations of the Company or any of its Restricted Subsidiaries;

(8)

any Lien incurred in the ordinary course of business incidental to the conduct of the business of the Company or the Restricted Subsidiaries or the ownership of their property (including (a) easements, rights of way and similar encumbrances, (b) rights or title of lessors under leases (other than Capital Lease Obligations), (c) rights of collecting banks having rights of setoff, revocation, refund or chargeback with respect to money or instruments of the Company or the Restricted Subsidiaries on deposit with or in the possession of such banks, (d) Liens imposed by law, including Liens under workers’ compensation or similar legislation and mechanics’, carriers’, warehousemen’s, materialmen’s, suppliers’ and vendors’ Liens, (e) Liens incurred to secure performance of obligations with respect to statutory or regulatory requirements, performance or return-of-money bonds, surety bonds or other obligations of a like nature and incurred in a manner consistent with industry practice, or (f) operators Liens under joint operating agreements or similar customary agreements in the Oil and Gas Business);

(9)

Liens securing all outstanding notes and the Subsidiary Guarantees thereof;

(10)

Liens securing Indebtedness incurred to refinance Indebtedness incurred under clauses (3), (4) or (5) that was previously so secured, provided that any such Lien is limited to all or part of the same property or assets (plus improvements, accessions, proceeds or dividends or distributions in respect thereof) that secured (or, under the written arrangements under which the original Lien arose, could secure) the Indebtedness being refinanced or is in respect of property that is the security for a Permitted Lien hereunder; and

(11)

Liens incurred in the ordinary course of business of the Company or any Restricted Subsidiary of the Company with respect to obligations that do not exceed, at the time of incurrence of such Lien, the greater of (a) $250.0 million or (b) 2.5% of ACNTA at any one time outstanding.

“Permitted Refinancing Indebtedness” means any Indebtedness of the Company or any of its Restricted Subsidiaries issued in exchange for, or the net proceeds of which are used to extend, refinance, renew, replace, defease or refund other Indebtedness of the Company or any of its Restricted Subsidiaries (other than intercompany Indebtedness); provided that:

(1)

the principal amount (or accreted value, if applicable) of such Permitted Refinancing Indebtedness does not exceed the principal amount (or accreted value, if applicable) of the Indebtedness being extended, refinanced, renewed, replaced, defeased or refunded (plus all accrued interest on the Indebtedness and the amount of all expenses and premiums incurred in connection therewith);

(2)

such Permitted Refinancing Indebtedness has a final maturity date later than the final maturity date of, and has a Weighted Average Life to Maturity equal to or greater than the Weighted Average Life to Maturity of, the Indebtedness being extended, refinanced, renewed, replaced, defeased or refunded;

(3)

if the Indebtedness being extended, refinanced, renewed, replaced, defeased or refunded is subordinated in right of payment to the notes or the Subsidiary Guarantees, such Permitted Refinancing Indebtedness is subordinated in right of payment to the notes or the Subsidiary Guarantees on terms at least as favorable to the Holders of notes as those contained in the documentation governing the Indebtedness being extended, refinanced, renewed, replaced, defeased or refunded; and

(4)

such Indebtedness is not incurred by a Restricted Subsidiary of the Company if the Company is the obligor on the Indebtedness being extended, refinanced, renewed, replaced, defeased or refunded;

provided, however, that a Restricted Subsidiary that is also a Guarantor may guarantee Permitted Refinancing Indebtedness incurred by the Company, whether or not such Restricted Subsidiary was an obligor or guarantor of the Indebtedness being extended, refinanced, renewed, replaced, defeased or refunded.

Notwithstanding the preceding, any Indebtedness incurred under Credit Facilities pursuant to the covenant described under the caption “—Certain Covenants—Incurrence of Indebtedness and Issuance of Preferred Stock” shall be subject only to the refinancing provision in the definition of Credit Facilities and not pursuant to the requirements set forth in the definition of Permitted Refinancing Indebtedness.

