As filed with the Securities and Exchange Commission on September 1, 2005

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM SB-2

REGISTRATION STATEMENT UNDER THE SECURITIES ACT OF 1933

TGC INDUSTRIES, INC.

(Name of small business issuer in its charter)

1304 Summit, Suite 2
Plano, Texas 75074
(972) 881-1099

(Address and telephone number of principal executive offices)

Wayne A. Whitener
President and Chief Executive Officer
TGC Industries, Inc.
1304 Summit, Suite 2
Plano, Texas 75074
(972) 881-1099

(Name, address and telephone number of agent for service)

Copies to:

Approximate date of proposed sale to the public: As soon as practicable after the effective date of the registration statement.

If this form is filed to register additional securities for an offering pursuant to Rule 462(b) under the Securities Act of 1933, as amended, please check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering. o

If this form is a post-effective amendment filed pursuant to Rule 462(c) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering. o

If this form is a post-effective amendment filed pursuant to Rule 462(d) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering. o

If delivery of the prospectus is expected to be made pursuant to Rule 434, check the following box. o

CALCULATION OF REGISTRATION FEE

(1)    Includes up to 825,000 shares issuable upon exercise by the underwriters of their over-allotment option of which up to 412,500 shares will be issued by us and 412,500 shares are currently held, and will be sold, by the selling shareholders.

(2)    Estimated solely for the purpose of calculating the registration fee in accordance with Rule 457(c) under the Securities Act of 1933 based on the average of the high and low price of Registrant’s common stock on August 30, 2005, as reported on the American Stock Exchange.

The Registrant hereby amends this registration statement on such date or dates as may be necessary to delay its effective date until the Registrant shall file a further amendment which specifically states that this registration statement shall thereafter become effective in accordance with Section 8(a) of the Securities Act of 1933, as amended, or until the registration statement shall become effective on such date as the Commission, acting pursuant to said Section 8(a), may determine.

SUBJECT TO COMPLETION, DATED SEPTEMBER 1, 2005

The information in this prospectus is not complete and may be changed. We and the selling shareholders may not sell these securities until the registration statement filed with the Securities and Exchange Commission is effective. This prospectus is not an offer to sell these securities and is not soliciting an offer to buy these securities in any state where the offer or sale is not permitted.

Prospectus

5,500,000 Shares

Common Stock

We are offering 5,500,000 shares of our common stock. Our common stock is traded on the American Stock Exchange under the symbol “TGE.” On August 30, 2005, the closing price of our common stock on the American Stock Exchange was $9.90 per share.

Investing in our common stock involves a high degree of risk. You should carefully consider the risks described under “Risk Factors” beginning on page 9 of this prospectus before buying shares of our common stock.

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

We and the selling shareholders have granted the underwriters a 30-day option to purchase up to an additional 412,500 shares of common stock from us and up to an additional 412,500 shares of common stock from the selling shareholders at the public offering price, less the underwriting discounts and commissions, to cover over-allotments, if any.

The underwriters expect to deliver the shares against payment in New York, New York on            , 2005.

The date of this prospectus is                       , 2005

TABLE OF CONTENTS

You should rely only on the information contained in this prospectus. No dealer, salesperson or other person is authorized to give information that is not contained in this prospectus. This prospectus is not an offer to sell nor is it seeking an offer to buy these securities in any jurisdiction where the offer or sale is not permitted. The information contained in this prospectus is correct only as of the date of this prospectus, regardless of the time of delivery of this prospectus or any sale of these securities.

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PROSPECTUS SUMMARY

This summary highlights selected information contained elsewhere in this prospectus. Because it is a summary, it may not contain all of the information that is important to you or that you should consider before investing in our common stock. You should read this entire prospectus carefully, including “Risk Factors” and the financial statements and related notes appearing elsewhere in this prospectus, before making an investment decision.

All references in this prospectus to “we,” “us,” “our,” or “Company” refer to TGC Industries, Inc. and its wholly-owned subsidiaries, Tidelands Geophysical Co., Inc. (“Tidelands”) and Exploration Surveys, Inc. Unless otherwise indicated, this prospectus assumes that the underwriters’ over-allotment option will not be exercised.

The selling shareholders refers to our directors who have agreed to sell up to 412,500 shares of our common stock to the underwriters upon exercise of the over-allotment option.

