AMERICAN NOBLE GAS, INC. - Annual Report: 2004 (Form 10-K)

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

Commission File No. 0-17204

INFINITY, INC.

(Exact Name of Small Business Issuer as Specified in its Charter)

1401 West Main Street, Suite C, Chanute, Kansas 66720

(Address of Principal Executive Offices, Including Zip Code)

(620) 431-6200

(Registrant’s telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act: None

Securities registered pursuant to Section 12(g) of the Act: Common Stock

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

      Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K, is not contained herein and will not be contained, to the best of Registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.     o

      Indicate by check mark whether the registrant is an accelerated filer (as defined in Rule 12B-2 of the Act).     Yes o          No þ

      The aggregate market value of voting and non-voting common equity held by non-affiliates as of June 30, 2004 was approximately $31,600,000 based upon a closing price of $3.87 per share as reported on the NASDAQ National Market. As of March 23, 2005, 12,632,927 of the Registrant’s $0.0001 par value Common Stock were outstanding.

DOCUMENTS INCORPORATED BY REFERENCE

      Portions of the Registrant’s Definitive Proxy Statement to be filed with the Securities and Exchange Commission pursuant to Regulation 14A in connection with the 2005 Annual Meeting of Shareholders are incorporated by reference in Part III of this Report on Form 10-K.

TABLE OF CONTENTS

FORWARD-LOOKING STATEMENTS

      This report on Form 10-K, including information incorporated by reference, contains forward-looking statements as defined in the Private Securities Litigation Reform Act of 1995. The use of any statements containing the words “anticipate,” “intend,” “believe,” “estimate,” “project,” “expect,” “plan,” “should” or similar expressions are intended to identify such statement. Forward-looking statements include, among other items:

      Forward-looking statements inherently involve risks and uncertainties that could cause actual results to differ materially from the forward-looking statements. Factors that could cause or contribute to such differences include, but are not limited to the following and the risks described in “Risk Factors”:

PART I

GENERAL

      Infinity, Inc. (“Infinity,” or the “Company”) is an independent energy company engaged in the acquisition, exploration, development and production of natural gas and oil in the United States through our wholly-owned subsidiaries, Infinity Oil and Gas of Texas, Inc. (“Infinity-Texas”) and Infinity Oil & Gas of Wyoming, Inc. (“Infinity-Wyoming”). Our current operations are focused in the Fort Worth Basin of North Central Texas and in the Rocky Mountain region in the Greater Green River Basin in Southwest Wyoming and the Sand Wash and Piceance Basins in Northwest Colorado. Infinity is also pursuing an oil and gas exploration opportunity offshore Nicaragua in the Caribbean Sea. In addition, we provide oilfield services in Eastern Kansas, Northeast Oklahoma and Northeast Wyoming through our wholly-owned subsidiary, Consolidated Oil Well Services, Inc. (“Consolidated”).

      From January 1, 2002 through December 31, 2004, we grew our production through exploration and development drilling exclusively in the Rocky Mountain region. During this period, we completed the drilling of 36 oil and gas wells with a success rate of 75% at our two projects in the Greater Green River Basin. Exploratory wells accounted for 25 wells, or 69%, of the total wells we drilled. Our total proved reserves as of December 31, 2004 were an estimated 9.2 billion cubic feet of gas equivalent (“Bcfe”) with a PV-10 Value (as defined below) of $24.0 million (after-tax PV-10 Value of $23.7 million). During 2004, we added approximately 2.8 Bcfe to proved reserves, produced approximately 1.2 Bcfe, and experienced negative revisions of approximately 1.1 Bcfe for a net increase of approximately 0.5 Bcfe.

      Subsequent to December 31, 2004 and through March 23, 2005, we have completed the drilling of an additional six wells (four in the Fort Worth basin, and one each in the Sand Wash and Greater Green River basin). Activities subsequent to December 31, 2004 in the Fort Worth, Sand Wash and Greater Green River Basins were not taken into account in the proved reserve estimate as of December 31, 2004, but may be reflected in future estimates.

      In accordance with our business strategy which is discussed below, we operate 100% of our projects with working interests that range between 50% and 100%.

      Our corporate office is located at 1401 West Main Street, Suite C, Chanute, Kansas 66720. Our telephone number is (620) 431-6200. Our website is http://www.infinity-res.com. The information on the website does not constitute part of this Annual Report on Form 10-K.

      On January 13, 2005, we entered into a securities purchase agreement (the “Senior Secured Notes Facility”) with affiliates of Promethean Asset Management, LLC and Angelo, Gordon & Co., L.P. (collectively, the “Buyers”), pursuant to which Infinity sold, and the Buyers purchased, $30 million aggregate principal amount of senior secured notes (the “Notes”) due January 13, 2009 and five-year warrants to purchase 924,194 shares of common stock at an exercise price of $9.09 per share and 732,046 shares of common stock at an exercise price of $11.06 per share (collectively, the “Warrants”). The Notes have an initial maturity of 48 months subject to extension for an additional twelve months upon the mutual agreement of Infinity and the Buyers. The Notes bear interest at 3-month LIBOR (London Interbank Offered Rate) plus 675 basis points, adjusted the first business day of each calendar quarter. The Notes are secured by essentially all of the assets of Infinity and its subsidiaries and are guaranteed by each of Infinity’s active subsidiaries. The Notes are redeemable by Infinity for cash at any time during the first year at 105% of par value, declining by 1% per year thereafter (101% during any extended maturity period), together with any accrued and unpaid interest. Under certain circumstances, Infinity has the option to repay the Notes with direct issuances of shares of registered common stock in lieu of cash.

      At quarterly intervals and over a three-year period, commencing in the third quarter of 2005, Infinity has the option to sell additional notes (the “Additional Notes”), along with additional warrants, in amounts of up to $15 million in any rolling twelve-month period and up to a maximum of $45 million. The Additional Notes would have an initial maturity of 42 months (54 months if the maturity of the Initial Notes is extended). The issuance of Additional Notes is subject to Infinity’s future satisfaction of various closing conditions. The ability to issue Additional Notes or the requirement to prepay Notes prior to maturity will depend upon a maximum Notes balance calculated quarterly based generally upon a combination of the financial performance of Consolidated and the SEC after-tax PV-10% value of our proved reserves.

      In connection with the issuance of the Notes and Warrants, Infinity also entered into a registrations rights agreement with the Buyers pursuant to which Infinity agreed to file a shelf registration statement covering resales of the ordinary shares issuable upon exercise of the Warrants.

      Infinity used approximately $9.2 million of the proceeds from the sale of the Notes and Warrants to repay all amounts outstanding pursuant to a Loan and Security Agreement between LaSalle Bank N.A. and Consolidated, a Credit Agreement between U.S. Bank National Association and Infinity-Wyoming, and certain other secured lending agreements, and those credit agreements have been terminated. Infinity is using the remainder of the proceeds to pay costs and expenses related to the sale of the Notes and Warrants and to fund its oil and gas exploration and development activities.

      In February 2005, we entered into a definitive agreement for the acquisition of approximately 24,500 gross and net acres in Comanche County in the Fort Worth Basin of Texas, subject to customary closing conditions. The agreement, as amended, also provides for a right of first refusal on all acres acquired by the seller in Comanche County. We expect to close the Comanche transaction on or before April 19, 2005. Upon closing, including acreage previously owned, Infinity-Texas will own and operate approximately 67,500 gross acres (approximately 56,300 acres net to Infinity’s interest) of leasehold in Erath, Hamilton and Comanche Counties, Texas. We believe the Comanche County acreage offers prospective vertical and horizontal drilling and production opportunities, targeting the Barnett Shale and Lower Marble Falls formations. The leased properties are located approximately 30 miles southwest of Infinity-Texas’ existing acreage in Erath and Hamilton Counties, Texas. Infinity-Texas agreed to drill at least one test well on the Comanche acreage during the next twelve months.

      Pursuant to requirements of the Senior Secured Notes Facility, on January 13, 2005, Infinity called for redemption the remaining $2.5 million of 8% Subordinated Convertible Notes due 2006 outstanding on February 28, 2005. During January and February 2005, the holders of all of the 8% subordinated convertible notes converted the debt and accrued interest into 517,296 shares of the Company’s common stock.

      Based on the volume weighted average stock price for Infinity’s common stock from February 18, 2005 to February 24, 2005 and pursuant to requirements of the Senior Secured Notes Facility, on February 25, 2005, Infinity called for redemption the remaining $8.2 million of 7% Subordinated Convertible Notes due 2007 outstanding on April 22, 2005 at a redemption price of 102.8% plus accrued and unpaid interest. During 2005, through March 23, the holders of $5,950,538 of 7% subordinated convertible notes have converted the debt and accrued interest into 783,779 shares of the Company’s common stock. Approximately $5.6 million of principal amount remains outstanding as of March 23, 2005. The Company has cash available to redeem the remaining 7% notes should they not be presented for conversion prior to the redemption date.

      Infinity-Texas is engaged in the acquisition, exploration, development and production of natural gas in the Fort Worth Basin of north central Texas. This subsidiary is a Delaware corporation with its headquarters located in Denver, Colorado.

      Infinity-Texas was formed in June 2004 to acquire, explore, develop and produce natural gas from the Barnett Shale formation and other producing formations in the Fort Worth Basin. The Barnett Shale is a marine shale formation that is natural gas bearing at depths believed to range from 1,000 to 8,500 feet and is believed to be ubiquitous across the Fort Worth Basin. Though this area has been well known for natural gas production for many years, improvements in fracture techniques and the employment of horizontal drilling in recent years have generally improved the economics of producing this reservoir. The reserve profile from productive wells drilled in the Barnett Shale region is shorter-lived compared to the typical reserve profile from wells drilled by Infinity-Wyoming in the Rocky Mountain region. In addition, the predominance of leases in the region relate to fee acreage and therefore have relatively few operating restrictions and regulations, as compared to the typically federally-owned leases in the Rocky Mountain region that involve a higher degree of operating restrictions and regulations.

      At December 31, 2004, Infinity-Texas had no proved reserves or production since no wells had been drilled, completed and hooked up for production at that point. During the three months ended December 31, 2004, Infinity-Texas drilled three gross (2.7 net) wells and completed one gross (0.9 net) well. Subsequent to December 31, 2004, Infinity-Texas has drilled an additional 2 wells (1.9 net) and completed four wells (3.7 net). It is anticipated that the initial wells will be connected to an existing third-party pipeline system during May 2005. Infinity-Texas operates all drilled wells and expects to operate future wells. Operating the oil and gas properties in which it owns an interest allows Infinity-Texas to exercise greater control over operating costs, capital expenditures and the timing of exploration, development and exploitation activities.

      Infinity-Wyoming is engaged in the acquisition, exploration, development and production of natural gas, condensate and crude oil in the Rocky Mountain region in Wyoming and Colorado. This subsidiary is a Wyoming corporation with its headquarters located in Denver, Colorado.

      Infinity-Wyoming was incorporated in January 2000 for the purpose of acquiring properties with the intent of exploring, developing and producing natural gas and coal bed methane. To date, we have developed our proven oil and gas reserves and increased production primarily through acquiring additional oil and gas leaseholds and drilling wells to exploit and develop tight sand properties.

      At December 31, 2004, Infinity-Wyoming had total estimated proved reserves of 9.2 Bcfe with a PV-10 Value of $24.0 million (after-tax PV-10 Value of $23.7 million). This valuation reflected average wellhead prices of $6.07 per thousand cubic feet (“Mcf”) of natural gas and $40.25 per barrel of crude oil at year-end.

      Approximately 97% of our proved oil and gas reserves were associated with tight sand properties on the Wamsutter Arch Pipeline Field in the Greater Green River Basin in Southwest Wyoming (the “Pipeline Field”). The balance of our proved reserves related to one proved undeveloped well location in the Sand Wash Basin in Colorado (the “Sand Wash Prospect”). The proved undeveloped location at the Sand Wash Prospect was drilling at December 31, 2004, was subsequently completed in early 2005, and had an initial flow rate of approximately 150 barrels of oil per day net to the company’s interest. Proved reserves at December 31, 2004 reflect only those quantities associated with a vertical wellbore.

      At December 31, 2004, Infinity-Wyoming operated all of the proved developed oil and gas locations. During the year ended December 31, 2004, Infinity-Wyoming drilled five gross (4.0 net) wells and completed three gross (2.0 net) of such wells. Infinity-Wyoming also completed an additional eight gross (and net) wells drilled during 2003 and prior. Subsequent to December 31, 2004, Infinity-Wyoming finished the drilling of three gross (and net) wells and completion of two of those wells, one each in the Sand Wash and Greater Green River Basins. Operating the oil and gas properties in which it owns an interest allows Infinity-Wyoming to exercise greater control over operating costs, capital expenditures and the timing of exploration, development and exploitation activities.

      During 2004, Infinity-Wyoming produced 1.2 Bcfe of gas, comprised of 1.0 Bcf of natural gas and 34,000 barrels of crude oil. Approximately 98% of this production was from the Pipeline Field and 2% of this production was from the Labarge Field in Big Piney area of the Greater Green River Basin in Wyoming (the “Labarge Field”). Total revenue from product sales totaled $6.3 million, comprised of natural gas sales of $4.9 million, or $5.12 per Mcf, and crude oil sales of $1.4 million, or $41.15 per barrel.

      Since 1999, Infinity has pursued an oil and gas exploration opportunity offshore Nicaragua in the Caribbean Sea. Over such time period, the relationships which have been built with the Instituto Nicaraguense de Energia (“INE”) and the geological and geophysical research that was done allowed Infinity to become one of only six companies qualified to bid on offshore blocks in the first international bidding round held by INE in January 2003. Infinity was awarded the bid on 24 blocks of acreage, comprising approximately 1.4 million acres, in May 2003, and entered into negotiations with INE to finalize the initial exploration and production contract for the two underlying prospects (Tyra and Perlas). Infinity anticipates the completion of the negotiations and execution of the contract during 2005.

      Consolidated acquired assets necessary to provide oilfield services in Eastern Kansas and Northeast Oklahoma in January 1994. Consolidated expanded its operations into Northeast Wyoming during September 1999. Consolidated provides services associated with drilling and completion of oil and gas wells, including cementing, acidizing, fracturing, nitrogen pumping and water hauling. In April 2004, Consolidated expanded its presence in the Mid-Continent region with the acquisition of substantially all of the assets and liabilities of Blue Star Acid Services, Inc., a provider of acid and cementing services in Eastern and Central Kansas and North Central Oklahoma, for $1.2 million in cash and the assumption of $0.2 million in liabilities. In September 2004, Consolidated sold selected assets in Eastern Kansas, including real property and facilities in Chanute, Kansas, to an exploration and production company and customer for $4.1 million in cash. A wholly-owned subsidiary of Infinity, CIS Oklahoma, Inc. (“CIS”), owns the real property and facilities that we occupy in Ottawa and Thayer, Kansas; Bartlesville, Oklahoma; and Gillette, Wyoming and leases its Eureka facility.

BUSINESS STRATEGY

      Our principal objective is to create shareholder value through the execution of a business strategy, the key elements of which include:

      We intend to finance our business strategies through employment of cash on hand, free cash flow from our operations, net proceeds from the sales of assets, and through external debt and equity capital raised in public and private offerings. Essentially all of our assets serve as collateral under the Senior Secured Notes Facility, and as such, any disposition of material assets would require the approval of the Buyers.