“Person” means any individual, corporation, partnership, joint venture, association, joint-stock company, trust, unincorporated organization, limited liability company or government or other entity.

“Production Payments” means, collectively, Dollar-Denominated Production Payments and Volumetric Production Payments.

“Rating Agency” means each of S&P and Moody’s, or if S&P or Moody’s or both shall not make a rating on the notes publicly available, a nationally recognized statistical rating agency or agencies, as the case may be, selected by the Company (as certified by a resolution of the Board of Directors) which shall be substituted for S&P or Moody’s, or both, as the case may be.

“Rating Decline” means the occurrence of a decrease of one or more gradations (including gradations within rating categories as well as between rating categories) in the rating of the notes by either Rating Agency.

“Reporting Failure” means the failure of the Company to file with the Commission and make available or otherwise deliver to the trustee and each Holder of notes, within the time periods specified in “—Certain Covenants—Reports” (after giving effect to any grace period specified under Rule 12b-25 under the Exchange Act), the periodic reports, information, documents or other reports that the Company may be required to file with the Commission pursuant to such provision.

“Restricted Investment” means an Investment other than a Permitted Investment.

“Restricted Subsidiary” of a Person means any Subsidiary of the referent Person that is not an Unrestricted Subsidiary.

“S&P” refers to Standard & Poor’s Ratings Services, a division of The McGraw Hill Companies, Inc., or any successor to the rating agency business thereof.

“Significant Subsidiary” means any Subsidiary that would be a “significant subsidiary” as defined in Article 1, Rule 1-02 of Regulation S-X, promulgated pursuant to the Securities Act, as such Regulation is in effect on the Issue Date.

“Stated Maturity” means, with respect to any installment of interest or principal on any series of Indebtedness, the date on which the payment of interest or principal was scheduled to be paid in the original documentation governing such Indebtedness, and will not include any contingent obligations to repay, redeem or repurchase any such interest or principal prior to the date originally scheduled for the payment thereof.

“Subsidiary” means, with respect to any specified Person:

(1)

any corporation, association or other business entity (other than a partnership) of which more than 50% of the total voting power of Voting Stock is at the time owned or controlled, directly or through another

Subsidiary, by that Person or one or more of the other Subsidiaries of that Person (or a combination thereof); and

(2)

any partnership (a) the sole general partner or the managing general partner of which is such Person or a Subsidiary of such Person or (b) the only general partners of which are that Person or one or more Subsidiaries of that Person (or any combination thereof), but only if such Person and its Subsidiaries are entitled to receive more than 20% of the assets of such partnership upon its dissolution.

“Subsidiary Guarantee” means any guarantee by a Guarantor of the Company’s payment Obligations under the indenture and on the notes.

“Unrestricted Subsidiary” means any Subsidiary of the Company (other than Whiting Oil and Gas Corporation) that is designated by the Board of Directors as an Unrestricted Subsidiary pursuant to a Board Resolution, but only to the extent that such Subsidiary:

(1)

has no Indebtedness other than Non-Recourse Debt;

(2)

is not party to any agreement, contract, arrangement or understanding with the Company or any Restricted Subsidiary of the Company unless the terms of any such agreement, contract, arrangement or understanding are no less favorable to the Company or such Restricted Subsidiary than those that might be obtained at the time from Persons who are not Affiliates of the Company;

(3)

is a Person with respect to which neither the Company nor any of its Restricted Subsidiaries has any direct or indirect obligation (a) to subscribe for additional Equity Interests or (b) to maintain or preserve such Person’s financial condition or to cause such Person to achieve any specified levels of operating results; and

(4)

has not guaranteed or otherwise directly or indirectly provided credit support for any Indebtedness of the Company or any of its Restricted Subsidiaries.