Our Business

We are a leading provider of seismic data acquisition services throughout the continental United States (“U.S.”). We have four seismic crews that supply seismic data to companies engaged in the domestic exploration and development of oil and natural gas, both on land and in land-to-water transition areas. Our customers rely on seismic data to identify areas where subsurface conditions are favorable for the accumulation of existing hydrocarbons, to optimize the development and production of hydrocarbon reservoirs, to better delineate existing oil and natural gas fields and to augment reservoir management techniques.

We acquire geophysical data using the latest in three-dimensional (“3-D”) survey techniques. We introduce acoustic energy into the ground by using vibration equipment or dynamite detonation, depending on surface terrain and subsurface requirements. The reflected energy, or echoes, is received through geophones, converted into a digital signal at a multi-channel recording unit and then transmitted to a central recording vehicle. Subsurface requirements dictate the number of channels necessary to perform our services. With our state-of-the-art seismic equipment, including computer technology and multiple channels, we acquire, on a cost effective basis, immense volumes of seismic data that when processed and interpreted produce more precise images of the earth’s subsurface. Our customers then use our seismic data to generate 3-D geologic models that help reduce finding costs and improve recovery rates from existing wells.

Our Competitive Strengths

Despite the historically cyclical challenges of the seismic industry, we have operated continuously since 1967 due to our prudent operating strategy. We believe that the key strengths of our business include the following:

·       Solid customer base.   Our customers consist of major and independent oil and natural gas exploration and development companies. In 2004, approximately 40.0% of our customers from 2003 utilized our services. We believe that the quality and loyalty of our customer base is attributable to our record for performance, safety and customer service.

·       Strong management team.   Our senior management team has extensive experience in providing both land, and land-to-water transition areas, seismic data acquisition services. Wayne Whitener, our President and Chief Executive Officer, has over 30 years of industry expertise, including 21 years with us. Our other key operations executives and managers each have approximately 30 years of industry experience. Because of our management team’s experience in the industry, we have developed and maintain strong relationships with our customers and their consultants.

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·       Investment in state-of-the-art technologies.   We have recently purchased two new ARAM ARIES recording systems (one 3,000 channel system and one 4,000 channel system) and intend to purchase a third new ARAM ARIES recording system with 4,000 channels with the proceeds of this offering. These ARAM ARIES recording systems significantly increase our capacity to meet the needs of our customers and complement our existing Opseis Eagle systems’ capabilities. The ARAM ARIES recording systems are state-of-the-art and allow us to record seismic data faster, enhancing the effectiveness and productivity of our crews and our revenue opportunities. We also have three new vibration vehicles scheduled for delivery in the third quarter of 2005 and are in discussions to acquire up to eight additional vibration vehicles in the first quarter of 2006.

·       Skilled and experienced seismic data acquisition crews.   Our crew managers have at least 20 years of industry experience and are trained to operate all of our seismic equipment and recording systems. Our crew managers are focused on maintaining crew productivity and the quality of the acquired data. We have experienced minimal turnover of our crew personnel.

·       Cost effective operations, favorable margins and strong financial position.   We believe we are able to offer seismic data acquisition services at competitive prices due to our well-trained and supervised crews, state-of-the-art, well-maintained equipment and low corporate overhead. Because we do not process seismic data for our customers, we do not incur the personnel and other costs associated with that service. In addition, we believe that the nature of our seismic recording equipment requires us to have fewer operating personnel. For the six months ended June 30, 2005, we had a favorable mix of contracts which resulted in an EBITDA margin of 36.5%, which we believe to be one of the highest in the industry. Adjusted for the proceeds of this offering, as of June 30, 2005, our funded debt to total capital would have been       %. Our financial strength is important to our customers who may undertake major seismic programs and make sizable pre-payments to us for our services.

Our Industry

We provide seismic data acquisition services primarily to oil and natural gas exploration and development companies for use in the onshore drilling and production of oil and natural gas. The major factors influencing demand for our seismic data acquisition services are:

·       High oil and natural gas prices.    U.S. oil and natural gas prices are extremely volatile. Year to date 2005 marks the third consecutive year of increases in yearly average New York Mercantile Exchange (“NYMEX”) near month oil and natural gas contract prices. We believe that rising oil and natural gas prices in the U.S., if sustained, should result in increased exploration and development activity and thus higher utilization and contract rates for seismic data acquisition services.

·       Increased decline rates in natural gas basins in the U.S.   Over the past 10 years, the number of U.S. natural gas wells drilled has increased significantly; however, a corresponding increase in production has not been realized. We believe that a significant reason for the limited supply response, even as drilling activities have increased, is the accelerating decline rates of production from new natural gas wells. A study published by the National Petroleum Council in September 2003 concluded, from analysis of production data over the preceding 10 years, that as a result of domestic natural gas decline rates of 25% to 30% per year, 80% of natural gas production in 10 years will be from wells that have not yet been developed. We believe that this tends to support a sustained higher natural gas price environment, which should create incentives for exploration and development companies to increase seismic activities in the U.S.