RISK FACTORS

      We incurred a net loss in our fiscal years ended December 31, 2004, 2003 and 2002 of approximately $4.6 million, $9.9 million and $1.6 million, respectively. Our history of losses may impair our ability to obtain financing for drilling and other business activities at all or on favorable terms. It may also impair our ability to attract investors if we attempt to raise additional capital, to grow our business or for other business purposes, by selling additional debt or equity securities in a private or public offering.

      Our ability to achieve a profit from operations on a long-term basis will largely depend on whether we are successful in exploring for and producing oil and gas from our existing properties. We face the following potential risks in developing our oil and gas properties:

      Our future oil and gas revenue, operating results, profitability, future rate of growth and the carrying value of oil and gas properties will depend heavily on prevailing market prices for oil and gas. We expect the market for oil and gas to continue to be volatile for the foreseeable future. For the period from January 1, 2004 through December 31, 2004 we received revenue per barrel of oil as low as $33.35 in January 2004 and as high as $52.58 in October 2004. During that period, the Inside FERC, first of the month CIG Index, the pricing index on which our gas sales are based, fluctuated from a low of $4.17 per MMBtu or approximately $4.59 per Mcf in April 2004 to a high of $6.98 per MMBtu or approximately $7.68 per Mcf during November 2004. Based on fourth quarter 2004 production levels, each $1.00 decrease in the price of crude oil would reduce Infinity’s oil revenue by approximately $2,500 per month and if none of the gas produced were being sold under fixed price contracts, each $0.10 decrease in natural gas price would reduce Infinity’s gas revenue by approximately $7,500 per month.

      Revenue generated from oilfield services provided by Consolidated is indirectly affected by the price of oil and gas. Consolidated has historically experienced higher revenue in periods of high oil and gas prices and lower revenue in periods of low oil and gas prices.

      Most of our proved reserves are natural gas. Therefore, the volatility in the price of natural gas will have the greatest impact on our operations. Various factors beyond our control affect prices of oil and gas, including:

      These external factors and the volatile nature of the energy markets generally make it difficult to estimate future prices of oil and gas. Significant declines in oil and natural gas prices for an extended period may cause various negative effects on our business, including:

      A charge to earnings and book value would occur if there is a further ceiling write-down of the carrying value of Infinity’s oil and gas properties. Impairments can occur when oil and gas prices are depressed or unusually volatile. Once incurred, a ceiling write-down of oil and gas properties is not reversible at a later date when better industry conditions may exist. We review, on a quarterly basis, the carrying value of our oil and gas properties under the full cost accounting rules of the SEC. Under these rules, costs of proved oil and gas properties may not exceed the present value of estimated future net revenue adjusted for future cash flows related to asset retirement obligations from proved reserves, after giving effect to cash flow from hedges, discounted at 10%, net of taxes. Application of the ceiling test generally requires pricing future revenue at the unescalated prices in effect as of the end of each fiscal quarter, after giving effect to Infinity’s cash flow hedge positions, if any, and requires a write-down for accounting purposes if the ceiling is exceeded, even if prices were depressed for only a short period of time.

      At December 31, 2004, the carrying amount of oil and gas properties subject to amortization exceeded the full cost ceiling limitation by approximately $8,900,000 based upon a natural gas price of approximately $6.07 per Mcf and an oil price of approximately $40.25 per barrel in effect at that date. However, due to significant subsequent price increases to approximately $6.53 per Mcf of gas and $54.55 per barrel of oil at the March 15, 2005 measurement date, the Company was only required to record a ceiling writedown of $4,100,000 in the quarter and year ended December 31, 2004. In 2003, the Company recorded a ceiling writedown of $2,975,000. A decrease in oil or gas prices, which continue to remain volatile, an increase in production costs, a decrease in estimated gas production in future periods, or the reclassification of development costs to properties subject to depletion without an increase in associated proved reserves could result in a ceiling write-down during future periods.

      The prices to be received for the natural gas production from our Wyoming, Colorado and Texas properties will be determined mainly by factors affecting the regional supply of and demand for natural gas, which include the degree to which pipeline and processing infrastructure exists in the region. Based on recent experience, regional differences could cause a negative basis differential of between $0.30 per Mcf and $1.50 per Mcf in Wyoming between the published indices generally used to establish the price received for regional natural gas production and the actual price received by us for our natural gas production.

      To manage our exposure to price risks in the marketing of our natural gas, we enter into natural gas fixed price physical delivery contracts from time to time with respect to a portion of our current or future production. These transactions could limit our potential gains if natural gas prices were to rise substantially over the price established by the contracts. In addition, such transactions may expose us to the risk of financial loss in certain circumstances, including instances in which:

      Full exploration and development of Infinity’s properties could require drilling in excess of 1,000 production wells, 100 disposal wells to handle produced water, and the construction of 100 production facilities. This could require capital expenditures over time of in excess of $1 billion. Currently, our potential sources of financing for these activities are cash generated by operations, future sales of equity securities or subordinated debt securities, obtaining additional subordinated debt financing or the sale of additional senior secured debt securities under the terms of an existing securities purchase agreement. Under that agreement, we can borrow up to $15 million per twelve-month period for the next three years, commencing in the third quarter of 2005, depending on our satisfaction of certain closing conditions and on our maximum balance of notes outstanding, based generally on a combination of performance of Infinity’s oilfield service business and the after-tax PV-10 Value of Infinity’s proved reserves.

      Future cash flows and the availability of financing are subject to a number of variables, such as:

      Issuing equity securities to satisfy our financing or refinancing requirements could cause substantial dilution to existing shareholders. Debt financing could lead to:

      In order to reduce our capital needs, while continuing development of our oil and gas projects, we could enter into partnerships with another oil and gas company or companies in which we would maintain a carried or reduced working interest in the oil and gas properties. However, this would reduce our ownership and control over the projects and could significantly reduce our future revenue generated from gas production.

      If projected revenue were to decrease due to lower oil and natural gas prices, decreased production or other reasons, and if we were not able to obtain the necessary capital, our ability to execute development plans or maintain production levels could be limited.

      Our Senior Secured Notes Facility is secured by a pledge of substantially all of our natural gas and oil properties and oilfield services business assets, is guaranteed by our subsidiaries and contains covenants that limit additional borrowings, dividends to shareholders, the incurrence of liens, investments, sales or pledges of assets, changes in control and other matters. The Senior Secured Notes Facility also requires that specified financial ratios be maintained. The restrictions of our Senior Secured Notes Facility may have adverse consequences on our operations and financial results including:

      As of March 23, 2005, we had total long-term debt of approximately $37.8 million. Our level of debt could have important negative consequences to our business.

      We may not be able to refinance our debt or obtain additional financing, particularly in view of the restrictions imposed by our Senior Secured Notes Facility on our ability to incur other debt and the fact that substantially all of our assets are currently pledged to secure obligations under that facility. Our overall level of long-term debt and our difficulty in obtaining additional debt financing may have adverse consequences on our operations and financial results including:

      There are numerous uncertainties inherent in estimating quantities of proved oil and natural gas reserves and their values. Actual production, revenue and reserve expenditures will likely vary from estimates.

      Estimates of oil and natural gas reserves are projections based on available geologic, geophysical, production and engineering data. There are uncertainties inherent in the manner of producing and the interpretation of this data as well as the projection of future rates of production and the timing of development

expenditures. Estimates of economically recoverable oil and natural gas reserves and future net cash flows necessarily depend upon a number of factors including:

      The most accurate method of determining proved reserve estimates is based upon a decline analysis method, which consists of extrapolating future reservoir pressure and production from historical pressure decline and production data. The accuracy of the decline analysis method generally increases with the length of the production history. Since our wells in Texas will begin producing this year, other (generally less accurate) methods such as volumetric analysis and analogy to the production history of wells of other operators in the same reservoir will be used, in conjunction with the decline analysis method to determine our estimates of proved reserves. As our wells are produced over time and more data is available, the estimated proved reserves will be redetermined on an annual basis and may be adjusted based on that data.

      Actual future production, gas and oil prices, revenues, taxes, development expenditures, operating expenses and quantities of recoverable gas and oil reserves most likely will vary from our estimates. Any significant variance could materially affect the quantities and present value of our reserves. In addition, we may adjust estimates of proved reserves to reflect production history, results of exploration and development and prevailing gas and oil prices. Our reserves may also be susceptible to drainage by operators on adjacent properties.

      In addition, investors should not construe the present value of future net cash flows as the current market value of the estimated oil and natural gas reserves attributable to our properties. The estimated discounted future net cash flows from proved reserves are based on prices and costs as of the date of the estimate, in accordance with applicable regulations, whereas actual future prices and costs may be materially higher or lower. Factors that will affect actual future net cash flows include:

      As a result of these and other factors, we will be required to periodically reassess the amount of our reserves, which may require us to recognize a ceiling write-down of our oil and gas properties. Such factors could cause us to write down the value of our properties in future periods.

      As of December 31, 2004, Infinity-Wyoming had approximately $6.9 million invested in unproved oil and gas properties not subject to amortization on its Labarge Field. During 2004, Infinity-Wyoming performed completion or recompletion operations on five wells in the Labarge Field.

      For the period ended December 31, 2005, or during 2006, a portion of the investment in unproved oil and gas properties may be reclassified to the full cost pool subject to depletion and the ceiling test, following our required periodic evaluation of the fair value of our unproved properties. The amount of any such reclassification could be significant. We could be required to write down a portion of the full cost pool of oil and gas properties subject to amortization upon reclassification of the unproved oil and gas property costs.

      The business of exploring for and developing oil and gas properties is an activity that involves a high degree of business and financial risk. Property acquisition decisions generally are based on assumptions about the quantity, quality, production costs, marketability, and sales price for the acreage or reserves being

acquired. Although available geological and geophysical information can provide information about the potential of a property, it is impossible to predict accurately the ultimate production potential, if any, of a particular property or well. Any decision to acquire a property is also influenced by our subjective judgment as to whether we will be able to locate the reserves, drill and equip the wells to produce the reserves, operate the wells economically, and market the production from the wells.

      Our operations are dependent upon the availability of certain resources, including drilling rigs, steel casing, water, chemicals, and other materials necessary to support our development plans and maintenance requirements. The lack of availability of one or more of these resources at an acceptable price could have a material adverse affect on our business.

      The successful completion of an oil or gas well does not ensure a profit on investment. A variety of factors may negatively affect the commercial viability of any particular well, including:

      In addition, market-related factors may cause a well to become uneconomic or only marginally economic, such as:

      The oil and natural gas business involves operating hazards, any of which could cause substantial losses, such as:

      As protection against operating hazards, we maintain insurance coverage against some, but not all, potential losses. This insurance has deductibles or self-insured retentions and contains certain coverage exclusions. Our insurance premiums can be increased or decreased based on the claims made by us under insurance policies. The insurance does not cover damages from breach of contract by us or based on alleged fraud or deceptive trade practices. Whenever possible, we obtain agreements from customers that limit our liability; however, insurance and customer agreements do not provide complete protection against losses and risks and losses could occur for uninsurable or uninsured risks, or in amounts in excess of existing insurance

coverage. The occurrence of an event that is not fully covered by insurance could harm our financial condition and results of operations.

      In addition, we may be liable for environmental damage caused by previous owners of property we own or lease. As a result, we may face substantial potential liabilities to third parties or governmental entities that could reduce or eliminate funds available for exploration, development or acquisitions or cause us to incur losses. An event that is not fully covered by insurance — for instance, losses resulting from pollution and environmental risks that are not fully insured — could cause us to incur material losses.

      In general, the volume of production from natural gas and oil properties declines as reserves are depleted, with the rate of decline depending on reservoir characteristics. Except to the extent we conduct successful exploration and development activities or acquire properties containing proved reserves, or both, our proved reserves will decline as reserves are produced. Our future natural gas and oil production is, therefore, highly dependent on our level of success in finding or acquiring additional reserves. The business of exploring for, developing or acquiring reserves is capital intensive. Recovery of our reserves, particularly undeveloped reserves, will require significant additional capital expenditures and successful drilling operations. To the extent cash flow from operations is reduced and external sources of capital become limited or unavailable, our ability to make the necessary capital investment to maintain or expand our asset base of natural gas and oil reserves would be impaired.

      Exploratory drilling involves numerous risks, including the risk that we will not find commercially productive natural gas or oil reservoirs. The cost of drilling, completing and operating wells is often uncertain, and a number of factors can delay or prevent drilling operations, including:

      Our future drilling activities may not be successful, and we cannot be sure of our overall drilling success rate. Unsuccessful drilling activities would result in significant expenses being incurred without any financial gain.

      The marketability of gas production will depend in part on the availability, proximity and capacity of pipeline systems owned by third parties. We generally deliver natural gas through gas gathering systems and gas pipelines that we do not own under interruptible or short-term transportation agreements. The transportation of our gas may be interrupted due to capacity constraints on the applicable system, for maintenance or repair of the system. Our ability to produce and market natural gas on a commercial basis could be harmed by any significant change in the cost or availability of markets, systems or pipelines.

      Federal, state and local authorities extensively regulate the oil and gas industry and the drilling and completion of oil and gas wells. Legislation and regulations affecting the industry are under constant review for amendment or expansion, raising the possibility of changes that may adversely affect, among other things, the pricing, production or marketing of oil and gas and oilfield services. Noncompliance with statutes and regulations may lead to substantial penalties and the overall regulatory burden on the industry increases the cost of doing business and, in turn, decreases profitability. Federal, state and local authorities regulate various aspects of oil and gas drilling, service and production activities, including the drilling of wells through permit and bonding requirements, the spacing of wells, the unitization or pooling of oil and gas properties, environmental matters, safety standards, the sharing of markets, production limitations, plugging and abandonment, and restoration.

      Our operations are subject to complex and constantly changing environmental laws and regulations adopted by federal, state and local government authorities. Infinity estimates it will spend approximately $1.0 million to drill and equip one water disposal well to handle water produced from gas wells in 2005. It costs Infinity approximately $50,000 per year to operate each disposal well. In addition to the environmental costs that will be incurred by our oil and gas production operations, Consolidated will incur an estimated $50,000 in costs associated with operating within current environmental regulations this fiscal year. New laws or regulations, or changes to current requirements, could result in our incurring significant additional costs. We could face significant liabilities to government and third parties for discharges of oil, natural gas or other pollutants into the air, soil or water, and we could have to spend substantial amounts on investigations, litigation and remediation.

      Although we believe that we are in substantial compliance with all applicable laws and regulations, we cannot be certain that existing laws or regulations, as currently interpreted or reinterpreted in the future, or future laws or regulations, will not harm our business, results of operations and financial condition. Laws and regulations applicable to us include those relating to:

      Under these laws and regulations, we could be liable for:

      Any noncompliance with these laws and regulations could subject us to material administrative, civil or criminal penalties or other liabilities.

      Our oilfield service operations routinely involve the handling of significant amounts of waste materials, some of which are classified as hazardous substances. Our operations and facilities are subject to numerous environmental laws, rules and regulations, including laws concerning:

      Compliance with and violations of laws protecting the environment may become more costly. Sanctions for failure to comply with these laws, rules and regulations, many of which may be applied retroactively, may include:

      In the United States, environmental laws and regulations typically impose strict liability. Strict liability means that in some situations we could be exposed to liability for cleanup costs and other damages as a result of our conduct, even if such conduct was lawful at the time it occurred, or as a result of the conduct of prior operators or other third parties. Cleanup costs, natural resource damages and other damages arising as a result of environmental laws and regulations, and costs associated with changes in environmental laws and regulations, could be substantial. From time to time, claims have been made against us under environmental laws. Changes in environmental laws and regulations may also negatively impact other oil and natural gas exploration and production companies, which in turn could reduce the demand for our oilfield services.