Any designation of a Subsidiary of the Company as an Unrestricted Subsidiary will be evidenced to the trustee by filing with the trustee the Board Resolution giving effect to such designation and an officers’ certificate certifying that such designation complied with the preceding conditions and was permitted by the covenant described above under the caption “—Certain Covenants—Restricted Payments.” If, at any time, any Unrestricted Subsidiary would fail to meet the preceding requirements as an Unrestricted Subsidiary, it will thereafter cease to be an Unrestricted Subsidiary for purposes of the indenture and any Indebtedness of such Subsidiary will be deemed to be incurred by a Restricted Subsidiary of the Company as of such date and, if such Indebtedness is not permitted to be incurred as of such date under the covenant described under the caption “—Certain Covenants—Incurrence of Indebtedness and Issuance of Preferred Stock,” the Company will be in default of such covenant.

“Volumetric Production Payments” means production payment obligations recorded as deferred revenue in accordance with GAAP, together with all related undertakings and obligations.

“Voting Stock” of any Person as of any date means the Capital Stock of such Person that is at the time entitled (without regard to the occurrence of any contingency) to vote in the election of the Board of Directors of such Person.

“Weighted Average Life to Maturity” means, when applied to any Indebtedness at any date, the number of years obtained by dividing:

(1)

the sum of the products obtained by multiplying (a) the amount of each then remaining installment, sinking fund, serial maturity or other required payments of principal, including payment at final maturity, in respect of the Indebtedness, by (b) the number of years (calculated to the nearest one-twelfth) that will elapse between such date and the making of such payment; by

(2)

the then outstanding principal amount of such Indebtedness.

MATERIAL U.S. FEDERAL INCOME TAX CONSEQUENCES

The following discussion is a summary of the material U.S. federal income tax (and, in the case of certain foreign individuals, estate tax) consequences relevant to the acquisition, ownership, and disposition of the new notes by U.S. Holders and by Non-U.S. Holders (each as defined below). This summary is based upon the Internal Revenue Code of 1986, as amended (the “Code”), Treasury regulations, rulings of the Internal Revenue Service (the “IRS”), and judicial decisions in existence on the date hereof, all of which are subject to change or different interpretations. Any such change could apply retroactively and could affect adversely the tax consequences described below. No assurance can be given that the IRS will agree with the views expressed in this summary, or that a court will not sustain any challenge by the IRS in the event of litigation. No advance tax ruling has been sought or obtained from the IRS regarding the tax consequences of the transactions described herein.

For purposes of this summary, a “U.S. Holder” is a beneficial owner of original notes or new notes that is (a) an individual who is a citizen of the United States or who is resident in the United States for U.S. federal income tax purposes, (b) an entity that is classified for U.S. federal income tax purposes as a corporation and that is organized under the laws of the United States, any state thereof, or the District of Columbia, or is otherwise treated for U.S. federal income tax purposes as a domestic corporation, (c) an estate the income of which is subject to U.S. federal income taxation regardless of its source, or (d) a trust (i) whose administration is subject to the primary supervision of a court within the United States and all substantial decisions of which are subject to the control of one or more United States persons as described in Section 7701(a)(30) of the Code (“United States persons”), or (ii) that has a valid election in effect under applicable Treasury regulations to be treated as a United States person.

For purposes of this summary, a “Non-U.S. Holder” is a beneficial owner of original notes or new notes that is neither a U.S. Holder nor an entity that is classified for U.S. federal income tax purposes as a partnership or as a “disregarded entity”. If an entity classified for U.S. federal income tax purposes as a partnership or as a “disregarded entity” owns new notes, the tax treatment of a member of the entity will depend on the status of the member and the activities of the entity. The tax treatment of such an entity, and the tax treatment of any member of such an entity, are not addressed in this summary. Any entity that is classified for U.S. federal income tax purposes as a partnership or as a “disregarded entity” and that owns original notes or new notes, and any members of such an entity, should consult their tax advisors.