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·       Need for increased oil and natural gas drilling activity as U.S. growth in demand outpaces U.S. supply growth.   The Energy Information Administration, or EIA, recently projected from 2003 through 2025, consumption of oil and natural gas in the U.S. are each projected to grow at an annual rate of 1.5%. However, U.S. domestic production of oil is projected to decrease (0.8)% annually and natural gas is projected to grow at an annual rate of 0.6% over the same period. The EIA also recently estimated that U.S. domestic consumption of oil and natural gas will outpace domestic production by 13.4% and 4.9% by 2010, respectively. By 2025, EIA forecasts that these supply and demand gaps for oil and natural gas may expand to 19.1% and 8.7%, respectively. The majority of the wells drilled by our customers have been wells drilled in search of natural gas reserves.

·       Trend towards drilling and developing unconventional resources.   As a result of improvements in extraction technologies along with general increases in prices, oil and natural gas companies increasingly are exploring for and developing “unconventional” resources, including hydrocarbons from tight sands and shales in new areas.

In addition, beginning on January 1, 2006, new energy legislation will permit the tax deduction of seismic data acquisition services over a 24 month period, instead of the longer write-off period previously in effect. We believe that this accelerated tax write-off may encourage additional exploration and development activity.

We anticipate that oil and natural gas exploration and development companies will continue to respond to sustained increases in demand by expanding their exploration and drilling activities and increasing capital spending. We believe that a continued increase in U.S. seismic work will be required for the oil and natural gas industry to help meet the expected increased demand for oil and natural gas in the U.S.

Our Growth Strategies

We believe that there are significant opportunities for us to increase our revenues and market position in the continental U.S. onshore seismic market. The major factors influencing our future growth are:

·       Optimizing equipment and crew utilization.   We will continue to focus on full utilization and productivity improvements of our crews. We believe that the acquisition of a third ARAM ARIES recording system with the proceeds of this offering will further increase our productivity given its rapid seismic data acquisition characteristics. We will train one of our Opseis Eagle crews to use the new ARAM ARIES recording system and redeploy that Opseis Eagle system with a new crew as customer demand dictates.

·       Maintaining our state-of-the-art technology position.   Our recent acquisition of the two new ARAM ARIES recording systems and planned acquisition of one additional new ARAM ARIES recording system and up to eight new vibration vehicles with the proceeds of this offering, combined with our current Opseis Eagle systems, position us as one of the leaders in our industry in terms of technology. Our ARAM ARIES recording systems incorporate real-time Windows based data recording, which gives our crews the capacity to complete more projects and generate more revenues. Our Opseis Eagle systems will continue to be utilized to support the needs of our customers particularly in markets and geographies better suited to their capabilities, such as in land-to-water transition and shallow gas areas. The continued operation of both of these systems will allow us to take advantage of the strengths of each system.

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·       Maintaining our efficient management structure.   Our crew level managers have significant local knowledge of numerous operating areas and have developed solid relationships with our customers at the field level. Senior management at the corporate level is responsible for sales, logistical, administrative and strategic decisions. While we may add crews and selectively hire additional corporate personnel, we intend to vigorously maintain an efficient and cost effective management structure. We believe that this structure will continue to allow us to be highly responsive to our customers’ needs.

·       Managing the mix and terms of our contracts.   We plan on managing our crews and equipment as a portfolio, balancing the mix of turnkey and term contracts and the type of equipment we use whenever possible. We will also continue to negotiate for some level of weather downtime protection.

·       Maintaining a conservative balance sheet and disciplined capital spending program.   We believe that our post-offering balance sheet will allow us the financial flexibility to pursue opportunities to grow our business. We will continue to evaluate opportunities to purchase new equipment and expand the number of crews as customer demand and market conditions permit.

Principal Executive Offices and Internet Address

Our principal executive offices are located at 1304 Summit, Suite 2, Plano, Texas 75074, and our phone number is (972) 881-1099. Our website is www.tgcseismic.com. Information contained on our website is not incorporated by reference into this prospectus, and you should not consider information contained on our website as part of this prospectus.