      Large volumes of water produced from coalbed methane wells and discharged onto the surface in the Powder River Basin of Wyoming have drawn the attention of government agencies, gas producers, citizens and environmental groups which may result in new regulations for the disposal of produced water. Infinity intends to use injection wells to dispose of water into underground rock formations at certain of its fields and intends to discharge onto the surface where permissible. If our wells produce water of lesser quality than allowed under Colorado, Texas or Wyoming state law for surface discharge or injection into underground rock formations, Infinity could incur costs of up to $7.50 per barrel of water to dispose of the produced water. At December 2004 production rates, this would cost us an additional $100,000 per month in average water disposal costs. If our wells produce water in excess of the limits of its disposal facilities, we may have to drill additional disposal wells. Each additional disposal well could cost us up to $1.0 million.

      We operate in the highly competitive areas of oil and natural gas exploration, exploitation, acquisition, production and oilfield services with many other companies. We face intense competition from a large number of independent companies as well as major oil and natural gas companies in a number of areas such as:

      Many of our competitors have financial and technological resources substantially exceeding those available to us. Many oil and gas properties are sold in a competitive bidding process in which we may lack technological information or expertise or financial resources available to other bidders. We cannot be sure that we will be successful in acquiring and developing profitable properties in the face of this competition.

      Because of our small size, growth in accordance with our business plans, if achieved, will place a significant strain on our financial, technical, operational and management resources. As we expand our activities and increase the number of projects we are evaluating or in which we participate, there will be additional demands on our financial, technical and management resources. The failure to continue to upgrade our technical, administrative, operating and financial control systems or the occurrence of unexpected expansion difficulties, including the recruitment and retention of experienced managers, geoscientists and engineers, could have a material adverse effect on our business, financial condition and results of operations and our ability to timely execute our business plan.

      The loss of key members of our management team, or difficulty attracting and retaining experienced technical personnel, could reduce our competitiveness and prospects for future success. Our success depends on the continued services of our executive officers and a limited number of other senior management and technical personnel. Loss of the services of any of these people could have a material adverse effect on our operations. We currently maintain “key man” life insurance on the lives of Stanton E. Ross and Stephen D. Stanfield in the amount of $250,000 each. We do not have employment agreements with any of our executive officers. Our exploratory drilling success and the success of other activities integral to our operations will depend, in part, on our ability to attract and retain experienced explorationists, engineers and other professionals. Competition for experienced explorationists, engineers and some other professionals is extremely intense. If we cannot retain our technical personnel or attract additional experienced technical personnel, our ability to compete could be harmed.

SIGNIFICANT PROJECT AND PROSPECT AREAS

      This section is an explanation and detail of some of the relevant project groupings from our overall inventory of projects and prospects. Our operations are focused primarily in Fort Worth Basin of Texas and the Greater Green River and Sand Wash Basins in the Rocky Mountain region. Our other area of interest is in the Caribbean Sea, offshore Nicaragua.

      For purposes of presentation, we divide our Fort Worth Basin operations into two main property areas: Erath and Hamilton Counties, Texas and Comanche County, Texas.

      At December 31, 2004, Infinity-Texas held leases on approximately 32,000 gross (approximately 27,000 net) acres in this area located in the southwest portion of the Fort Worth Basin in North Central Texas. Infinity-Texas currently seeks to explore for, develop and produce natural gas and natural gas liquids from the Barnett Shale, and possibly shallower formations. At March 23, 2005, Infinity-Texas operates five gross (4.6 net) wells in the area, all of which have been completed and are waiting installation of gathering and flow lines and hookup to a third-party pipeline system. Infinity-Texas has an average 90% working interest and 72% net revenue interest in the acreage in this area.

      Infinity-Texas expects to begin production from its initial wells as early as late April 2005. Based on initial drilling and completion efforts, Infinity-Texas has reserved a drilling rig as early as June 2005 and currently expects to drill approximately one horizontal well per month with accompanying completion operations to follow the drilling. Infinity-Texas also plans to drill a water disposal well in the area during 2005. Infinity-Texas believes it has a multi-year drilling inventory available to it in this area, adjusting for and reflective of spacing requirements and surface or lease restrictions. Dependent upon the success of early operations in 2005, Infinity-Texas may elect to accelerate drilling and completion operations in the area in 2006.

      In February 2005, Infinity-Texas signed a definitive agreement for the acquisition of leases on approximately 24,500 gross (and net) acres in this area, located approximately 30 miles southwest of the Erath and Hamilton County properties. The agreement, as amended, also provides for a right of first refusal on most of the acres acquired by the seller in Comanche County. We expect to close the Comanche transaction on or before April 19, 2005. Upon closing, Infinity-Texas expects to explore for natural gas and natural gas liquids from the Barnett Shale and Lower Marble Falls formations at varying depths between 2,400 and 2,700 feet. Infinity-Texas has a 100% working interest and 80% net revenue interest in the acreage in this area.

      Infinity-Texas agreed to drill at least one test well on the Comanche acreage during the next twelve months. Dependent upon the availability of drilling rigs and other support equipment, Infinity-Texas expects to commence drilling operations during the second half of 2005.

      For purposes of presentation, we divide our Greater Green River Basin operations into two main property areas: Pipeline Field and Labarge Field.

      At December 31, 2004, Infinity-Wyoming held leases on approximately 22,000 gross acres (approximately 19,000 net acres) located on the Wamsutter Arch in the Greater Green River Basin of Southwest Wyoming. Infinity-Wyoming currently seeks to exploit hydrocarbons in the cretaceous-aged Upper Almond sand at varying depths between 2,800 and 3,600 feet. At December 31, 2004, Infinity-Wyoming operated

40 wells in the field, of which 19 were active producers, 13 were shut-in, one was waiting completion operations, three were water disposal wells, and four were waiting plugging and abandonment.

      During 2004, Infinity-Wyoming produced approximately 929,800 Mcf of natural gas and 33,700 barrels of crude oil, or 1,131,800 thousand cubic feet of natural gas equivalent (“Mcfe”) from the field, compared to 1,051,200 Mcf of natural gas and 57,400 barrels of crude oil, or 1,395,700 Mcfe from the field during 2003. Production during 2004 represented a 19% decrease from 2003. Production has generally declined since peaking in the quarter ended March 31, 2003, when production reached 408,100 Mcfe.

      Infinity-Wyoming plans to drill up to seven additional well locations in the field during 2005, subject to rig availability and the completion of an ongoing federal environmental assessment. Infinity-Wyoming believes it may have up to an additional 20 drilling locations available to drill, including the planned wells for 2005.

      At December 31, 2004, Infinity-Wyoming held leases on approximately 12,000 gross (and 11,000 net) acres located on the northern extension of the Moxa Arch in Southwest Wyoming and held options on an additional approximately 18,000 gross acres. Infinity-Wyoming currently seeks to exploit hydrocarbons in the Cretaceous Upper Mesaverde coals at varying depths between 3,400 and 4,200 feet. At December 31, 2004, Infinity-Wyoming operated 12 wells in the field, of which five were active producers, five were shut-in, and two were water disposal wells.

      Infinity-Wyoming produced approximately 24,000 Mcf of natural gas from the field during 2004, as compared to approximately 29,000 Mcf of natural gas during 2003. Production during 2004 represented a 17% decrease as compared to 2003. Production has generally declined since peaking in the quarter ended September 30, 2002, when production reached 20,600 Mcfe. Production at Labarge has continued to be uneconomic, despite modest completion and recompletion efforts in 2004 to re-establish economic production. The completed and recompleted wells from 2004 continue to undergo dewatering operations, which may increase the level of gas production.

      Infinity-Wyoming is subject to an ongoing Bureau of Land Management environmental impact study (“EIS”) on the Labarge Field federal acreage. The EIS must be completed before Infinity-Wyoming can continue development of the acreage. The EIS was commenced in 2002 and was originally anticipated to be completed in six to eight months. Infinity-Wyoming currently anticipates that the EIS will be completed during 2005. Depending on the results of dewatering and and the availability of equipment, we may commence drilling and completion activities during the fourth quarter of 2005.

      For purposes of presentation, we divide our Northwest Colorado operations into two main property areas: Sand Wash Prospect and Piceance Basin Prospect.

      At December 31, 2004, Infinity-Wyoming held leases on approximately 104,000 gross acres (approximately 67,000 net acres) located in the Sand Wash Basin of Northwest Colorado and South Central Wyoming. Infinity-Wyoming currently seeks to explore and develop hydrocarbons in the fractured Niobrara calcareous shale between 5,500 and 6,500 feet. Secondary objectives include exploiting the Williams Fork and Iles coals at varying depths between 2,500 and 3,000 feet. Infinity-Wyoming continues to seek offers from other industry operators for interests in the acreage in exchange for cash and a carried interest in drilling operations. No assurance can be given that any such transactions will be consummated.

      At December 31, 2004, Infinity-Wyoming operated four shut-in wells in the field which were completed in the coals. Drilling was in progress at one fractured Niobrara proved undeveloped location, which was subsequently completed as a producer in February 2005.

      Infinity-Wyoming plans to drill one additional well targeting the fractured Niobrara shale during 2005, subject to rig availability, and conduct additional geological and geophysical studies to identify potential additional locations. As it pertains to the Williams Fork and Iles coals, Infinity-Wyoming suspended dewatering efforts of two wells at the original pilot location in 2004 due to the onset of winter and the resultant substantial production of ice on the surface. No measurable gas production was achieved during 2004. Infinity-Wyoming will evaluate the results of the dewatering process during 2004 prior to determining what additional operations, if any, to perform.

      At December 31, 2004, Infinity-Wyoming held leases on approximately 20,000 gross and net acres in the northeastern corner of the Piceance Basin in Northwest Colorado. Infinity-Wyoming originally sought to exploit the Williams Fork and Iles coals at varying depths between 1,000 and 3,000 feet. Under the terms of the lease agreement covering a substantial portion of the acreage, Infinity-Wyoming is required to drill and complete five wells by November 20, 2005, or relinquish the acreage to the seller. Infinity-Wyoming drilled one pilot wireline coring well during 2004 and the results of the ensuing core analysis and gas desorption analysis indicated coalbed methane gas content in the coals was below the level believed by management to be commercial. In 2005, Infinity-Wyoming expects to re-evaluate its plans to explore for coalbed methane or other potential conventional and deeper formation targets at this prospect. Management believes it is unlikely that the drilling commitments will be met during 2005.

      Since being awarded the two concessions in 2003, Infinity has negotiated a number of key terms and conditions of the exploration and production contract covering the approximate 1.4 million acre Tyra (approximately 823,000 acres in the north) and Perlas (approximately 566,000 acres in the south) concession areas offshore Nicaragua. The contract as currently negotiated, contemplates an exploration period of up to six years with four sub-phases and a production period of up to 30 additional years (with a potential five year extension). The contract is in final negotiations and is expected to be executed in 2005, following final approvals by the Nicaraguan government. Upon execution, the initial capital costs during the first twelve months, for which Infinity would post a performance bond, are expected to be up to approximately $800,000, with up to an additional $1,600,000 during the second twelve months, to cover costs of environmental studies, geological and geophysical analysis, acquisition of seismic data and other operational expenses.

      Exploration offshore Nicaragua will focus on Eocene and Cretaceous carbonate reservoirs and Infinity’s management and consultants believe: (i) numerous analogies can be made between the Infinity concession block and production from fractured Cretaceous carbonates in Mexico, Venezuela and Guatemala and (ii) the presence of Cretaceous source rocks onshore Honduras and Nicaragua can be projected into the offshore Caribbean Shelf. Infinity plans to seek offers from another industry operator or operators for interests in the acreage in exchange for cash and a carried-interest in exploration and development operations. No assurance can be given that any such transactions will be consummated.

      In February 2000, Infinity Oil and Gas of Kansas, Inc. (“Infinity-Kansas”) acquired a 100% working interest in a property in Eastern Kansas, through a joint venture with an operator in which a former director of Infinity is a partner and operations manager. Infinity-Kansas’ total investment in the property was approximately $1,100,000. In addition, Infinity-Kansas had an active oil lease in the Owl Creek Field in Woodson County, Kansas which was acquired for $510,000. Effective May 1, 2002, Infinity-Kansas sold its interest in oil and gas properties in Eastern Kansas for $180,000 cash and a $1,620,000 note receivable due in May 2005. The issuer of the note has the option to return the underlying interests to Infinity-Kansas in lieu of repaying the note receivable. Infinity-Kansas does not anticipate the return of the underlying interests based on its belief that the value of these interests currently exceeds the balance of the note receivable. Infinity-Kansas does not currently have any material investment in any other oil and gas prospects.

OILFIELD SERVICES

      Consolidated provides numerous services associated with drilling and completion of oil and gas wells, including cementing, acidizing, fracturing, nitrogen pumping and water hauling. Consolidated provides these services out of service facilities it owns or leases in Ottawa, Eureka, and Thayer, Kansas; Bartlesville, Oklahoma; and Gillette, Wyoming. Due to the decrease in the number of wells being drilled and the schedule on which wells would be drilled by Infinity-Wyoming and an increase in service requests and equipment demand in other services areas, Consolidated closed its Rock Springs, Wyoming facility, terminated its lease on the operating facilities and transferred its service equipment to its other locations in December 2003. In April 2004, Consolidated expanded its presence in Mid-Continent region with the acquisition of substantially all of the assets and liabilities of Blue Star Acid Services, Inc., a provider of acid and cementing services in Eastern and Central Kansas and North Central Oklahoma, for $1.2 million in cash and the assumption of $0.2 million in liabilities. In September 2004, Consolidated sold selected assets from its Chanute, Kansas location, including real property and facilities, to an exploration and production company and customer, for $4.1 million in cash.

      Consolidated operates a fleet of approximately 100 vehicles specifically designed to provide service to oil and gas well operators working at depths ranging from 100 to 5,000 feet, as is usually the case in Eastern Kansas, Northeast Oklahoma, and for coal bed methane development in the Powder River Basin of Wyoming. The service vehicles are part of the collateral for the Senior Secured Note Facility closed in January 2005.

      Consolidated leases property near Cheyenne, Wyoming, which is the site of the brine water treatment facility. Rent on this land lease is $1,000 per year. The lease is for a term of twenty five years beginning July 1994, but may be terminated by Consolidated at any time on written notice. In February of 2003 Consolidated signed a letter of intent to sell these facilities and transfer the lease on the property to the new owner. However, the potential purchaser to the letter of intent was unable to finance the acquisition and the sale has not been completed. Consolidated is working with the potential purchaser to identify a structure which will allow the sale to be completed. We do not know when or if the sale might be completed.

      Infinity-Wyoming engaged Netherland, Sewell & Associates, Inc., independent petroleum engineers, to prepare estimates of proved reserves, projected future production and related future net revenue for our properties as of December 31, 2004 and 2003. Estimates prepared by Netherland, Sewell & Associates, Inc. were based upon review of production histories and other geologic, economic, ownership, volumetric and engineering data. In estimating reserve quantities that are economically recoverable, oil and gas prices and estimated development and production costs as of December 31, 2004 were utilized. Activity subsequent to December 31, 2004 in the Fort Worth, Sand Wash and Greater Green River Basins was not taken into consideration in the proved reserve estimate as of December 31, 2004, but may be reflected in future estimates.