This summary does not discuss all U.S. federal income tax considerations that may be relevant to U.S. Holders and Non-U.S. Holders in light of their particular circumstances or that may be relevant to certain beneficial owners that may be subject to special treatment under U.S. federal income tax law (for example, tax-exempt organizations, insurance companies, banks and other financial institutions, dealers in securities, traders in securities that elect to use a mark-to-market method of accounting, real estate investment trusts, regulated investment companies, individual retirement accounts, qualified pension plans, persons who hold original notes or new notes as part of a straddle, hedging, constructive sale, conversion, or other integrated transaction, persons that purchase or sell new notes as part of a wash sale for tax purposes, U.S. Holders whose functional currency is not the U.S. dollar, controlled foreign corporations, passive foreign investment companies, and corporations that accumulate earnings to avoid U.S. federal income tax). Furthermore, this summary does not discuss any alternative minimum tax consequences, and does not address any aspects of state, local, or foreign taxation. This summary only applies to those beneficial owners that purchase new notes in the initial offering at the initial offering price and that hold new notes as “capital assets” within the meaning of Section 1221 of the Code. In the case of any Non-U.S. Holder who is an individual, this summary assumes that this individual was not formerly a United States citizen, and was not formerly a resident of the United States for U.S. federal income tax purposes.

Treasury regulations provide special rules for the treatment of debt instruments that provide for contingent payments. Under these regulations, a contingency is disregarded if the contingency is remote or incidental, or, in certain circumstances, it is significantly more likely than not that such contingency will not occur. We intend to

take the position that the contingencies on the new notes (for example, your right to require us to purchase the new notes upon a Change of Control, as described under “Description of New Notes—Repurchase at the Option of Holders—Change of Control”) will not cause the “contingent payment debt instrument” rules of the Treasury regulations to apply. A successful challenge of this position by the IRS could affect the timing and amount of income inclusions with respect to the new notes, and could also cause any gain from the sale or other disposition of a new note to be treated as ordinary income rather than as capital gain. Beneficial owners of the new notes should consult their tax advisors regarding the possible application of the contingent payment debt instrument rules to the new notes. The remainder of this summary assumes that the new notes will not be considered to be contingent payment debt instruments.

BENEFICIAL OWNERS OF NEW NOTES ARE HEREBY NOTIFIED THAT: (A) ANY DISCUSSION OF FEDERAL TAX ISSUES IN THIS PROSPECTUS IS NOT INTENDED OR WRITTEN TO BE RELIED UPON, AND CANNOT BE RELIED UPON, BY SUCH BENEFICIAL OWNERS OR ANY OTHER PERSONS FOR THE PURPOSE OF AVOIDING PENALTIES THAT MAY BE IMPOSED ON THEM UNDER THE INTERNAL REVENUE CODE; (B) SUCH DISCUSSION WAS WRITTEN IN CONNECTION WITH THE PROMOTION OR MARKETING (WITHIN THE MEANING OF TREASURY DEPARTMENT CIRCULAR 230) OF THE OFFERING OF THE NEW NOTES OR OTHER MATTERS ADDRESSED HEREIN; AND (C) BENEFICIAL OWNERS OF NEW NOTES ARE ENCOURAGED TO SEEK ADVICE BASED ON THEIR PARTICULAR CIRCUMSTANCES FROM AN INDEPENDENT TAX ADVISOR.

THIS SUMMARY IS INCLUDED FOR GENERAL INFORMATION ONLY AND MAY NOT BE APPLICABLE DEPENDING UPON THE PARTICULAR SITUATION OF A BENEFICIAL OWNER OF NEW NOTES.

Treatment of the Exchange

For U.S. federal income tax purposes, (i) the exchange of original notes for new notes pursuant to the exchange offer will not constitute a taxable event to U.S. Holders or Non-U.S. Holders, (ii) each new note will be treated as a continuation of the corresponding original note, (iii) the initial tax basis of a new note will be the same as the adjusted tax basis of the corresponding original note immediately before the exchange, and (iv) the holding period of a new note will include the holding period of the corresponding original note.

U.S. Holders

Interest

Interest on the new notes generally will be taxable to a U.S. Holder as ordinary interest income (in accordance with the U.S. Holder’s regular method of tax accounting) at the time such income is accrued or received.