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The Offering

The number of shares of common stock outstanding after the offering is based upon the number of shares outstanding as of August 30, 2005, and except as otherwise noted assumes:

·       the expected conversion of our 81¤2% Senior Convertible Preferred Stock into 2,519,664 shares of our common stock, which will be called for redemption at the $1.75 redemption price upon consummation of this offering;

·       exclusion of a total of 227,000 shares issuable upon exercise under outstanding options granted under our stock option plan and 26,000 shares issuable upon exercise of the warrants that are not being repurchased by us with a weighted average exercise price of $2.06 per share and $1.00 per share, respectively; and

·       no exercise by the underwriters of their over-allotment option to purchase up to 412,500 shares of common stock from us.

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Summary Financial Data

The following table sets forth our summary financial data for the periods indicated. The summary financial data for the years ended December 31, 2002, 2003 and 2004 are derived from our audited financial statements. The summary financial data for the six months ended June 30, 2004 and 2005 are derived from our unaudited financial statements and includes, in management’s opinion, all adjustments necessary for a fair presentation of our financial position as of such date and our results of operations for such period. You should read the following summary financial data in conjunction with “Selected Financial Data,” “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” and the financial statements and notes thereto, included elsewhere in this prospectus. Our results of operations for the six month period ended June 30, 2005, may not be indicative of results that may be expected for the full year. The following table presents a non-GAAP financial measure, EBITDA. This measure is not calculated or presented in accordance with accounting principles generally accepted in the United States of America, or GAAP. We explain this measure below and reconcile it to its most directly comparable financial measures calculated and presented in accordance with GAAP in “Non-GAAP Financial Measures” below.

(1)          In July 2005, we put into operation our second ARAM ARIES recording system which has 4,000 recording channels, increasing the total number of working crews to four and available recording channels to 14,000.

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The following table sets forth a summary of our balance sheet data as of June 30, 2005 on a historical basis and on an as adjusted basis to reflect our receipt of estimated net proceeds from our sale of 5,500,000 shares of common stock in this offering, after deducting underwriting discounts and commissions and estimated offering expenses and the application of those net proceeds.

(1)          On a pro forma as adjusted basis, which reflects our capitalization as of June 30, 2005 with adjustments to reflect the issuance of 126,100 shares of common stock resulting from the conversion of 126,100 shares of our 81¤2% Senior Convertible Preferred Stock, the issuance of 2,519,664 shares of common stock resulting from the expected conversion of the remaining shares of our 81¤2% Senior Convertible Preferred Stock into shares of our common stock and the sale of the 5,500,000 shares of common stock offered by us in this offering, after deducting estimated underwriting discounts and commissions, and after giving effect to our receipt and application of the estimated net proceeds from this offering.

Non-GAAP Financial Measure

We define EBITDA as net income plus expenses of interest, income taxes, depreciation and amortization. We use EBITDA as a supplemental financial measure to assess:

·       the financial performance of our assets without regard to financing methods, capital structures, taxes or historical cost basis;

·       our liquidity and operating performance over time and in relation to other companies that own similar assets and that we believe calculate EBITDA in a manner similar to us; and

·       the ability of our assets to generate cash sufficient for us to pay potential interest expenses.

We also understand that such data is used by investors to assess our performance. However, EBITDA is not a measure of operating income, operating performance or liquidity presented in accordance with GAAP. When assessing our operating performance or our liquidity, you should not consider this data in isolation or as a substitute for our net income, cash flow from operating activities or other cash flow data calculated in accordance with GAAP. EBITDA excludes some, but not all, items that affect net income and operating income, and these measures may vary among other companies. Therefore, EBITDA as presented below may not be comparable to similarly titled measures of other companies. Further, the results presented by EBITDA cannot be achieved without incurring the costs that the measure excludes: interest, taxes, depreciation and amortization.

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The following table reconciles our EBITDA to our net income (loss) (Unaudited):

The following table reconciles our EBITDA to our net cash provided by (used in) operating activities (Unaudited):

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RISK FACTORS

Any investment in our common stock involves a high degree of risk. You should carefully consider the risks and uncertainties described below and the other information included in this prospectus before purchasing our common stock. Although the risks described below are the risks that we believe are material, they are not the only risks relating to our business and our common stock. Additional risks and uncertainties, including those that are not yet identified or that we currently believe are immaterial, may also adversely affect our business, financial condition or results of operations. If any of the events described below occur, our business and financial results could be materially and adversely affected. The market price of our common stock could decline due to any of these risks, perhaps significantly, and you could lose all or part of your investment.

Company Risks

We have a history of losses, and we may incur losses again.