      The following table sets forth estimates as of December 31, 2004 derived from the Netherland, Sewell & Associates, Inc. reserve report. The present value (discounted at 10 percent) of estimated future net revenue before income taxes (“PV-10 Value”) shown in the table is not intended to represent the current market value of our estimated proved oil and gas reserves. For additional information concerning the present value of future net revenue from these proved reserves, see Note 19- Supplemental Oil and Gas Information (Unaudited) in the Notes to the Consolidated Financial Statements.

      There are numerous uncertainties inherent in estimating quantities of proved reserves and in projecting future rates of production and timing of development expenditures, including many factors beyond the control of the producer. The reserve data set forth herein represents only estimates. Reserve engineering is a subjective process of estimating underground accumulations of oil and gas that cannot be measured in an exact way, and the accuracy of any reserve estimate is a function of the quality of available data and of engineering and geological interpretation and judgment and the existence of development plans. In addition, results of drilling, testing and production subsequent to the date of an estimate may justify revision of such estimate. Accordingly, the reserve estimates are often different from the quantities of oil and gas that are ultimately recovered. Further, the estimated future net revenue from proved reserves and the present value thereof are based upon certain assumptions, including future geologic success, prices, production levels and costs that may not prove correct. Predictions about prices and future production levels are subject to great uncertainty and the meaningfulness of such estimates is highly dependent upon the accuracy of the assumptions upon which they are based. Oil and gas prices have fluctuated widely in recent years. There is no assurance that prices will not be materially higher or lower than the prices utilized in estimating the reserves.

      The weighted average sales prices utilized for purposes of estimating our proved reserves and future net revenue therefrom as of December 31, 2004 were $6.07 per Mcf of natural gas and $40.25 per barrel of crude oil.

      The following table sets forth Infinity’s net oil and gas production, average sales prices, and costs and expenses associated with such production during the years indicated.

      Infinity owned 24 gross (22 net) producing wells and 5 gross (5 net) service wells as of December 31, 2004. Infinity owned an additional 28 gross (27.7 net) wells which were shut in, waiting completion or plugging and abandonment operations as of December 31, 2004.

      The following table sets forth certain information regarding the gross costs incurred in the purchase of proved and unproved properties and in development and exploration activities.

      The following table sets forth certain information regarding the wells completed during the years indicated. Frequently wells are spud or drilled in one period and completed in a subsequent period. In the table, “gross” refers to the total wells in which we have a working interest and “net” refers to gross wells multiplied by our working interest therein.

      As of December 31, 2004, Infinity had an additional nine wells which were awaiting completion, including five wells waiting plugging and abandonment operations and four which were completed as producers by March 23, 2005.

      The following table sets forth the gross and net acres of developed and undeveloped oil and gas leases held by Infinity-Texas and Infinity-Wyoming as of December 31, 2004. Developed acreage is acreage assigned to producing wells for the spacing unit of the producing formation.

      Infinity-Wyoming held options on an additional approximately 18,000 gross acres in the Labarge field as of December 31, 2004. The table does not reflect any reclassification of our acreage to reflect the wells completed by Infinity-Texas and Infinity-Wyoming after December 31, 2004.

      Infinity-Wyoming sells gas from the Pipeline Field to Duke Energy Field Services (“Duke”). Approximately 55% of its gas was sold to Duke on a forward contract basis during the nine months ended December 31, 2004, with the remainder being sold at the Inside FERC, first of the month CIG Index, a published pricing index on which gas sales contracts in the Rocky Mountains are generally based. Infinity-Wyoming enters into the contracts to hedge its production when market conditions are deemed favorable in order to manage price fluctuations and achieve a more predictable cash flow. The following table identifies the contracts that were in place during the year ended December 31, 2004:

      Oil production from the Pipeline Field is sold at the average daily NYMEX posted price less $0.50 per barrel. For December 2004, this was a price of $42.84 per barrel of oil.

      The following table shows exploration and production revenue and the percentage of consolidated revenue that the value represented for each of the years ended December 31, 2004, 2003 and 2002.

      Based on the general demand for oil and natural gas, Infinity does not believe that a loss of any customer would have a material adverse effect on its business.

      Consolidated provides its services to oil and gas developers and lease operators throughout Eastern Kansas and Northeast Oklahoma, which includes the Forest City and Cherokee Basins, and in the Powder River Basin of Northeast Wyoming. Consolidated also provides its services in the Arkoma basin of Eastern Oklahoma and provides well cementing services to water well drillers in Missouri, Kansas and Oklahoma.

      Consolidated provided services to approximately 475 customers during 2004, to approximately 400 customers during 2003 and to approximately 380 customers during 2002. The following table sets out information about Consolidated’s major customers during each of these periods:

      Consolidated also provided services to Infinity-Wyoming which resulted in eliminated inter-company revenue of approximately $2.1 million in 2002. The amount of revenue earned by Consolidated from inter-company sales was less than $20,000 during 2003. There were no inter-company sales during 2004. Consolidated has no long-term service contracts with any customers and we do not believe that a loss of any one of our customers will have a prolonged material adverse effect on Consolidated’s business. However, the loss of several customers in any location or a rapid, significant change in oil and gas prices to the extent that customers curtail their development activities could have a material adverse impact on our financial and operating results.

      Infinity and its subsidiaries compete in virtually all facets of their businesses with numerous other companies, including many that have significantly greater financial and other resources. Such competitors may be able to pay more for desirable oil and gas leases and to evaluate, bid for, and purchase a greater number of properties than the financial or personnel resources of Infinity permit. The oilfield service competitors may be able to invest more resources in research and development of new completion techniques and acquire additional equipment to allow them to dedicate resources to a customer in a way that Consolidated is unable to.

      Infinity’s business strategy includes highly competitive oil and natural gas acquisition, exploration, development and production. There can be no assurance, however, that Infinity or its subsidiaries will be able to successfully acquire identified targets, or have the financing available for the acquisitions. We face intense competition from a large number of independent exploration and development companies as well as major oil and gas companies in a number of areas such as:

      Many of our competitors have financial and technological resources substantially exceeding those available to Infinity. Many oil and gas properties are sold in a competitive bidding process in which we may lack technological information or expertise available to other bidders. We cannot be sure that we will be successful in acquiring and developing profitable properties in the face of this competition.

      Consolidated’s competition in Eastern Kansas consist mainly of Cudd Pumping Services. In Northeast Oklahoma, Consolidated competes with Cudd Pumping Services, BJ Services Company, Oilwell Fracturing Services, Inc. and several small local companies. Consolidated believes that its bulk materials facilities, experienced work force, and well maintained fleet of service vehicles puts it in a competitive position to maintain revenues in these locations. Consolidated continues to see competition from three major service companies, Halliburton Company, BJ Services, and Schlumberger Ltd., and numerous smaller cementing companies in Northeast Wyoming. Consolidated may be at a competitive disadvantage when compared to the major companies that are well established with substantial financial resources. These companies can redirect assets and manpower, much like Consolidated has done, to insure that resources to meet the growing demand are available. Some of the exploration and development companies in this area also have the resources available to develop their own service providers. Consolidated’s ability to provide services that meet the market demand in a timely manner while providing quality service to the wells will be crucial to its ability to compete in this market.

      Effective September 2001, Infinity-Wyoming entered into a gas gathering and transportation contract with Duke in which Duke built gas gathering laterals and installed compression facilities to deliver gas produced from the Pipeline Field to the Overland Trail Transmission pipeline. During 2002, the contract was amended to include additional compression and gathering facilities installed by Duke and delivery points for the additional production being generated by Infinity-Wyoming. Infinity-Wyoming pays a gathering fee of $0.40 per Mcf until 7,500,000 Mcf have been produced at which time the fee will be reduced to $0.25 per Mcf. Infinity-Wyoming was obligated to deliver 600,000 Mcf the first year, 1,600,000 Mcf the second year, 2,000,000 the third year, 1,800,000 the fourth year, and 1,500,000 in the fifth and final year of the contract. To date, Infinity-Wyoming has delivered approximately 3,137,000 Mcf under this contract. The Pipeline sales volumes will also be subject to a $0.15 per MMBtu charge for access onto the Overland Trail Transmission line. While Infinity-Wyoming has failed to deliver the volumes required under the terms of the contract, the pipeline operator has also not provided the compression and gathering capabilities they were required to provide under the contract. Management has received a verbal commitment from the operator that the volume commitments will be adjusted and management does not expect that there will be a contract shortfall under the renegotiated volumes.

      Beginning April 1, 2003 and effective through March 31, 2004, Infinity-Wyoming had contracted to sell 3,500 MMBtu per day to Duke at a price of $4.71 per MMBtu, which equates to approximately $5.16 per Mcf. In 2004, Infinity-Wyoming entered into two additional contracts with Duke for the sale of 2,000 MMBtu per day. The first contract is for the period April 1, 2004 through March 31, 2005 and sets a price of $4.40 per MMBtu (approximately $4.84 per Mcf). The second contract is for the period beginning April 1, 2005 and ending March 31, 2006 and is for $4.15 per MMBtu (approximately $4.57 per Mcf). Infinity-Wyoming will receive the Colorado Interstate Gas (CIG) Pipeline first of the month index price for each Mcf of gas in excess of the contracted volume delivered onto the Overland Trail Transmission line. Infinity and its subsidiaries had no agreements or commitments at December 31, 2004, other than those shown above, to provide quantities of oil or gas in the future.

      Infinity’s business is affected by numerous laws and regulations, including, among others, laws and regulations relating to energy, environment, conservation and tax. Failure to comply with these laws and regulations may result in the assessment of administrative, civil and/or criminal penalties, the imposition of injunctive relief or both. Moreover, changes in any of these laws and regulations could have a material adverse effect on our business. In view of the many uncertainties with respect to current and future laws and regulations, including their applicability to Infinity, we cannot predict the overall effect of such laws and regulations on our future operations.

      Infinity believes that its operations comply in all material respects with applicable laws and regulations and that the existence and enforcement of such laws and regulations have no more restrictive effect on our method of operations than on other similar companies in the energy industry.

      The following discussion contains summaries of certain laws and regulations and is qualified as mentioned above.

      Various aspects of Infinity’s oil and natural gas operations are regulated by agencies of the federal government. The Federal Energy Regulatory Commission (“FERC”) regulates the transportation of natural gas in interstate commerce pursuant to the Natural Gas Act of 1938 (“NGA”) and the Natural Gas Policy Act of 1978 (“NGPA”). In the past, the federal government has regulated the prices at which oil and gas could be sold. While “first sales” by producers of natural gas and all sales of crude oil, condensate and natural gas liquids can currently be made at uncontrolled market prices, Congress could reenact price controls in the future. Deregulation of wellhead sales in the natural gas industry began with the enactment of the NGPA in 1978. In 1989, Congress enacted the Natural Gas Wellhead Decontrol Act (the “Decontrol Act”). The Decontrol Act removed all NGA and NGPA price and non-price controls affecting wellhead sales of natural gas effective January 1, 1993.

      Commencing in April 1992, the FERC issued Order Nos. 636, 636-A, 636-B, 636-C and 636-D (“Order No. 636”), which require interstate pipelines to provide transportation services separate, or “unbundled,” from the pipelines’ sales of gas. Also, Order No. 636 requires pipelines to provide open access transportation on a nondiscriminatory basis that is equal for all natural gas shippers. Although Order No. 636 does not directly regulate Infinity’s production activities, FERC has stated that it intends for Order No. 636 to foster increased competition within all phases of the natural gas industry.

      Infinity conducts certain operations on federal oil and gas leases, which are administered by the Bureau of Land Management (“BLM”). Of Infinity-Wyoming’s Pipeline Field acreage, approximately 15,000 gross acres are leases that are administered by the Bureau of Land Management (“BLM”). Approximately 3,000 acres of 11,000 total acres of Infinity-Wyoming’s Labarge Field acreage, including acreage subject to options, are part of federal units for which Infinity-Wyoming is the operator for the development of the resources to certain depths. The Piceance Basin Prospect and Sand Wash Prospect acreage also include acreage that is administered by the BLM. Federal leases contain relatively standard terms and require compliance with detailed BLM regulations and orders, which are subject to change. Among other restrictions, the BLM has regulations restricting the flaring or venting of natural gas, and the BLM has proposed to amend such regulations to prohibit the flaring of liquid hydrocarbons and oil without prior authorization. Under certain circumstances, the BLM may require any company operations on federal leases to be suspended or terminated. Any such suspension or termination could materially and adversely affect Infinity’s financial condition, cash flows and operations.

      The Minerals Management Service (“MMS”) administers the valuation , payment and reporting for royalties on oil and gas produced from federal leases. The BLM issued a final rule that amended its regulations

governing the valuation of gas produced from federal leases. This rule, which becomes effective June 1, 2005, primarily affects the transportation allowance used to value the federal royalty.

      Exploration and production operations of Infinity-Texas and Infinity-Wyoming are subject to various types of regulation at the federal, state, and local levels. These regulations include requiring permits and drilling bonds for the drilling of wells and regulating the location of wells, the method of drilling and casing wells, and the surface use and restoration of properties upon which wells are drilled. Many states also have statutes or regulations addressing conservation matters, including provisions for the unitization or pooling of oil and gas properties, the establishment of maximum rates of production from oil and gas wells and the regulation of spacing, plugging and abandonment of such wells. The operation and production of Infinity-Wyoming’s properties is subject to the rules and regulations of the Wyoming Oil and Gas Conservation Commission (WYOGCC) and the Colorado Oil and Gas Conservation Commission (COGCC). In addition a portion of the properties are on federal lands and are subject to Onshore Orders 1 and 2, The National Historic Preservation Act (NHPA), National Environmental Policy Act (NEPA) and the Endangered Species Act. The operation and production of Infinity-Texas’ properties is subject to the rules and regulations of the Railroad Commission of Texas (RRC).

      Additional proposals and proceedings that might affect the oil and gas industry are pending before Congress, the FERC, BLM, MMS, state commissions and the courts. Infinity cannot predict when or whether any such proposals and proceedings may become effective. In the past, the natural gas industry has been heavily regulated. There is no assurance that the regulatory approach currently pursued by various agencies will continue indefinitely. Notwithstanding the foregoing, Infinity does not anticipate that compliance with existing federal, state and local laws, rules and regulations will have a material or significantly adverse effect upon the capital expenditures, earnings or competitive position of Infinity or its subsidiaries.

      Various federal, state and local laws and regulations relating to the protection of the environment affect our operations and costs. The areas affected include:

      The environmental and land use laws and regulations affecting oil and natural gas operations have been changed frequently in the past, and in general, these changes have imposed more stringent requirements that increase operating costs and/or require capital expenditures in order to remain in compliance. We believe that our business operations are in substantial compliance with current laws and regulations. Failure to comply with these requirements can result in civil and/or criminal fines and liability for non-compliance, clean-up costs and other environmental damages. It is also possible that unanticipated developments or changes in law could cause us to make environmental expenditures significantly greater than those we currently expect.

      The following is a summary discussion of the framework of key environmental and land use regulations and requirements affecting our oil and natural gas exploration, development, production and transportation operations.

      Discharges to Waters. The Federal Water Pollution Control Act of 1972, as amended (the “Clean Water Act”), and comparable state statutes impose restrictions and controls, primarily through the issuance of permits, on the discharge of produced waters and other oil and natural gas wastes into regulated waters and

wetlands. These controls have become more stringent over the years, and it is possible that additional restrictions will be imposed in the future, including potential restrictions on the use of hydraulic fracturing. These laws prohibit the discharge of produced waters and sand, drilling fluids, drill cuttings and other substances related to the oil and natural gas industry into onshore, coastal and offshore waters without a permit.