Amortizable bond premium

In general, if a U.S. Holder’s initial tax basis in a new note (or, in the case of a new note acquired by the U.S. Holder pursuant to the exchange, if the U.S. Holder’s initial tax basis in the corresponding original note) is greater than the stated redemption price at maturity of the new note, the excess will be treated as “bond premium” for U.S. federal income tax purposes, and a U.S. Holder may elect to amortize the bond premium over the remaining term of the new note on a constant-yield basis as an offset to the interest income on the new note that is taken into account by the U.S. holder under its regular method of tax accounting. However, because the new notes may, under certain circumstances, be redeemed by us at a premium prior to maturity, special rules would apply which could result in a deferral, reduction, or elimination of the amortization of some of the bond premium on a new note.

A U.S. Holder’s tax basis in a new note will be reduced by the amount of bond premium on the new note that is so amortized. If a U.S. Holder does not elect to amortize bond premium, the U.S. Holder will be required to report the full amount of stated interest on the new note as ordinary income, even though the U.S. Hold may be required to recognize a capital loss (which may not be available to offset ordinary income) on a sale or other disposition of the new note.

An election to amortize bond premium applies to all taxable debt instruments acquired by the U.S. Holder on or after the first day of the first taxable year to which such election applies, and may not be revoked without the consent of the IRS. U.S. Holders that hold new notes with bond premium are encouraged to consult their tax advisors regarding the application of these rules.

Sale or other taxable disposition of new notes

In the case of a sale, redemption, retirement, or other taxable disposition of a new note, a U.S. Holder generally will recognize capital gain or loss in an amount equal to the difference between the amount realized on the taxable disposition, other than amounts attributable to accrued but unpaid interest on the new notes (which will be treated as a payment of interest), and the U.S. Holder’s tax basis in such new notes. A U.S. Holder’s tax basis in a new note generally will be equal to the cost of the new note (net of accrued interest) to such U.S. Holder (or, in the case of a new note acquired by the U.S. Holder pursuant to the exchange, the adjusted tax basis in the corresponding original note immediately before the exchange), as reduced by any amortizable bond premium. Any such capital gain or loss generally will be long-term capital gain or loss if the U.S. Holder’s holding period for the new notes is more than one year at the time of disposition. A long-term capital gain recognized by an individual upon a taxable disposition of a new note is generally eligible for reduced rates of U.S. federal income taxation. The deductibility of capital losses is subject to certain limitations.

Unearned Income Medicare Contribution Tax

A 3.8% Medicare contribution tax will be imposed on the “net investment income” of certain United States individuals and on the undistributed “net investment income” of certain estates and trusts (subject to certain thresholds). Among other items, “net investment income” generally includes interest and certain net gain from the disposition of property (such as the new notes), less certain deductions.

Backup withholding and information reporting

In general, information returns will be filed with the IRS in connection with payments on the new notes and the proceeds from a sale or other disposition of the new notes. A U.S. Holder will be subject to backup withholding on these payments if the U.S. Holder fails to provide its taxpayer identification number in the manner required by applicable law, fails to certify that it is not subject to the backup withholding tax, or otherwise fails to comply with applicable backup withholding tax rules.

Any amounts withheld from a U.S. Holder under the backup withholding provisions may be credited against the U.S. federal income tax liability, if any, of the U.S. Holder, and may entitle the U.S. Holder to a refund, provided that the required information is timely furnished to the IRS.

Non-U.S. Holders

Interest earned on a new note by a Non-U.S. Holder will be considered “portfolio interest,” and will not be subject to U.S. federal income tax or withholding, if:

•

the Non-U.S. Holder is neither (i) a “controlled foreign corporation” that is related to us as described in Section 881(c)(3)(C) of the Code, (ii) a bank receiving the interest on a loan made in the ordinary course of its business, nor (iii) a person who owns, directly or under the attribution rules of

Section 871(h)(3)(C) of the Code, 10% or more of the total combined voting power of all classes of our stock entitled to vote;

•

the certification requirements described below are satisfied; and

•

the interest is not effectively connected with the conduct of a trade or business within the United States by the Non-U.S. Holder.