Although we reported net income (before dividend requirements on preferred stock) of approximately $2,865,000 for the six months ended June 30, 2005, we have a history of losses with only two profitable years since 1998. In 2004, we had net income (before dividend requirements on preferred stock) of approximately $2,868,000, and in 2003 we had net income (before dividend requirement on preferred stock) of approximately $555,000. Our ability to be profitable in the future will depend on many factors beyond our control, but primarily on the level of demand for land-based seismic data acquisition services by oil and natural gas exploration and development companies. Even if we do achieve profitability, we may not be able to sustain or increase profitability on a quarterly or annual basis. To date, we have not paid a significant amount of income taxes due to our net operating loss carryforwards. However, we anticipate utilizing all of our net operating loss carryforwards in 2005, which will result in our payment of federal and state income taxes in 2005.

Our revenues and operating results can be expected to fluctuate from period to period.

Our revenues and operating results may fluctuate. These fluctuations are attributable to the level of new business in a particular period, the timing of the initiation, progress or cancellation of significant projects, higher revenues and expenses on our dynamite contracts and costs we incur to train new crews we may add in the future to meet increased customer demand. Fluctuations in our operating results may also be affected by other factors that are outside of our control such as permit delays, weather delays and crew productivity. Oil and natural gas prices are at record highs, and have resulted in increasing demand for our services. There can be no assurance that high prices will continue. The demand for our services will be adversely affected by a significant reduction in oil and natural gas prices. Since our business has high fixed costs, the negative effect of one or more of these factors could trigger wide variations in our operating revenues and profitability from quarter to quarter.

We are implementing a growth strategy which, if successful, will place significant demands on us and subject us to numerous risks.

Growing businesses often have difficulty managing their growth. If our growth strategy is successful, significant demands will be placed on our management, accounting, financial, information and other systems and on our business. We will have to expand our management and continue recruiting and employing experienced executives and key employees capable of providing the necessary support. In addition, to manage our anticipated growth we will need to continue to improve our financial, accounting, information and other systems in order to effectively manage our growth, and in doing so could incur substantial additional expenses that could harm our financial results. We cannot assure you that our management will be able to manage our growth effectively or successfully, or that our financial, accounting, information or other systems will be able to successfully accommodate our external and internal growth. Our failure to meet these challenges could materially impair our business.

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We are dependent upon significant customers.

We derive a significant amount of our revenues from a small number of oil and natural gas exploration and development companies. During 2004 and the six months ended June 30, 2005, our two largest customers accounted for approximately 48.4% and 31.6% of revenues, respectively. While our revenues are derived from a concentrated customer base, our significant customers may vary between years. If we lose one or more major customers in the future, or if one or more customers encounter financial difficulties, our business, financial condition and results of operations could be materially and adversely affected.

We receive revenues from customers who engage consultants for processing and interpreting the seismic data we provide.

We receive revenues from customers who have engaged consultants to process and interpret their seismic data. Consultants can have an influence in determining which company its customers use to acquire seismic data. A consultant could recommend that its customers consider using other seismic companies.

We face intense competition in our business from companies with greater financial resources.

The seismic data acquisition services industry is a highly competitive business in the continental U.S. Our competitors include companies with financial resources that are significantly greater than our own as well as companies of comparable and smaller size.

Technological change in our business creates risks of technological obsolescence and requirements for future capital expenditures. If we are unable to keep up with these technological advances, we may not be able to compete effectively.

Seismic data acquisition technologies historically have steadily improved and progressed, and we expect this progression to continue. Our strategy is to upgrade our seismic data acquisition equipment on a regular basis to maintain our competitive position. However, since we are in a capital intensive industry and have limitations on our ability to obtain the financing necessary to enable us to purchase state-of-the-art equipment, some of our competitors may be able to purchase newer equipment when we may not be able to do so.

We are dependent on our management team and key employees and the loss of any of them could harm our business.

We have limited management depth with the result that the loss, whether by death, departure or illness, of Wayne A. Whitener, our President and Chief Executive Officer, or our other senior executives could have a material adverse effect on the ability of management to continue operations at the same level of efficiency. We have key man insurance on the life of our President and Chief Executive Officer so that, in the event of his untimely death, we would receive the insurance proceeds of $1,000,000 under this policy.

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Certain members of our management team are not subject to employment or non-competition agreements and may leave our employment at any time.

None of the members of our management team, other than our President and Chief Executive Officer, are subject to employment agreements or non-competition agreements; therefore, any of these members of our management team could leave our employment upon little or no notice which could have a material adverse effect on our management’s ability to continue operations at the same level of effectiveness. Additionally, the lack of non-competition agreements would allow these members of our management team to immediately begin working for one of our competitors upon the termination of their relationship with us, which could have a negative impact on our strategic plan and our relationships with customers.