      The Clean Water Act also regulates stormwater discharges from industrial properties and construction activities and requires separate permits and implementation of a stormwater management plan establishing best management practices, training, and periodic monitoring. Certain operations are also required to develop and implement “Spill Prevention, Control, and Countermeasure” plans or Facility Response Plans to address potential oil spills.

      The Clean Water Act provides for civil, criminal and administrative penalties for unauthorized discharges of oil, hazardous substances and other pollutants. It also imposes substantial potential liability for the costs of removal or remediation associated with discharges of oil or hazardous substances. State laws governing discharges to water also provide varying civil, criminal and administrative penalties and impose liabilities in the case of a discharge of petroleum or its derivatives, or other hazardous substances into regulated waters.

      Oil Spill Regulations. The Oil Pollution Act of 1990, as amended (the “OPA”), amends and augments oil spill provisions of the Clean Water Act, imposing potentially unlimited liability on responsible parties, without regard to fault, for the costs of cleanup and other damages resulting from an oil spill in U.S. waters. Responsible parties include (i) owners and operators of onshore facilities and pipelines and (ii) lessees or permittees of offshore facilities.

      Air Emissions. Our operations are subject to local, state and federal regulations governing emissions of air pollution. Administrative enforcement actions for failure to comply strictly with air pollution regulations or permits are generally resolved by payment of monetary fines and correction of any identified deficiencies. Alternatively, regulatory agencies could require us to forego construction, modification or operation of certain air emission sources. Air emissions from oil and natural gas operations also are regulated by oil and natural gas permitting agencies including the MMS, BLM and state agencies.

      We may generate wastes, including hazardous wastes that are subject to the federal Resource Conservation and Recovery Act (“RCRA”) and comparable state statutes, although certain oil and natural gas exploration and production wastes currently are exempt from regulation under RCRA. The EPA has limited the disposal options for certain wastes that are designated as hazardous under RCRA (“Hazardous Wastes”). Furthermore, it is possible that certain wastes generated by our oil and natural gas operations that are currently exempt from treatment as Hazardous Wastes may in the future be designated as Hazardous Wastes, and therefore be subject to more rigorous and costly operating, disposal and clean-up requirements. State and federal oil and natural gas regulations also provide guidelines for the storage and disposal of solid wastes resulting from the production of oil and natural gas, both on- and off-shore.

      Superfund. Under some environmental laws, such as the Comprehensive Environmental Response, Compensation, and Liability Act of 1980, also known as CERCLA or the Superfund law, and similar state statutes, responsibility for the entire cost of cleanup of a contaminated site, as well as natural resource damages, can be imposed upon any current or former site owners or operators, or upon any party who discharged one or more designated substances (“Hazardous Substances”) at the site, regardless of the lawfulness of the original activities that led to the contamination. CERCLA also authorizes the EPA and, in some cases, third parties to take actions in response to threats to the public health or the environment and to seek to recover from the potentially responsible parties the costs of such action. Although CERCLA generally exempts petroleum from the definition of Hazardous Substances, in the course of our operations we may have generated and may generate wastes that fall within CERCLA’s definition of Hazardous Substances. We may also be an owner or operator of facilities at which Hazardous Substances have been released by previous owners or operators. We may be responsible under CERCLA for all or part of the costs to clean up facilities at which such substances have been released and for natural resource damages. We have not, to our knowledge, been identified as a potentially responsible party under CERCLA, nor are we aware of any prior owners or

operators of our properties that have been so identified with respect to their ownership or operation of those properties.

      Abandonment and Remediation Requirements. Federal, state and local regulations provide detailed requirements for the abandonment of wells, closure or decommissioning of production and transportation facilities, and the environmental restoration of operations sites. The Colorado Oil and Gas Conservation Commission, Wyoming Oil and Gas Conservation Commission and the Texas Railroad Commission are the principal state agencies and BLM the primary federal agency responsible for regulating the drilling, operation, maintenance and abandonment of all oil and natural gas wells in the state. State and BLM regulations require operators to post performance bonds.

      Significant potential costs relating to environmental and land use regulations associated with our existing properties and operations include those relating to (i) plugging and abandonment of facilities, (ii) clean-up costs and damages due to spills or other releases and (iii) civil penalties imposed for spills, releases or non-compliance with applicable laws and regulations.

      Infinity-Texas, Infinity-Wyoming, and Consolidated currently own or lease properties that are being used for the disposal of drilling and produced fluids from exploration, development and production of oil and gas and for other uses associated with the oil and gas industry. Although these subsidiaries follow operating and disposal practices that they considers appropriate under applicable laws and regulations, hydrocarbons or other wastes may have been disposed of or released on or under the properties owned or leased by the subsidiaries or on or under other locations where such wastes were taken for disposal. Infinity could incur liability under the Comprehensive Environmental Response, Compensation and Liability Act or comparable state statutes for contamination caused by wastes it generated or for contamination existing on properties it owns or leases, even if the contamination was caused by the waste disposal practices of the prior owners or operators of the properties. In addition, it is not uncommon for landowners and other third parties to file claims for personal injury and property damage allegedly caused by the release of produced fluids or other pollutants into the environment.

      The operations of Consolidated routinely involve the handling of significant amounts of oilfield related materials, some of which are classified as hazardous substances. Consolidated’s transportation operations are regulated under the Federal Motor Carrier Safety Regulations of the Department of Transportation as administered by the Kansas Department of Transportation, Oklahoma Department of Transportation, and Wyoming Department of Transportation. The operation of salt-water disposal wells by Consolidated is regulated by the Kansas Department of Health and Environment. Consolidated will incur an estimated $100,000 in costs associated with operating within current environmental regulations this fiscal year primarily related to transportation of hazardous substances.

      During December 2004, Infinity-Wyoming produced an average of 430 barrels of water per day from wells that it operates. Infinity-Wyoming currently uses four injection wells to dispose of the water into underground rock formations and plans to continue to use this method for disposal of the water produced from its operated wells. If the future wells produce water of lesser quality than allowed under state law for injection in underground rock formations or at a volume greater than can be injected into the current disposal wells, Infinity-Wyoming could incur costs of up to $7.50 per barrel of water to dispose of the produced water. At current production rates, this would cost Infinity-Wyoming approximately an additional $100,000 a month in water disposal costs. If Infinity-Wyoming’s wells produce water in excess of the limits of its permitted facilities, Infinity-Wyoming may have to drill additional disposal wells. Each additional disposal well could cost Infinity-Wyoming approximately $1,000,000. It costs Infinity-Wyoming approximately $50,000 per year to operate these disposal wells.

      Infinity-Texas utilizes significant quantities of water in the fracture and stimulation of its wells in the Fort Worth Basin. Typically a high percentage of this water flows back and must be disposed of. Infinity-Texas

plans to drill a disposal well in Erath County, Texas during 2005. Each disposal well is expected to cost Infinity-Texas approximately $1,000,000.

      As is customary in the oil and gas industry, only a preliminary title examination is conducted at the time Infinity acquires leases of properties believed to be suitable for drilling operations. Prior to the commencement of drilling operations, a thorough title examination of the drill site tract is conducted by independent attorneys. Once production from a given well is established, Infinity prepares a division order title opinion indicating the proper parties and percentages for payment or production proceeds, including royalties. We believe that we have satisfactory title to all of our material assets. Although title to these properties is subject to encumbrances in some cases, such as customary interests generally retained in connection with acquisition of real property, customary royalty interests and contract terms and restrictions, liens under operating agreements, liens related to environmental liabilities associated with historical operations, liens for current taxes and other burdens, easements, restrictions and minor encumbrances customary in the oil and natural gas industry, we believe that none of these liens, restrictions, easements, burdens and encumbrances will materially detract from the value of these properties or from our interest in these properties or will materially interfere with our use in the operation of our business. In addition, we believe that we have obtained sufficient rights-of-way grants and permits from public authorities and private parties for us to operate our business in all material respects as described in this offering memorandum.

      The oil and natural gas business involves a variety of operating risks, such as those described under “Risk Factors — Risks Related to Our Business — Our business involves significant operating risks.” In accordance with industry practice, we maintain insurance against some, but not all, potential risks and losses. For some risks, we may not obtain insurance if we believe 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, it could adversely affect us.

      On December 31, 2004, Infinity and its subsidiaries had approximately 111 employees. Consolidated had 96 employees in its oilfield services business; Infinity-Texas and Infinity-Wyoming had 9 employees in their exploration and production business; and Infinity had 6 employees in executive and administrative positions.

      There are currently no pending material legal proceedings to which we are a party.

      No matters were submitted to a vote of the Company’s shareholders during the fourth quarter of 2004.

PART II

     Principal Market and Price Range of Common Stock

      Infinity’s Common Stock began trading on the Nasdaq Small-Cap Market on June 29, 1994, under the symbol “IFNY.” The following table sets forth the high and low closing sale prices for Infinity’s Common Stock as reported by the Nasdaq Stock Market. The closing price of the Common Stock on March 23, 2005 was $10.45 per share.

     Approximate Number of Holders of Common Stock

      At March 23, 2005, there were 235 record holders of Infinity’s $0.0001 par value Common Stock.

     Dividends

      Holders of common stock are entitled to receive such dividends as may be declared by Infinity’s Board of Directors. Infinity has not declared nor paid and does not anticipate declaring or paying any dividends on its common stock in the near future. Any future determination as to the declaration and payment of dividends will be at the discretion of Infinity’s board of directors and will depend on then-existing conditions, including Infinity’s financial condition, results of operations, contractual restrictions, capital requirements, business prospects and such other factors as the board deems relevant. Pursuant to the terms of its Senior Secured Notes Facility, Infinity is prohibited from paying dividends.

      The selected consolidated financial information presented below for the years ended December 31, 2004, 2003 and 2002, and March 31, 2001, and the nine month transition period ended December 31, 2001 is derived from the audited consolidated financial statements of Infinity. Infinity changed its fiscal year end to December 31 fiscal year end from a March 31 fiscal year end effective December 31, 2001. Certain reclassifications have been made to prior financial data to conform to the current presentation. The table gives effect to the two-for-one split of Infinity’s common stock effective May 13, 2002 for all periods presented.

      The following information should be read in conjunction with the Consolidated Financial Statements and Notes presented elsewhere in this Form  10-K. Infinity follows the full-cost method of accounting for oil and gas properties. See “Organization and Summary of Significant Accounting Policies,” included in Note 1 to the Consolidated Financial Statements.

      Infinity and its operating subsidiaries Infinity-Texas, Infinity-Wyoming and Consolidated are engaged in identifying and acquiring oil and gas acreage, exploring and developing acquired acreage, oil and gas production, and providing oilfield services. Infinity’s primary focuses are on: (i) the acquisition, exploration and development of and production from its properties in the Fort Worth Basin of North Central Texas and Greater Green River, Sand Wash and Piceance Basins of Southwest Wyoming and Northwest Colorado; and (ii) providing oilfield services in the Mid-Continent region and the Powder River Basin of Northeast Wyoming. Infinity has also been awarded a 1.4 million acre concession offshore Nicaragua in the Caribbean Sea which it intends to explore over the next few years subject to consummation of the long-term exploration and production contract governing such activity.

     Overview of Oil and Gas Exploration and Production Activity

      Infinity, through Infinity-Texas, expanded its exploration and production operations into the Fort Worth Basin of Texas during the year ended December 31, 2004. The opportunity to operate in Texas was attractive to Infinity due to year-round access to exploration and development locations, ease of permitting, better weather, and less restrictive government and environmental laws and regulations. In addition, early results for other operators in the Fort Worth Basin were encouraging to Infinity-Texas, and its minority joint interest partners, who were experienced in other successful parts of the basin. Meanwhile, Infinity-Wyoming continued to explore and develop the various projects and prospects in the Rocky Mountains, but was hampered by weather, governmental and environmental restrictions and regulations, as well as various operational issues at the Labarge Field and Pipeline Field. Infinity-Wyoming began initial exploration efforts for coalbed methane in the Sand Wash and Piceance Basins, and also commenced development drilling for oil at its Sand Wash Prospect.

      Infinity expects to continue to explore and develop its Fort Worth Basin acreage and its Rocky Mountain projects and prospects. Infinity expects its Rocky Mountain projects to proceed more slowly, due in part to governmental restrictions. In addition to reducing and refinancing indebtedness, Infinity raised equity and debt capital during 2004 (and early 2005) to fund its exploration and production operations. Infinity expects to be able to continue to raise capital during 2005 and beyond to fund its exploration and production operations, although the timing, cost and amounts, if any, will depend upon general energy and capital markets conditions and the success of the Company’s operations.

      Infinity-Wyoming has selected Netherland, Sewell and Associates, Inc. to prepare its December 31, 2004 and 2003 third party reserve evaluations. Results of these evaluations are disclosed in the “Supplemental Oil and Gas Disclosures” in Infinity’s Consolidated Financial Reports and in the “Oil and Natural Gas Reserves” section of Item 1. and Item 2. Business and Properties. Another engineering firm prepared the reserve evaluation as of December 31, 2002.

     Overview of Oilfield Service Operations

      Consolidated continued to develop its business relationships as the largest oilfield service provider in Eastern Kansas and Northeast Oklahoma by serving approximately 475 customers during 2004. The continued strong price of natural gas and crude oil and the focus on development of the coal bed methane

potential of the Cherokee basin in Eastern Kansas and Northeast Oklahoma contributed to the overall increase in activity for Consolidated. During 2004 Consolidated achieved several operational milestones:

      Consolidated is actively seeking opportunities through acquisitions or mergers to expand its service area, increase its market share or enhance the services it provides to its customers.

      On January 13, 2005, we entered into a securities purchase agreement (the “Senior Secured Notes Facility”) with affiliates of Promethean Asset Management, LLC and Angelo, Gordon & Co., L.P. (collectively, the “Buyers”), pursuant to which Infinity sold, and the Buyers purchased $30 million aggregate principal amount of senior secured notes (the “Notes”) due January 13, 2009 and five-year warrants to purchase 924,194 shares of common stock at an exercise price of $9.09 per share and 732,046 shares of common stock at an exercise price of $11.06 per share (collectively, the “Warrants”). The Notes have an initial maturity of 48 months subject to extension for an additional twelve months upon the mutual agreement of Infinity and the Buyers. The Notes bear interest at 3-month LIBOR (London Interbank Offered Rate) plus 675 basis points, adjusted the first business day of each calendar quarter. The Notes are secured by essentially all of the assets of Infinity and its subsidiaries and are guaranteed by each of Infinity’s active subsidiaries. The Notes are redeemable by Infinity for cash at any time during the first year at 105% of par value, declining by 1% per year thereafter (101% during any extended maturity period), together with any accrued and unpaid interest. Under certain circumstances, Infinity has the option to repay the Notes with direct issuances of shares of registered common stock in lieu of cash.

      At quarterly intervals and over a three-year period, commencing in the third quarter of 2005, Infinity has the option to sell additional notes (the “Additional Notes”), along with additional warrants, in amounts of up to $15 million in any rolling twelve-month period and up to a maximum of $45 million. The Additional Notes would have an initial maturity of 42 months (54 months if the maturity of the Initial Notes is extended). The issuance of Additional Notes is subject to Infinity’s future satisfaction of various closing conditions. The ability to issue Additional Notes or requirement to prepay Notes prior to maturity will depend upon a maximum Notes balance calculated quarterly based generally upon a combination of financial performance of Consolidated and (ii) the SEC after-tax PV-10% value of our proved reserves.