In general, the certification requirements will be satisfied if either (i) the beneficial owner of the new note provides, to the person that otherwise would be required to withhold U.S. tax, a properly completed IRS Form W-8BEN (or a suitable substitute form) that includes the beneficial owner’s name and address and that certifies, under penalties of perjury, that the beneficial owner is not a United States person, or (ii) a securities clearing organization, bank, or other financial institution which holds customers’ securities in the ordinary course of its trade or business holds the new note on behalf of a beneficial owner and provides to the person that otherwise would be required to withhold U.S. tax, a statement certifying under penalties of perjury that an applicable IRS Form W-8BEN (or a suitable substitute form) has been received by it from the beneficial owner, or from another financial institution acting on behalf of the beneficial owner, and furnishes a copy to the person that otherwise would be required to withhold U.S. tax. These certification requirements may be satisfied with other documentary evidence in the case of a new note held through a qualified intermediary.

Any payments to a Non-U.S. Holder of interest that do not qualify for the “portfolio interest” exemption and that are not effectively connected with the conduct of a trade or business (or, if a United States income tax treaty applies, are not attributable to a permanent establishment maintained) within the United States by the Non-U.S. Holder will be subject to U.S. federal income tax and withholding at a rate of 30% (or at a lower rate under an applicable income tax treaty). To claim a reduction or exemption under an applicable income tax treaty, a Non-U.S. Holder must generally submit, to the person that otherwise would be required to withhold U.S. tax, a properly completed IRS Form W-8BEN (or a suitable substitute form).

Any interest earned on a new note that is effectively connected with the conduct of a trade or business (and, if a United States income tax treaty applies, is attributable to a permanent establishment maintained) within the United States by a Non-U.S. Holder will be subject to U.S. federal income tax at regular graduated rates. If the Non-U.S. Holder is classified as a corporation for U.S. federal income tax purposes, such income will also be taken into account for purposes of determining the amount of U.S. branch profits tax, which is imposed at a rate of 30% (or at a lower rate under an applicable income tax treaty) on effectively connected earnings and profits, subject to certain adjustments. However, such effectively connected income will not be subject to U.S. federal income tax withholding, provided that the Non-U.S. Holder furnishes a properly completed IRS Form W-8ECI (or a suitable substitute form) to the person that otherwise would be required to withhold U.S. tax.

Sale or other taxable disposition of new notes

Subject to the discussion below regarding information reporting and backup withholding, any gain recognized by a Non-U.S. Holder upon a sale, redemption, retirement, or other taxable disposition of new notes will not be subject to U.S. federal income tax unless:

•

the gain is effectively connected with the conduct of a trade or business (and, if an applicable United States income tax treaty applies, is attributable to a permanent establishment maintained) within the United States by the Non-U.S. Holder; or

•

in the case of an individual, such individual is present in the United States for 183 days or more during the taxable year in which the gain is realized and certain other conditions are met.

In the case of a Non-U.S. Holder whose gain is described in the first bullet point above, any such gain will be subject to U.S. federal income tax at regular graduated rates, and, if the Non-U.S. Holder is classified as a corporation for U.S. federal income tax purposes, may also be subject to a U.S. branch profits tax, which is

imposed at a rate of 30% (or at a lower rate under an applicable income tax treaty) on effectively connected earnings and profits, subject to certain adjustments.

An individual Non-U.S. Holder described in the second bullet point above will be subject to a flat 30% tax on such gain, which may be offset by U.S. source capital losses even though the individual is not considered a resident of the United States.

Backup withholding and information reporting

The amount of any interest paid to a Non-U.S. Holder with respect to new notes and the amount of any tax withheld, generally must be reported to the IRS and to the Non-U.S. Holder, regardless of whether withholding was required. Copies of the information returns reporting such interest and withholding may also be made available under the provisions of an applicable income tax treaty or agreement to the tax authorities in the country in which the Non-U.S. Holder resides.