We extend credit to our customers without requiring collateral, and a default by a customer could have a material adverse effect on our operating revenues.

We perform ongoing credit evaluations of our customers’ financial conditions and, generally, require no collateral from our customers. A default in payment from one of these large customers could have a material adverse effect on our operating revenues for the period involved.

Certain of our core assets are pledged as collateral for short term notes that require large monthly payments.

Certain assets that are critical to our operations, including our two ARAM ARIES recording systems, are pledged as collateral to our equipment lenders and could be subject to foreclosure in the event that we default on our indebtedness. We currently have debt obligations covering the purchase of our two ARAM ARIES recording systems that require monthly payments between approximately $67,000 and $81,000 for the first ARAM ARIES recording system and between approximately $94,000 and $114,000 for the second ARAM ARIES recording system, each over 36 month terms. Any decline in our operations could inhibit our ability to make these substantial monthly payments. In light of the short terms of these notes, a failure to make the monthly payments on these notes could cause our lenders to promptly foreclose on the assets securing these notes. The foreclosure of certain of our core assets securing these notes could severely limit our ability to continue operations.

We may be subject to liability claims that are not covered by our insurance.

Our business is subject to the general risks inherent in land-based seismic data acquisition activities. Our activities are often conducted in remote areas under dangerous conditions, including the detonation of dynamite. These operations are subject to risks of injury to personnel and equipment. Our crews are mobile, and equipment and personnel are subject to vehicular accidents. These risks could cause us to experience equipment losses, injuries to our personnel and interruptions in our business.

In addition, we could be subject to personal injury or real property damage claims in the normal operation of our business. Such claims may not be covered under the indemnification provisions in our general service agreements to the extent that the damage is due to our negligence, gross negligence or intentional misconduct.

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We do not carry insurance against certain risks that we could experience, including business interruption resulting from equipment maintenance or weather delays. We obtain insurance against certain property and personal casualty risks and other risks when such insurance is available and when our management considers it advisable to do so. Currently we maintain employers liability with limits of $1,000,000 per accident and $2,000,000 in aggregate, commercial general liability of $1,000,000 per accident and $2,000,000 in aggregate, pollution liability of $1,000,000 per accident and $2,000,000 in aggregate, automobile liability with a $1,000,000 combined single limit and a $10,000,000 umbrella policy. Our general service agreements require us to have specific amounts of insurance. There can be no assurance, however, that any insurance obtained by us will be adequate to cover any losses or liabilities, or that this insurance will continue to be available or available on terms which are acceptable to us. Liabilities for which we are not insured, or which exceed the policy limits of our applicable insurance, could have a materially adverse effect on us.

We will be subject to the requirements of Section 404 of the Sarbanes-Oxley Act. If we are unable to timely comply with Section 404 or if the costs related to compliance are significant, our profitability, stock price and results of operations and financial condition could be materially adversely affected.

We will be required to comply with the provisions of Section 404 of the Sarbanes-Oxley Act of 2002 by December 31, 2006. Section 404 requires that we document and test our internal control over financial reporting and issue management’s assessment of our internal control over financial reporting. This section also requires that our independent registered public accounting firm opine on those internal controls and management’s assessment of those controls. We are currently evaluating our existing controls against the standards adopted by the Committee of Sponsoring Organizations of the Treadway Commission, or COSO. During the course of our ongoing evaluation and integration of the internal control over financial reporting, we may identify areas requiring improvement, and we may have to design enhanced processes and controls to address issues identified through this review.

We believe the out-of-pocket costs, the diversion of management’s attention from running the day-to-day operations and operational changes caused by the need to comply with the requirements of Section 404 of the Sarbanes-Oxley Act could be significant. If the time and costs associated with such compliance exceed our current expectations, our profitability could be affected.

We cannot be certain at this time that we will be able to successfully complete the procedures, certification and attestation requirements of Section 404 or that we or our auditors will not identify material weaknesses in internal control over financial reporting. If we fail to comply with the requirements of Section 404 or if we or our auditors identify and report any material weakness, the accuracy and timeliness of the filing of our annual and quarterly reports may be negatively affected and could cause investors to lose confidence in our reported financial information, which could have a negative effect on the trading price of our common stock. In addition, a material weakness in the effectiveness of our internal control over financial reporting could result in an increased chance of fraud and the loss of customers, reduce our ability to obtain financing and require additional expenditures to comply with these requirements, each of which could negatively impact our business, profitability and financial condition.