      Infinity used approximately $9.2 million of the proceeds from the sale of Notes and Warrants to repay all amounts outstanding pursuant to a Loan and Security Agreement between LaSalle Bank N.A. and Consolidated, a Credit Agreement between U.S. Bank National Association and Infinity-Wyoming, and certain other secured lending agreements, and those credit agreements have been terminated. Infinity is using the remainder of the proceeds to pay costs and expenses related to the sale of the Notes and Warrants and to fund its oil and gas exploration and development activities.

      In February 2005, we entered into a definitive agreement for the acquisition of approximately 24,500 gross and net acres in Comanche County in the Fort Worth Basin of Texas, subject to customary closing conditions. The agreement, as amended, also provides for a right of first refusal on all acres acquired by

the seller in Comanche County. We expect to close the Comanche transaction on or before April 19, 2005. Upon closing, including acreage previously owned, Infinity-Texas will own and operate approximately 67,500 gross acres (approximately 56,300 acres net to Infinity’s interest) of leasehold in Erath, Hamilton and Comanche Counties, Texas. We believe the Comanche County acreage offers prospective vertical and horizontal drilling and production opportunities, targeting the Barnett Shale and Lower Marble Falls formations. The leased properties are located approximately 30 miles southwest of Infinity-Texas’ existing acreage in Erath and Hamilton Counties, Texas. Infinity-Texas agreed to drill at least one test well on the Comanche acreage during the next twelve months.

      Pursuant to requirements of the Senior Secured Notes Facility, on January 13, 2005, Infinity called for redemption the remaining $2.5 million of 8% Subordinated Convertible Notes due 2006 outstanding on February 28, 2005. During January and February 2005, the holders of all of the 8% subordinated convertible notes converted the debt and accrued interest into 517,296 shares of the Company’s common stock.

      Based on the volume weighted average stock price for Infinity’s common stock from February 18, 2005 to February 24, 2005 and pursuant to requirements of the Senior Secured Notes Facility, on February 25, 2005, Infinity called for redemption the remaining $8.2 million of 7% Subordinated Convertible Notes due 2007 outstanding on April 22, 2005 at a redemption price of 102.8% plus accrued and unpaid interest. During 2005, through March 23, the holders of $5,950,538 of 7% subordinated convertible notes have converted the debt and accrued interest into 783,779 shares of the Company’s common stock. Approximately $5.6 million of principal amount remains outstanding as of March 23, 2005. The Company has cash on deposit in excess of the amount outstanding at March 23, 2005, should the remaining 7% notes not be presented for conversion prior to the redemption date.

      Infinity-Wyoming plans to focus on increasing production through development of acreage. Infinity-Wyoming anticipates capital expenditures will be approximately $10 million to drill approximately eight wells, and complete four wells in progress at December 31, 2004, and conduct additional geological and geophysical analysis on its acreage positions.

      Infinity-Texas will focus on increasing its acreage position and commencing production in the Fort Worth Basin of central Texas. Infinity-Texas anticipates its capital expenditures will be approximately $30 million to acquire additional acreage, drill approximately fifteen wells, complete three wells in progress at December 31, 2004, and conduct additional geological and geophysical analysis on its acreage positions.

      The ability of Infinity-Wyoming and Infinity-Texas to complete these activities is dependent on a number of factors including, but not limited to:

      Consolidated expects to increase its oilfield service revenue during 2005 due to the increase in the number of wells being drilled and completed by property owners in our service areas and through strategic acquisitions. These acquisitions would be done in order to:

      Revenues from oilfield services are expected to be between $14 million and $15 million. Management expects that it could make acquisitions that will cost between $10 million and $20 million during 2005 and expects to fund the acquisitions through the issuance of subordinated debt or common stock. Excluding acquisitions and related capital expenditures, Consolidated also expects to have capital expenditures of about $2 million related to equipment and facilities. These capital expenditures would be financed through cash flow and cash on hand.

      Infinity continues to negotiate the final exploration and production agreement with INE for the Perlas and Tyra blocks offshore Nicaragua. Management expects to complete the negotiations and execute the agreement in 2005. Upon execution, Infinity would be required to post a performance bond of approximately $0.7 million for the initial work on the leases which will include an environmental study and the development of geological information developed from additional seismic evaluation. Infinity expects to incur additional costs to complete the negotiations and finalize the leases of approximately $0.1 million.

      Infinity incurred a net loss after taxes of $4.6 million, or $0.49 per diluted share, in 2004 compared to a net loss after taxes of $9.9 million, or $1.23 per diluted share, in 2003.

      Infinity achieved total revenue of $21.0 million in 2004 compared to $18.2 million in 2003. The $2.8 million increase in revenue was attributable to a $3.1 million increase in oilfield service operations, partially offset by a $0.3 million decrease in oil and gas production revenue. Infinity earned a gross profit of $10.5 million during 2004, a $1.4 million, or 15% increase in gross profit from $9.1 million in 2003. Gross profit from exploration and production was $3.6 million during both 2004 and 2003.

      General and administrative expenses for the year ended December 31, 2004 increased $0.2 million from $5.3 million in 2003 to $5.5 million in 2004. In 2003, Infinity incurred approximately $0.6 million in expenses associated with the detailed negotiations relating to a potential merger and the process leading up to negotiations in which Infinity solicited and reviewed strategic alternatives. Infinity and its subsidiaries also recognized additional depreciation, depletion and amortization (“DD&A”) expense of approximately $2.1 million during 2004, an increase to approximately $5.2 million compared to DD&A of approximately $3.1 million for 2003. The increase in DD&A was due to the increase in the depletion rate on and increased investment in oil and gas producing properties and the increase in the investment in Consolidated’s fleet in 2004. During 2004, Infinity-Wyoming also recognized a $4.1 million ceiling write-down of its oil and gas properties based on the full cost ceiling test for oil and gas properties subject to depletion, as compared to $3.0 million in 2003. As a result, Infinity recognized an operating loss of $4.3 million for 2004, compared to an operating loss of $2.3 million for 2003.

      Interest expense and finance charges and amortization of loan costs decreased by $4.5 million to $3.3 million for 2004 compared to $7.8 million for 2003. The decrease was primarily due to the recognition in 2003 of $5.6 million of amortization of loan costs associated with the value of warrants and options granted in conjunction with obtaining new debt financing and the amortization of $0.6 million of cash loan costs paid when those same loans were obtained, compared to $2.1 million of amortization of loan costs in 2004. Infinity

also experienced a $0.3 million decrease in interest expense in 2004 compared to 2003 due to a decrease in average debt outstanding, lower interest rates on certain indebtedness and an increase in interest capitalized to undeveloped properties.

      The following table provides statistical information for the year ended December 31, 2004, 2003 and 2002 (due to rounding and other operating expenses the sum of the individual amounts presented may not equal the totals):

      During 2004, Infinity-Wyoming recorded approximately $1.4 million in revenue on the sale of 33,668 barrels of oil, (201,828 Mcfe) and approximately $4.9 million in revenue on gas sales of 953,428 Mcf from its Pipeline and Labarge projects. Infinity-Wyoming incurred $1.9 million in oil and gas production expenses and $0.7 million in production taxes to produce oil and gas during the year ended December 31, 2004. The total production expenses and production taxes of approximately $2.6 million equate to approximately $2.28 in lifting costs on total production of 1,155,436 Mcfe. The 19% decrease in equivalent production in 2004 as compared to 2003 was primarily a result natural declines in production rates for wells in the Pipeline field.

      Infinity-Wyoming also incurred $0.7 million in general and administrative costs and $3.6 million in DD&A expense, or depletion expense of $3.06 per Mcf equivalent for 2004 compared to $0.92 per Mcf equivalent for 2003. DD&A costs for 2004 increased by $2.1 million due to the increased depletion rate associated with the increased investment in developed oil and gas properties without a corresponding increase in proved reserve quantities. The higher depletion rate in 2004 was partially offset by lower oil and gas production in 2004 compared to 2003.

      Under full cost accounting rules, Infinity reviews, on a quarterly basis, the carrying value of its oil and gas properties. Under these rules, capitalized costs of proved oil and gas properties, may not exceed the present value of estimated future revenue at the un-escalated prices in effect as of the end of each fiscal quarter, and a write-down for accounting purposes is required if the ceiling is exceeded. Infinity-Wyoming is also required to evaluate the value of its unproved oil and gas properties and adjust the value to the lower of the cost or market value of the properties.

      At December 31, 2004, the carrying amount of oil and gas properties subject to amortization exceeded the full cost ceiling limitation by approximately $8.9 million based upon a natural gas price of approximately $6.07 per Mcf and an oil price of approximately $40.25 per barrel in effect at that date. However, due to significant subsequent price increases to approximately $6.53 per Mcf of gas and $54.55 per barrel of oil at the March 15, 2005 measurement date, Infinity was required to record a ceiling writedown of $4.1 million in the quarter and year ended December 31, 2004. In 2003, the Company recorded a ceiling writedown of approximately $3.0 million.

      During 2003 Infinity recorded $1.8 million in revenue on the sale of 57,654 barrels of oil, (345,924 Mcf equivalent) and $4.8 million in revenue on the sale of 1,080,456 Mcf of natural gas from its Pipeline and Labarge projects. Infinity-Wyoming incurred approximately $2.2 million in production expenses and $0.8 million in production taxes to produce the oil and gas during 2003. The total production expenses and production taxes of approximately $2.9 million equate to $2.05 in lifting costs on total Mcf equivalents of 1,426,380. Infinity-Wyoming also incurred approximately $0.8 million in general and administrative costs and $1.6 million in DD&A expense.

      Sales for 2004 increased 27% to $14.7 million from $11.6 million in 2003. Sales of cementing services increased by approximately $1.7 million due to the acquisition of Blue Star Acid Services in April 2004 and by approximately $0.7 million due to an increase of 200 jobs at the Gillette, Wyoming camp. In 2004, the Chanute, Kansas camp cemented an additional 160 wells and generated an additional $0.7 million in revenue compared to its 2003 activity, prior to its sale in September 2004. The following table details the increase in gross revenue in millions of dollars, before discounts and inter-company eliminations, for the years shown, based on the number and type of core service jobs performed (due to rounding the sum of the individual amounts presented may not equal the totals):

Oilfield Service Statistics

      The increase in the number of cementing jobs performed reflects the increase in the number of wells being drilled in Eastern Kansas and Northeast Oklahoma as well as in Northeast Wyoming. As well testing is completed on the newly drilled wells, completion and stimulation activities such as acidizing and fracturing should increase. Management believes that the increase in the number of wells cemented by Consolidated during the year and the continued high prices for oil and natural gas are good indicators of future increases in its acidizing and fracturing activities as well.

      The additional activity also led to a 27% increase in the cost of goods sold of approximately $1.7 million. The increase in cost of goods sold was primarily due to the increase in materials of approximately $0.9 million, labor expense of approximately $0.4 million, and an increase in equipment operating costs and maintenance of approximately $0.4 million. General and administrative expenses for oilfield services of $2.8 million for 2004 was comparable to the same period in 2003.

      Infinity and its subsidiaries incurred approximately $2.1 million in expenses associated with corporate activities during 2004 and 2003.

      Other income and expense was a net expense of $0.3 million for 2004 compared to $7.6 million for 2003. Infinity recognized a $4.5 million decrease in interest expense of which $4.2 million was associated with the amortization of financing costs. There was also a $0.3 million decrease in interest expense in 2004 compared to 2003 period due to a decrease in average debt outstanding, lower interest rates on certain indebtedness and an increase in the amount of interest capitalized to undeveloped properties.

      Infinity reflected no net tax benefit or expense in 2004 and 2003. The net operating losses generated in 2004 and 2003 increased Infinity’s net deferred tax asset. Due to uncertainty as to the ultimate utilization of the net operating losses, the net deferred tax asset has been fully reserved by a valuation allowance as described in Note 11 of the consolidated financial statements.

      Infinity incurred a net loss after taxes of $9.9 million, or $1.23 per fully diluted share, in 2003 compared to a net loss after taxes of $1.6 million, or $0.22 per fully diluted share in 2002.

      Infinity achieved a $4.6 million increase in gross profit to $9.1 million in 2003 from $4.5 million for 2002. The increase in gross profit during 2003 compared to 2002 was the result of a $3.0 million, or approximately 36%, increase in oilfield service revenue to $11.6 million from $8.6 million. The increase in revenue was partially offset by a $1.6 million, or 35%, increase in oilfield service cost of services provided (see “Oilfield Services” discussion below). Oilfield service revenue for 2002 was reduced by the elimination of $2.1 million of oilfield service sales that were provided to Infinity-Wyoming by Consolidated for the development of its oil and gas properties and the cost of services provided was reduced by $1.1 million for the cost of those services provided to Infinity-Wyoming. The oilfield service subsidiary provided minimal services to Infinity-Wyoming in 2003. Additionally, gross profit comparisons were affected by a $4.2 million, or approximately 178%, increase in sales of oil and gas from $2.4 million for 2002 to $6.6 million in 2003 with a corresponding increase of $0.6 million in oil and gas production costs and $0.5 million increase in production taxes in 2003 (see “Oil and Gas Production” discussion below).

      General and administrative expenses for 2003 increased $0.7 million from $4.6 million in 2002 to $5.3 million in 2003. In 2003, Infinity incurred approximately $0.6 million in expenses associated with the detailed negotiations relating to a potential merger, which negotiations were terminated in April 2003, and the process leading up to those negotiations in which Infinity solicited and reviewed strategic alternatives. Infinity and its subsidiaries also recognized additional DD&A expense of approximately $1.3 million during 2003, an increase to approximately $3.1 million for the period compared to DD&A of approximately $1.8 million for 2002. The increase in DD&A was due to the increase in the investment in Consolidated’s fleet in 2002 and the increase in the depletion rate on the oil and gas producing properties. Infinity-Wyoming also recognized a $3.0 million ceiling write-down of its oil and gas properties based on the full cost ceiling test for oil and gas properties subject to depletion. As a result, Infinity recognized an operating loss of $2.3 million for 2003, compared to an operating loss of $1.9 million for 2002.

      Interest expense and finance charges increased by $7.0 million to $7.8 million for 2003 compared to $0.8 million for 2002. The increase was primarily due to the recognition of $5.6 million of amortization of loan costs associated with the value of warrants and options granted in conjunction with obtaining debt financing and the amortization of $0.6 million of cash loan costs paid when those same loans were obtained. Infinity also experienced a $0.9 million increase in interest expense in 2003 period compared to 2002 due to the increase in debt outstanding, higher interest rates on certain notes issued in 2003 and a decrease in the amount of interest that was capitalized to undeveloped properties as Infinity experienced a period of development inactivity during a significant portion of 2003.

      Infinity recognized a deferred income tax benefit of $1.1 million in 2002. The net operating losses generated in 2003 increased Infinity’s net deferred tax asset. Due to uncertainty as to the ultimate utilization of the net operating losses, the net deferred tax asset has been fully reserved by a valuation allowance as discussed in Note 11 of the consolidated financial statements. Therefore, Infinity has reflected no net tax expense or benefit for 2003.

      See the table above for statistical information for 2003 and 2002 (due to rounding and other operating expenses the sum of the individual amounts presented may not equal the totals).