Any interest paid to a Non-U.S. Holder with respect to new notes generally will not be subject to backup withholding, provided that the Non-U.S. Holder certifies, under penalties of perjury, on IRS Form W-8BEN or W-8ECI (or a suitable substitute form) that it is not a United States person and certain other conditions are met, or the Non-U.S. Holder otherwise establishes an exemption.

The payment to a Non-U.S. Holder of the proceeds of a disposition of a new note by or through the U.S. office of a broker generally will not be subject to information reporting or backup withholding if the Non-U.S. Holder either certifies, under penalties of perjury, on IRS Form W-8BEN or W-8ECI (or a suitable substitute form) that it is not a United States person and certain other conditions are met, or the Non-U.S. Holder otherwise establishes an exemption. Information reporting and backup withholding generally will not apply to the payment of the proceeds of a disposition of a new note by or through the foreign office of a foreign broker (as defined in applicable Treasury regulations). Information reporting requirements (but not backup withholding) will apply, however, to a payment of the proceeds of the disposition of a new note by or through a foreign office of a U.S. broker or of a foreign broker with certain relationships to the United States, unless the broker has documentary evidence in its records that the holder is not a United States person and certain other conditions are met, or the holder otherwise establishes an exemption.

Any amounts withheld from a Non-U.S. Holder under the backup withholding provisions may be credited against the U.S. federal income tax liability, if any, of the Non-U.S. Holder, and may entitle the Non-U.S. Holder to a refund, provided that the required information is timely furnished to the IRS.

Estate tax consequences

Any new note that is owned (or treated as owned) by an individual who is not a citizen or resident (as specially defined for U.S. federal estate tax purposes) of the United States at the date of death will not be included in such individual’s estate for U.S. federal estate tax purposes, unless the individual owns, directly or indirectly, 10% or more of the voting power of all our stock, or, at the time of such individual’s death, payments in respect of the new notes would have been effectively connected with the conduct by such individual of a trade or business in the United States.

PLAN OF DISTRIBUTION

Each broker-dealer that receives new notes for its own account pursuant to the exchange offer must acknowledge that it will deliver a prospectus in connection with any resale of such new notes. We reserve the right in our sole discretion to purchase or make offers for, or to offer new notes for, any original notes that remain outstanding subsequent to the expiration of the exchange offer pursuant to this prospectus or otherwise and, to the extent permitted by applicable law, purchase original notes in the open market, in privately negotiated transactions or otherwise. This prospectus, as it may be amended or supplemented from time to time, may be used by a broker-dealer in connection with resales of new notes received in exchange for original notes where such original notes were acquired as a result of market-making activities or other trading activities. We have agreed that for a period of 180 days beginning when the new notes are issued, we will make this prospectus, as amended or supplemented, available to any broker-dealer for use in connection with any such resale. In addition, until December 24, 2013, all dealers effecting transactions in the new notes may be required to deliver a prospectus.

We will not receive any proceeds from any sale of new notes by brokers-dealers. New notes received by broker-dealers for their own account pursuant to the exchange offer may be sold from time to time in one or more transactions in the over-the-counter market, in negotiated transactions, through the writing of options on the new notes or a combination of such methods of resale, at market prices prevailing at the time of resale, at prices related to such prevailing market prices or at negotiated prices. Any such resale may be made directly to purchasers or to or through brokers or dealers who may receive compensation in the form of commissions or concessions from any such broker-dealer and/or the purchasers of any such new notes. Any broker-dealer that resells new notes that were received by it for its own account pursuant to the exchange offer and any broker or dealer that participates in a distribution of such new notes may be deemed to be an “underwriter” within the meaning of the Securities Act and any profit on any such resale of new notes and any commissions or concessions received by any such persons may be deemed to be underwriting compensation under the Securities Act. The letter of transmittal states that by acknowledging that it will deliver and by delivering a prospectus, a broker-dealer will not be deemed to admit that it is an “underwriter” within the meaning of the Securities Act.