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Industry Risks

We derive all of our revenues from companies in the oil and natural gas exploration and development industry, a historically cyclical industry with levels of activity that are significantly affected by the levels and volatility of oil and natural gas prices.

Any prolonged reduction in the overall level of exploration and development activities, whether resulting from changes in oil and natural gas prices or otherwise, can adversely impact us in many ways by negatively affecting:

·       our revenues, cash flows and profitability;

·       our ability to maintain or increase our borrowing capacity;

·       our ability to obtain additional capital to finance our business and the cost of that capital; and

·       our ability to attract and retain skilled personnel whom we would need in the event of an upturn in the demand for our services.

Worldwide political, economic and military events have contributed to oil and natural gas price volatility and are likely to continue to do so in the future. Depending on the market prices of oil and natural gas, oil and natural gas exploration and development companies may cancel or curtail their drilling programs, thereby reducing demand for our services. Oil and natural gas prices have been volatile historically and, we believe, will continue to be so in the future. Many factors beyond our control affect oil and natural gas prices, including:

·       the cost of exploring for, producing and delivering oil and natural gas;

·       the discovery rate of new oil and natural gas reserves;

·       the rate of decline of existing and new oil and natural gas reserves;

·       available pipeline and other oil and natural gas transportation capacity;

·       the ability of oil and natural gas companies to raise capital;

·       actions by OPEC (the Organization of Petroleum Exporting Countries);

·       political instability in the Middle East and other major oil and natural gas producing regions;

·       economic conditions in the U.S. and elsewhere;

·       domestic and foreign tax policy;

·       weather conditions in the U.S. and elsewhere;

·       the pace adopted by foreign governments for the exploration, development and production of their national reserves;

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

·       the overall supply and demand for oil and natural gas.

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The high fixed costs of our operations could result in operating losses.

Companies within our industry are typically subject to high fixed costs which primarily consist of depreciation, a non-cash item, and maintenance expenses associated with their seismic data acquisition equipment and crew costs. In addition, ongoing maintenance capital expenditures, as well as new equipment investment, can be significant. As a result, any extended periods of significant downtime or low productivity caused by reduced demand, weather interruptions, equipment failures, permit delays or other causes could adversely affect our results of operations.

Our operations are subject to delays related to obtaining land access rights of way from third parties which could affect our results of operations.

Our seismic data acquisition operations could be adversely affected by our inability to obtain timely right of way usage from both public and private land and/or mineral owners. Delays associated with obtaining such rights of way could negatively affect our results of operations.

Our industry has recently experienced shortages in the availability of equipment. Any difficulty we experience replacing or adding equipment could adversely affect our business.

We may not be able to acquire equipment to replace our existing equipment or add additional equipment. The high demand for the services that we provide has decreased the supply of geophysical equipment, resulting in extended delivery dates on orders of new equipment. Any delay in obtaining equipment could delay the implementation of additional crews and restrict the productivity of our existing crews. Although we are in discussions regarding the purchase of up to eight vibration vehicles to be delivered in the first quarter of 2006, the acquisition of these additional units from the proceeds of this offering could be delayed for several months due to the high demand for the vehicles. A delay in obtaining equipment essential to our operations could have a material adverse effect on our operations.

Our business is subject to government regulation which may adversely affect our future operations.

Our operations are subject to a variety of federal, state and local laws and regulations, including laws and regulations relating to the protection of the environment and archeological sites. We are required to expend financial and managerial resources to comply with such laws and related permit requirements in our operations, and we anticipate that we will continue to be required to do so in the future. Although such expenditures historically have not been material to us, the fact that such laws or regulations change frequently makes it impossible for us to predict the cost or impact of such laws and regulations on our future operations. The adoption of laws and regulations that have the effect of reducing or curtailing exploration and development activities by energy companies could also adversely affect our operations by reducing the demand for our services.

Risks Related To Our Common Stock And This Offering

Our common stock has experienced, and may continue to experience, price volatility and low trading volume.

Our stock price is subject to significant volatility. Overall market conditions including a decline in oil and natural gas prices, in addition to other risks and uncertainties described in this “Risk Factors” section and elsewhere in this prospectus, may cause the market price of our common stock to fall. Our high and low closing stock prices for the 12 months ended August 30, 2005 were $11.70 and $1.65, respectively.