      During 2003, Infinity-Wyoming recorded approximately $1.8 million in revenue on the sale of 57,654 barrels of oil, (345,924 Mcf equivalents) and approximately $4.8 million in revenue on the gas sales of 1,080,456 Mcf from its Pipeline and Labarge projects. Infinity-Wyoming incurred $2.1 million in production expenses and $0.8 million in production taxes to produce the oil and gas during 2003. The total production expenses and production taxes of approximately $2.9 million equate to approximately $2.04 in lifting costs on total Mcf equivalents of 1,426,380. Infinity-Wyoming also incurred $0.8 million in general and administrative costs and $1.6 million in DD&A expense, or approximately $1.63 per Mcf equivalent for the period. The general and administrative expense included approximately $0.2 million in costs associated with the detailed negotiations relating to a potential merger, which negotiations were terminated in May 2003, and the process leading up to those negotiations in which Infinity solicited and reviewed strategic alternatives. Excluding these costs, general and administrative expenses for Infinity-Wyoming were unchanged when compared to the prior year period. DD&A costs for the period increased by $1.3 million due to the increased depletion rate associated with the investment in developed oil and gas properties. The higher rate was the result of the increase in oil and gas production and the decrease in the proved reserves from 2002 to 2003.

      Infinity also recognized in 2003 a ceiling write-down of its oil and gas properties under the full cost ceiling test of approximately $3.0 million. Due to the limited availability of capital for development of its properties, the decision not to re-new a portion of Infinity-Wyoming’s leases during 2004, and the condemnation of leases due to geological and geophysical evaluation, Infinity-Wyoming re-classified approximately $5.0 million of its investment in oil and gas properties not subject to depletion to subject to amortization.

      During 2002 Infinity-Wyoming recorded $0.9 million in revenue on the sale of 42,525 barrels of oil, (255,150 Mcf equivalent) and $1.3 million in revenue on the sale of 648,160 Mcf of natural gas from its Pipeline and Labarge projects. Infinity-Wyoming incurred approximately $1.1 million in lease operating expenses, $0.2 million in production taxes and $0.3 million in transportation fees to produce the oil and gas during 2002. The total production expenses and production taxes of approximately $1.6 million equate to $1.79 in lifting costs on total Mcf equivalents of 903,310. Infinity-Wyoming also incurred approximately $0.7 million in general and administrative costs and $0.2 million in DD&A expense, or approximately $1.00 per Mcf equivalent for the period.

      The increase in production was primarily a result of the increased production time for wells in each period. Several wells began production in the third and fourth quarters of 2002. These wells produced for all of 2003 while producing for only a short period and at lower volumes during 2002.

      Infinity-Kansas recorded net revenue of $0.2 million from its Kansas properties and operating expenses and production taxes of $0.2 million during 2002. Effective May 1, 2002 Infinity-Kansas sold its interest in the Owl Creek and Manson properties to West Central Oil, LLC for cash and a note receivable. Under the full cost method of accounting for oil and gas properties, Infinity and its subsidiaries did not recognize a gain or loss on the sale of its oil and gas properties since the sale did not have a material impact on the relationship between the oil and gas property values and the value of the reserves associated with those properties. Infinity reduced its investment in the remaining oil and gas properties by approximately $244,000 on the sale of the property.

      During 2003, production, oil and gas prices, operating expenses and development expenditures for Infinity-Wyoming’s Labarge and Pipeline projects varied from those estimated in reserve reports at December 31, 2002 and additional geological, geophysical, and engineering data became available and was analyzed. Production at Labarge continued to be uneconomic, possibly due in part to down-hole operational problems. Quantities of proved oil and gas reserves as evaluated by Netherland Sewell and Associates at December 31, 2003 were substantially less than our previous estimates which in turn resulted in a higher depletion rate for the last part of 2003.

      The 58% increase in production during 2003 combined with the significant reduction in proved reserves at January 1, 2004 resulted in a $1.2 million increase in depletion of developed oil and gas properties in 2003 compared to the 2002 period.

      Infinity-Wyoming experienced a $0.3 million increase in administrative expenses in 2003 compared to 2002. This increase in administrative expense was primarily legal, accounting, and consulting fees associated with the detailed negotiations relating to a potential merger, which negotiations were terminated in May 2003, and the process leading up to those negotiations in which Infinity solicited and reviewed strategic alternatives.

      Sales for 2003 increased to $11.6 million from $8.6 million, net of inter-company eliminations, in 2002. Infinity eliminated oilfield services sales of $2.1 million from revenues for sales of services to Infinity-Wyoming during 2002. There were no material inter-company sales in 2003. Sales of cementing services from Consolidated’s Bartlesville, Oklahoma camp increased by approximately $0.8 million and revenue from fracturing services from that camp increased by approximately $1.3 million in 2003 compared to 2002. The increase in revenue was primarily due to an increase in development activity during the second and third quarters of 2003 as customers moved from the evaluation of their prospects to the full scale development of their prospects in areas serviced from the Bartlesville facility. Revenue from cementing services provided from Consolidated’s Gillette, Wyoming facility increased by approximately $1.3 million, due to increased coalbed methane development activity in the Powder River Basin of Wyoming. Crews from the Gillette facility cemented over 400 wells in 2003 compared to 78 in 2002. The following table details the increase in gross revenue in millions of dollars, before discounts and inter-company eliminations, for the periods, based on the number and type of core service jobs performed (due to rounding the sum of the individual amounts presented may not equal the totals):

Oilfield Service Statistics

      The increase in the number of cementing jobs performed reflects the increase in the number of wells being drilled in Eastern Kansas and Northeast Oklahoma as well as in Wyoming. The additional activity also led to an increase in the cost of goods sold of approximately $1.6 million. The increase in cost of goods sold was primarily due to the increase in materials of approximately $0.7 million, labor expense of approximately $0.4 million, and an increase in equipment operating costs and maintenance of approximately $0.3 million. General and administrative expenses for oilfield services for 2003 were comparable to 2002.

      Infinity and its subsidiaries incurred approximately $2.1 million in expenses associated with corporate activities during 2003 compared to approximately $1.9 million in 2002. Included in the $0.2 million increase was approximately $0.3 million in legal, accounting, and consulting fees associated with the detailed negotiations relating to a potential merger, which negotiations were terminated in May 2003, and the process leading up to those negotiations in which Infinity solicited and reviewed strategic alternatives.

      Other income and expense was a net expense of $7.6 million for 2003 compared to $0.8 million for 2002. Infinity recognized a $7.0 million increase in interest expense of which $6.0 million was associated with the amortization of financing costs. $5.4 million of the increase in amortization of loan costs related to options and warrants granted in conjunction with obtaining new debt financing and the remainder of the increase was related to cash loan costs paid when those same loans were obtained. There was also a $0.9 million increase in interest expense in 2003 compared to 2002 due to the increase in debt outstanding, higher interest rates on notes issued in 2003 and a decrease in the amount of interest that was capitalized to undeveloped properties as Infinity experienced a period of development inactivity during a significant portion of 2003.

      Infinity recognized a deferred tax benefit of approximately $1.1 million in 2002. The net operating losses generated in 2003 increased Infinity’s net deferred tax asset. Due to uncertainty as to the ultimate utilization of the net operating losses, the net deferred tax asset has been fully reserved by a valuation allowance as described in Note 11 of the consolidated financial statements. Therefore, Infinity has reflected no net tax expense or benefit for 2003.

      Infinity’s primary sources of liquidity are cash provided by operations and debt and equity financing. Infinity’s primary needs for cash are for the operation, development, production, exploration and acquisition of oil and gas properties, for fulfillment of working capital obligations, and for the operation and development through acquisitions of oilfield service businesses.

      As of December 31, 2004, the Company had working capital of $0.3 million, compared to a working capital deficit of $2.2 million at December 31, 2003. Working capital increased by approximately $2.5 million due to an approximate $5.9 million increase in current assets due primarily to (i) a $2.3 million increase in cash; (ii) a $1.7 million increase in net accounts receivable; and (iii) an approximate $1.6 million increase in the current portion of a note receivable, offset by an approximate $3.4 million increase in current liabilities due to (i) a $1.5 million increase in accounts payable and (ii) a $3.5 million increase in accrued liabilities; offset by (iii) a $1.4 million decrease in current portion of long-term debt.

      During the year ended December 31, 2004, cash provided by operating activities was $5.5 million, compared to $2.8 million in 2003. The increase in cash provided by operating activities of $2.7 million was primarily due to the $5.3 million decrease in net loss.

      During 2004, Infinity used $9.9 million in investing activities, compared to $6.9 million used in 2003. The increase in cash used in investing activities of $3.0 million was primarily attributable to a $6.0 million increase in exploration and production capital expenditures and a $1.7 million increase in oilfield services capital expenditures, partially offset by a $4.6 million increase in proceeds of sale of fixed assets.

      During 2004, Infinity financing activities provided $6.8 million, compared to $3.9 million from financing activities during 2003. The increase in cash provided by financing activities of $2.9 million was due to an $8.5 million increase in proceeds from equity issuances, net of issuance costs, offset by a $5.3 million decrease in proceeds from borrowings and a $0.3 million increase in debt repayments.

      Effective June 13, 2001, Infinity sold $6,475,000 in 8% Subordinated Convertible Notes in a private placement. During the year ended December 31, 2004, $308,276 of the notes and interest accrued on those notes was converted into 63,179 shares of common stock, leaving an outstanding balance on the notes of $2,493,000 at December 31, 2004. The remaining notes and accrued interest were converted in their entirety by February 28, 2005 into 517,296 shares of the Company’s common stock.

      Effective April 17, 2002, Infinity sold $12,540,000 in 7% Subordinated Convertible Notes in a private placement. Infinity issued $391,000 in additional notes for the payment of accrued interest due April 15, 2004 and $404,000 in additional notes for the payment of accrued interest due October 15, 2004. In addition, during

the year ended December 31, 2004, $487,472 of the notes and interest accrued on notes were converted into 62,685 shares of common stock, leaving an outstanding balance on the notes of $11,516,698 at December 31, 2004. During 2005, through March 23, the holders of $5,950,538 of 7% have converted the debt and accrued interest into 783,779 shares of the Company’s common stock. The remaining notes are currently subject to redemption by Infinity on April 22, 2005 and the outstanding balance of the notes on March 23, 2005 was approximately $5.6 million. Infinity has cash available to redeem the remaining 7% notes should they not be presented for conversion prior to the redemption date.

      Effective November 25, 2002, Infinity issued $3,000,000 in notes to a stockholder. These notes were secured with a first or second priority security interest in certain gas properties and accrued interest at 7% per annum. On January 15, 2004, Infinity issued 125,000 shares of common stock valued at $4.00 per share and paid $750,000 in cash, as partial payment on the $3,000,000 bridge note. As a result of the private placement of common stock on November 15, 2004, the note was repaid in full during November 2004.

      In January 2002, Consolidated established a term loan collateralized by substantially all of its oilfield service equipment, a revolving line of credit secured by the eligible receivables of Consolidated and a $1.0 million capital expenditures line of credit with LaSalle Bank, N.A. (“LaSalle Bank”). Effective July 9, 2004, Consolidated borrowed $5.4 million under this facility. As a result of the closing of the Senior Secured Notes Facility, the indebtedness under the LaSalle facility was repaid in full on January 13, 2005.

      In September 2003, Infinity-Wyoming established a Secured Revolving Borrowing Base Credit Facility with U.S. Bank National Association (“U.S. Bank”). The facility provided for funding of up to $25.0 million, and the initial amount made available under the facility and drawn by the Company was $5.5 million. At December 31, 2004 $5.0 million of debt under the U.S. Bank facility is reflected as long-term debt as it was repaid using the long-term credit facility. As a result of the closing of the Senior Secured Notes Facility, the indebtedness under the U.S. Bank facility was repaid in full on January 13, 2005.

      Infinity issued 1,000,000 shares of common stock in January 2004 in a private placement for which it received net proceeds after offering costs of approximately $3.9 million. The net proceeds of this offering, after making a $750,000 payment on notes, were used to pay costs associated with the completion of the Pipeline Field wells drilled in the fourth quarter of 2003, to pay for the Labarge Field well completion activities, and for working capital.

      Infinity issued 1,027,000 shares of common stock in November 2004 in a private placement for which it received net proceeds after offering costs of approximately $4.9 million. The net proceeds of this offering, after making a $1,750,000 payment on notes, were used to pay costs associated with the initial drilling of the Fort Worth Basin wells drilled in the fourth quarter of 2004 and for working capital.

      Depending on the availability of capital resources, the availability of third party contractors for drilling and completion services, and satisfaction of regulatory activities, Infinity could incur capital expenditures of approximately $42 million during 2005. Capital expenditures by operating entity would be approximately $30 million by Infinity-Texas; $10 million by Infinity-Wyoming; and $2 million by Consolidated. The Company could also make capital expenditures for acquisitions in excess of these amounts should appropriate opportunities arise.

      Following the sale of the Senior Secured Notes and Warrants to Buyers in January 2005, Infinity used approximately $9.2 million of the proceeds to repay all amounts outstanding pursuant to the Loan and Security Agreement between LaSalle Bank N.A. and Consolidated, the Credit Agreement with U.S. Bank National Association and Infinity-Wyoming, and certain other secured lending agreements, and those credit agreements have been terminated. No principal on the Notes is due until 2009. Following the repayment of debt and transaction expenses of approximately $2.3 million, Infinity had approximately $18.5 million available for oil and gas exploration and development expenditures. In addition, at quarterly intervals and over a three year period, commencing in the third quarter of 2005, Infinity has the option to sell additional notes, along with warrants, in amounts up to $15 million in any rolling twelve-month period. The ability to issue

Additional Notes will depend upon a maximum Notes balance calculated quarterly based generally upon a combination of financial performance of Consolidated and the SEC after-tax PV-10% value of our proved reserves. Management of the Company is of the opinion that it is reasonably likely that the Company will be eligible to sell $15 million in additional Notes and Warrants during the second half of 2005.

      In January 2005, Infinity called for the redemption of the remaining 8% Subordinated Convertible Notes due 2006 outstanding on February 28, 2005. All $2.5 million outstanding on the 8% notes converted into common stock prior to the redemption date.

      In February 2005, Infinity has called for redemption of the remaining 7% Subordinated Convertible Notes due 2007 outstanding on April 22, 2005. Approximately $5.6 million of principal remains outstanding as of March 23, 2005. The Company has cash on deposit in excess of the amount outstanding at March 23, 2005, should the remaining 7% notes not be presented for conversion prior to the redemption date.

      Depending on the market price for crude oil and natural gas during 2005, production levels from wells not yet placed on line, and continued demand for and acceptance of our oilfield service operations in the geographic areas we serve, Infinity would expect to generate at least $10 million from operating activities during 2005.

      Through March 23, 2005, Infinity has received approximately $4 million in proceeds from the exercise of options and warrants. Management expects to receive proceeds from additional exercises during 2005, but is unable to predict the amount or timing of such proceeds.

      In summary, Infinity believes that it will have approximately $47.5 million available to it in 2005 from the net proceeds from the sale of Notes ($18.5 million), the sale of Additional Notes ($15.0 million), cash from operating activities (at least $10.0 million), and proceeds from the exercise of options and warrants (at least $4.0 million), to fund its planned capital expenditures of approximately $42 million and redeem the 7% notes should none of the balance outstanding at March 23, 2005 be presented for conversion.