For a period of 180 days beginning when the new notes are issued, we will promptly send additional copies of this prospectus and any amendment or supplement to this prospectus to any broker-dealer that requests such documents in the letter of transmittal. We have agreed to pay all expenses incident to the exchange offer, other than commissions or concessions of any brokers or dealers and will indemnify the holders of the notes (including any broker-dealers) against certain liabilities, including liabilities under the Securities Act.

WHERE YOU CAN FIND MORE INFORMATION

We file annual, quarterly and current reports, proxy statements and other information with the SEC. We also filed a registration statement on Form S-4, including exhibits, under the Securities Act of 1933 with respect to the new notes offered by this prospectus. This prospectus is a part of the registration statement, but does not contain all of the information included in the registration statement or the exhibits. You may read and copy the registration statement and any other document that we file at the SEC’s public reference room at 100 F Street, N.E., Washington D.C. 20549. You can call the SEC at 1-800-SEC-0330 for further information on the operation of the public reference room. You can also find our public filings with the SEC on the internet at a web site maintained by the SEC located at http://www.sec.gov.

We are “incorporating by reference” specified documents that we file with the SEC, which means:

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incorporated documents are considered part of this prospectus;

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we are disclosing important information to you by referring you to those documents; and

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information we file with the SEC will automatically update and supersede information contained in this prospectus.

We incorporate by reference the documents listed below and any future filings we make with the SEC under Sections 13(a), 13(c), 14 or 15(d) of the Securities Exchange Act of 1934 after the date of this prospectus and before the end of the offering of the securities pursuant to this prospectus:

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our Annual Report on Form 10-K for the year ended December 31, 2012;

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our Quarterly Reports on Form 10-Q for the quarters ended March 31, 2013, June 30, 2013 and September 30, 2013;

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our Current Reports on Form 8-K, dated January 7, 2013, May 7, 2013, June 17, 2013, June 17, 2013, June 22, 2013, June 28, 2013, July 15, 2013, September 6, 2013, September 9, 2013, September 23, 2013, and October 31, 2013; and

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our definitive proxy statement on Schedule 14A filed on March 25, 2013.

Notwithstanding the foregoing, information furnished under Items 2.02 and 7.01 of any Current Report on Form 8-K, including the related exhibits under Item 9.01, is not incorporated by reference in this prospectus.

You may request a copy of any of these filings, at no cost, by request directed to us at the following address or telephone number:

Whiting Petroleum Corporation

1700 Broadway, Suite 2300

Denver, Colorado 80290

(303) 837-1661

Attention: Corporate Secretary

You can also find these filings on our website at www.whiting.com. However, we are not incorporating the information on our website other than these filings into this prospectus.

LEGAL MATTERS

Certain legal matters relating to this offering will be passed upon for us by the law firm of Foley & Lardner LLP.

EXPERTS

The financial statements, and the related financial statement schedule, incorporated in this prospectus by reference from Whiting Petroleum Corporation’s Annual Report on Form 10-K for the year ended December 31, 2012, and the effectiveness of Whiting Petroleum Corporation’s internal control over financial reporting have been audited by Deloitte & Touche LLP, an independent registered public accounting firm, as stated in their reports, which are incorporated herein by reference. Such financial statements and financial statement schedule have been so incorporated in reliance upon the reports of such firm given upon their authority as experts in accounting and auditing.

Certain information with respect to our oil and natural gas reserves derived from the report of Cawley Gillespie & Associates, Inc., an independent petroleum engineering consultant, has been included in this prospectus, and incorporated in this prospectus by reference from Whiting Petroleum Corporation’s Annual Report on Form 10-K for the year ended December 31, 2012.

LOGO

Whiting Petroleum Corporation

Offer to Exchange All Outstanding, Unregistered

$400,000,000 5.750% Senior Notes due 2021 (CUSIP Nos. 966387AJ1 and U9650FAC1)

For New, Registered

$400,000,000 5.750% Senior Notes due 2021 (CUSIP No. 966387AH5)

PROSPECTUS

November 14, 2013