      Should Infinity identify acquisition opportunities, or if it wishes to accelerate the exploration and development of its oil and gas properties beyond that currently anticipated, or if cash flow from operating activities is not at levels anticipated, or if Infinity is unable to sell additional notes and warrants under the Senior Secured Notes Facility, Infinity may seek the forward sale of oil and gas production, partnerships or strategic alliances for the development of its undeveloped acreage, the public or private offering of common or preferred equity or subordinated debt, asset sales, or other joint interest or joint venture opportunities to fund any cash shortfalls.

      Infinity believes the following critical accounting policies affect its more significant judgments and estimates used in the preparation of its consolidated financial statements.

      Infinity’s estimated quantities of proved reserves at December 31, 2004 and 2003 were prepared by independent petroleum engineers Netherland, Sewell and Associates, Inc. and at December 31, 2002 were prepared by independent petroleum engineers Wells Chappell and Company, Inc. Infinity’s estimates of oil and natural gas reserves, by necessity, are projections based on geologic and engineering data, and there are uncertainties inherent in the interpretation of such data as well as the projection of future rates of production and the timing of development expenditures. Reserve engineering is a subjective process of estimating underground accumulation of oil and natural gas that are difficult to measure. The accuracy of any reserve estimate is a function of the quality of available data, engineering and geological interpretation and judgment. Estimates of economically recoverable oil and natural gas reserves and future net cash flows necessarily depend upon a number of variable factors and assumptions, such as historical production from the area compared with production from other producing areas, the assumed effects of regulations by governmental agencies and assumptions governing future oil and natural gas prices, future operating costs, severance, ad valorem and excise taxes, development costs and work-over and remedial costs, all of which may in fact vary

considerably from actual results. For these reasons, estimates of the economically recoverable quantities of oil and natural gas attributable to any particular group of properties, classifications of such reserves based on risk of recovery, and estimates of the future net cash flows expected there from may vary substantially. Any significant variance in the assumptions could materially affect the estimated quantity and value of the reserves, which could affect the carrying value of Infinity’s oil and gas properties and the rate of depletion of the oil and gas properties. Actual production, revenues and expenditures with respect to Infinity’s reserves will likely vary from estimates, and such variances may be material.

      Infinity follows the full cost method of accounting for oil and gas properties. Under this method, all productive and nonproductive costs incurred in connection with the exploration for and development of oil and gas reserves are capitalized. Such capitalized costs include lease acquisition, geological and geophysical work, delay rentals, drilling, completing and equipping oil and gas wells, and salaries, benefits and other internal salary related costs directly attributable to these activities. The capitalized costs are amortized over the life of the reserves associated with the assets with the amortization being expensed as depletion in the period that the reserves are produced. This depletion expense is calculated by dividing the period’s production volumes by the estimated volume of reserves associated with the investment and multiplying the calculated percentage by the capitalized investment. Costs associated with production and general corporate activities are expensed in the period incurred. Interest costs related to unproved properties and properties under development are also capitalized to oil and gas properties.

      If the net investment in oil and gas properties less asset retirement obligations, exceeds an amount equal to the sum of (1) the standardized measure of discounted future net cash flows from proved reserves including the effect of cash flow hedges, and (2) the lower of cost or fair market value of properties in process of development and unexplored acreage, the excess is charged to expense as additional depletion. Infinity is required to review the carrying value of its oil and gas properties each quarter under the full cost accounting rules of the Securities and Exchange Commission. Under these rules, capitalized costs of proved oil and gas properties, excluding the future cash outflows associated with settling asset retirement obligations that have been accrued in the full cost pool, less accumulated amortization and related deferred taxes, may not exceed an amount equal to the sum of the present value of estimated future net revenues from proved reserves, discounted at 10%. Application of the ceiling test generally requires pricing future revenue at the un-escalated prices in effect as of the last day of the quarter, including the effects of cash flow hedges, and requires a write down for accounting purposes if the ceiling is exceeded. Unproved oil and gas properties are not amortized, but are assessed for impairment either individually or on an aggregated basis using a comparison of the carrying values of the unproved properties to net future cash flows.

      At December 31, 2004, the carrying amount of oil and gas properties subject to amortization exceeded the full cost ceiling limitation by approximately $8,900,000 based upon a natural gas price of approximately $6.07 per Mcf and an oil price of approximately $40.25 per barrel in effect at that date. However, due to significant subsequent price increases to approximately $6.53 per Mcf of gas and $54.55 per barrel of oil at the March 15, 2005 measurement date, the Company was only required to record a ceiling writedown of $4,100,000 in the quarter and year ended December 31, 2004. In 2003, the Company recorded a ceiling writedown of $2,975,000.

      A decline in prices received for oil and gas sales or an increase in operating costs subsequent to the measurement date or reductions in estimated economically recoverable quantities could result in a requirement that Infinity recognize an additional ceiling write-down of oil and gas properties in a future period. Normal dispositions of oil and gas properties are accounted for as adjustments of capitalized costs, with no gain or loss recognized.

      Equipment utilized in the oilfield service business and to support operations on Infinity’s oil and gas properties is stated at cost. This equipment is depreciated using the straight line method over the estimated useful lives of the assets of three to 30 years.

      The deferred tax assets and liabilities represent the future tax return consequences of those temporary differences, which will either be taxable or deductible when the assets and liabilities are recovered or settled. The measurement of deferred tax assets is reduced, if necessary, by the amount of any tax benefits that are not expected to be realized based on available evidence that is more likely than not to be realized in the form of a deferred tax valuations allowance.

      Infinity has no material off-balance sheet arrangements.

      Infinity’s contractual obligations, including those of its consolidated subsidiaries, include long-term debt, equipment and operating leases and other non-current obligations. The following table lists Infinity’s significant contractual obligations at December 31, 2004.

      For purposes of this table, Infinity is assuming that the holders of the 7% and 8% subordinated convertible notes will not exercise the conversion feature. In addition periodic interest payments required under the credit facilities and the 7% and 8% subordinated convertible notes are not reflected in the table. In January 2005, the Company repaid the revolving credit facility and term loans using proceeds from the Senior Secured Notes facility. However, the table above reflects the original maturity of the debt.

      This table does not reflect the obligations associated with the gas gathering contract related to the Pipeline property. That contract is subject to certain delivery commitments that Infinity-Wyoming has not met. However, the gas gatherer has also not been able to supply the additional system capacity to allow Infinity-Wyoming to meet its delivery obligations and, Infinity-Wyoming expects that the contract will be amended to reflect volume requirements that are consistent with deliveries.

      In December 2004, the FASB issued SFAS No. 123(R), “Share-Based Payment,” which is a revision of SFAS No. 123, “Accounting for Stock-Based Compensation”. SFAS No. 123(R) is effective for public companies for interim or annual periods beginning after June 15, 2005, supersedes APB Opinion No. 25, “Accounting for Stock Issued to Employee’s,” and amends SFAS No. 95, “Statement of Cash Flows.” SFAS No. 123(R) requires all share-based payments to employees, including grants of employee stock options, to be recognized in the financial statements based on their fair values, beginning with the first interim or annual

period after June 15, 2005, with early adoption encouraged. The pro forma disclosures, previously permitted under SFAS No. 123, no longer will be an alternative to financial statement recognition. SFAS No. 123(R) also requires the tax benefits in excess of recognized compensation expenses to be reported as a financing cash flow, rather than as an operating cash flow as required under current literature. This requirement may serve to reduce the Company’s future cash provided by operating activities and increase future cash provided by financing activities, to the extent of associated tax benefits that may be realized in the future.

      The Company is required to adopt SFAS No. 123(R) in its third quarter of fiscal 2005, beginning July 1, 2005. Under SFAS No. 123(R), Infinity must determine the appropriate fair value model to be used for valuing share-based payments, the amortization method for compensation cost, and the transition method to be used at date of adoption. The transition methods include prospective and retroactive adoption options. Under the retroactive options, prior periods may be restated either as of the beginning of the year of adoption or for all periods presented. The prospective method requires that compensation expense be recorded for all unvested stock options and restricted stock at the beginning of the first quarter of adoption of SFAS No. 123(R); the retroactive methods would record compensation expense for all unvested stock options and restricted stock beginning with the first period restated. Infinity is evaluating the requirements of SFAS No. 123(R), and expects that the adoption of SFAS No. 123(R) will not have a material impact on consolidated results of operations and earnings per share as all outstanding options are fully vested.

      In December 2004, the FASB issued SFAS No. 153, “Exchanges of Nonmonetary Assets — An Amendment of APB Opinion No. 29, Accounting for Nonmonetary Transactions” (“SFAS 153”). SFAS 153 eliminates the exception from fair value measurement for nonmonetary exchanges of similar productive assets in paragraph 21(b) of APB Opinion No. 29, “Accounting for Nonmonetary Transactions,” and replaces it with an exception for exchanges that do not have commercial substance. SFAS 153 specifies that a nonmonetary exchange has commercial substance if the future cash flows of the entity are expected to change significantly as a result of the exchange. SFAS 153 is effective for the fiscal periods beginning after June 15, 2005. The Company is currently evaluating the effect that the adoption of SFAS 153 will have on consolidated results of operations and financial condition but does not expect it to have a material impact.

      Staff Accounting Bulletin (“SAB”) 106 was released in September 2004. SAB 106 expresses the SEC staff’s views on the interaction of SFAS No. 143 and the full cost method and provides guidance on computing the full cost ceiling as well as depreciation, depletion and amortization. SAB 106 also requires additional disclosures regarding how the application of SFAS No. 143 has affected the ceiling test and depreciation, depletion and amortization. The Company adopted SAB 106 during the fourth quarter of 2004 and experienced no significant impact on its depletion or ceiling test calculation.

      Infinity’s major market risk exposure is in the pricing applicable to its oil and gas production. Realized pricing is primarily driven by the prevailing price for crude oil and spot prices applicable to Infinity’s crude oil and natural gas production. Historically, prices received for gas production have been volatile and unpredictable. Pricing volatility is expected to continue. Gas price realizations ranged from a low of $4.17 to a high of $6.98 per Mcf during the year ended December 31, 2004. Oil price realizations ranged from a low of $33.35 per barrel to a high of $52.58 per barrel during the period.

      Infinity periodically enters into fixed price contracts or hedging activities on a portion of its projected natural gas production in accordance with its Energy Risk Management Policy. These activities are intended to support cash flow at certain levels by reducing the exposure to oil and gas price fluctuations. Realized gains or losses from Infinity’s cash flow risk management activities are recognized in production revenues. In the year ended December 31, 2004, the effect of Infinity-Wyoming hedging its gas production compared to if it had sold the gas on the spot market was a decrease in revenue of approximately $0.6 million.

      The Securities Purchase Agreement dated as of January 13, 2005 by and among Infinity and the Buyers of the Notes includes a covenant that at each date that is the end of a quarterly or annual period covered by a quarterly report on Form 10-Q or annual report on Form 10-K (a “Determination Date”), at least 20% of the Company’s estimate of its oil and gas production for the 12-month period commencing immediately after such

Determination Date shall be protected from price fluctuations using derivatives, fixed price agreements and/or volumetric production payments. It is the opinion of management that the Company would have been in compliance with this hedging requirement at December 31, 2004, had the Notes been issued and outstanding on that date.

      The consolidated financial statements and supplementary information filed as part of this Item 8 are listed under Part IV, Item 15, “Exhibits, Financial Statement Schedules, and Reports on Form 8-K” and contained in this Form 10-K at page F-1.

      None.

      The Company maintains disclosure controls and procedures that are designed to ensure that information required to be disclosed in the reports under the Securities Exchange Act of 1934, as amended (“Exchange Act”) are communicated, processed, summarized and reported within the time periods specified in the SEC’s rules and forms. At the end of the Company’s fourth quarter of 2004, as required by Rules 13a-15 and 15d-15 of the Exchange Act, an evaluation was carried out under the supervision and with the participation of the Company’s management, including the Chief Executive Officer and Principal Financial and Accounting Officer, of the effectiveness of the design and operation of disclosure controls and procedures (as defined in Rule 13a-15(e) under the Exchange Act). Based upon that evaluation, the Chief Executive Officer and the Principal Financial and Accounting Officer concluded that the design and operation of these disclosure controls and procedures were effective as of that date. No changes in internal controls over financial reporting identified in connection with its evaluation (as required by Rules 13a-15(d) and 15d-15(d) of the Exchange Act) occurred during the fourth quarter of 2004 that affected, or were reasonably likely to materially affect, the Company’s internal control over financial reporting.

      Although the evaluation did not detect any material weaknesses or significant deficiencies in the Company’s system of internal accounting controls over financial reporting, management has identified certain deficiencies in its reconciliation procedures, level of staffing, and inherent limitations in its electronic data processing software. The Company has added additional accounting staff during the first quarter of 2005 and intends to add additional accounting personnel during the second quarter of 2005 to address these deficiencies. The Company will also assess the viability of replacing or enhancing its electronic data processing software in 2005.

PART III

      Information regarding directors of Infinity is incorporated by reference to the section entitled “Election of Directors” in our definitive proxy statement to be filed with the Securities and Exchange Commission pursuant to Regulation 14A in connection with the 2004 annual meeting of shareholders (the “Proxy Statement”).

      Reference is made to the information set forth under the caption “Executive Compensation and Other Information” in the Proxy Statement, which information (except for the report of the board of directors on executive compensation and the performance graph) is incorporated by reference in this report on Form 10-K.

      Reference is made to the information set forth under the caption “Security Ownership of Principal Shareholders and Management” in the Proxy Statement, which information is incorporated by reference in this report on Form 10-K.

      Reference is made to the information contained under the caption “Certain Transactions” contained in the Proxy Statement, which information is incorporated by reference in this report on Form 10-K.

      Reference is made to the information contained under the caption “Appointment of Independent Accountant” contained in the Proxy Statement, which information is incorporated by reference in this report on Form 10-K.

PART IV

      (a) Documents filed as part of this report on Form 10-K or incorporated by reference.

EXHIBITS

SIGNATURES

      In accordance with the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, Infinity has duly caused this Report to be signed on its behalf by the undersigned thereunto duly authorized.

Dated: March 30, 2005

      Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of Infinity and in the capacities and on the dates indicated:

INDEX TO CONSOLIDATED FINANCIAL STATEMENTS

REPORT OF INDEPENDENT REGISTERED

PUBLIC ACCOUNTING FIRM

To the Board of Directors and Stockholders

Infinity, Inc. and Subsidiaries

Chanute, Kansas

      We have audited the consolidated balance sheets of Infinity, Inc. and Subsidiaries as of December 31, 2004 and 2003 and the consolidated statements of operations, changes in stockholders’ equity and cash flows for the years ended December 31, 2004, 2003 and 2002. These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits.

      We conducted our audits in accordance with standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audit included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the consolidated financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall consolidated financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

      In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial condition of Infinity, Inc. and Subsidiaries, as of December 31, 2004 and 2003, and the results of their operations and their cash flows for the years ended December 31, 2004, 2003 and 2002, in conformity with accounting principles generally accepted in the United States of America.

      As discussed in Note 1 to the consolidated financial statements, effective January 1, 2003, the Company changed its method of accounting for asset retirement obligations.

March 13, 2005, except for Notes 7, 8 and 16

  which are as of March 23, 2005

Denver, Colorado

INFINITY, INC. AND SUBSIDIARIES

CONSOLIDATED FINANCIAL STATEMENTS

CONSOLIDATED BALANCE SHEETS