Our common stock is listed on the American Stock Exchange under the symbol “TGE.” However, daily trading volumes for our common stock are, and may continue to be, relatively small compared to many other publicly traded securities. For example, since April 18, 2005, when we began trading on the

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American Stock Exchange, our daily trading volume has been as low as 1,600 shares. We cannot assure you that this offering will increase the trading volume for our common stock. It may be difficult for you to sell your shares in the public market at any given time at prevailing prices, and the price of our common stock may, therefore, be volatile.

Purchasers of common stock will experience immediate and substantial dilution.

Based on an assumed offering price of $              per share and assuming the conversion of all of our outstanding 81¤2% Senior Convertible Preferred Stock into our common stock, purchasers of our common stock in this offering will experience an immediate and substantial dilution of $              per share in the net tangible book value per share of common stock from the public offering price and our pro forma net tangible book value as of June 30, 2005 after giving effect to this offering would be $              per share. You will incur further dilution if outstanding options exercisable into 227,000 shares of our common stock and warrants that are not being purchased but remain exercisable into 26,000 shares of our common stock are exercised. In addition, our Restated Articles of Incorporation allows us to issue significant numbers of additional shares.

The large number of shares eligible for public sale could depress the market price of our common stock.

The market price for our common stock could decline as a result of sales of a large number of shares of our common stock in the market after this offering, and the perception that these sales could occur may depress the market price. Based on shares outstanding as of August 30, 2005, and assuming all the shares of our 81¤2% Senior Convertible Preferred Stock convert into common stock prior to this offering, we will have outstanding 14,481,437 shares of common stock after this offering. We have a registration statement on Form SB-2 on file with the SEC to cover the resale of our common stock by certain non-affiliates issuable upon the conversion of our 81¤2% Senior Convertible Preferred Stock. As of August 30, 2005, there are 747,464 shares outstanding of our 81¤2% Senior Convertible Preferred Stock that are held by non-affiliates and are convertible into 747,464 shares of our common stock. An additional 227,000 shares of our common stock are issuable upon exercise of outstanding stock options (of which 83,667 shares are currently exercisable) and 26,000 shares of our common stock are issuable upon exercise of outstanding warrants that are not being repurchased by the Company.

Our officers and directors own a large percentage of our common stock, and they may control our business and affairs.

Upon completion of this offering, our officers and directors as a group will beneficially own approximately 31.4% of our common stock. As a result, they will continue to be able to exercise significant influence, and in most cases control, over matters requiring shareholder approval, including the election of directors, changes to our charter documents and significant corporate transactions. This concentration of ownership makes it unlikely that any other holder or group of holders of our common stock will be able to affect the way we are managed or the direction of our business. The continued concentrated ownership of our common stock will make it difficult for another company to acquire us and for you to receive any related takeover premium for your shares (unless the controlling group approves the acquisition).

We will have broad discretion over the use of proceeds from this offering and may use the proceeds in a manner significantly different from our current plans.

While we currently expect to use the net proceeds from this offering for the purchase of new equipment, the repurchase of stock purchase warrants exercisable into 3,516,645 shares of our common stock, and for working capital and general corporate purposes, we will have broad discretion to adjust the application and allocation of the net proceeds, other than with respect to the repurchase of the warrants.

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Our expectations regarding future business needs may prove to be inaccurate. Accordingly, we will retain broad discretion in the allocation of the net proceeds from this offering, and we reserve the right to change the use of these proceeds as a result of contingencies such as the timing and purchase of equipment. The success of our operations is influenced by capital expenditures and working capital allocations and will substantially depend upon our discretion and judgment with respect to the application and allocation of the net proceeds from this offering.

Certain provisions of our Restated Articles of Incorporation may make it difficult for a third party to acquire us or may adversely impact your rights as a common shareholder.

Our Restated Articles of Incorporation contain provisions that require the approval of holders of 80% of our issued and outstanding shares before we can enter into a merger or other business combination or sell all or substantially all of our assets. Additionally, if we increase the size of our board from the current six to nine directors, we could be required to stagger our directors’ terms and our directors could not be removed without approval of holders of 80% of our issued and outstanding shares. These provisions could discourage or impede a tender offer, proxy contest or other similar transaction involving control of us.

In addition, our board of directors has the right to issue preferred stock upon such terms and conditions as it deems to be in the best interest of the Company. The terms of such preferred stock may adversely impact the dividend and liquidation rights of the common shareholders without the approval of the common shareholders.

We do not intend to pay cash dividends on our common stock in the foreseeable future, and therefore only appreciation of the price of our common stock will provide a return to our shareholders.

While there are currently no restrictions prohibiting us from paying dividends to our shareholders, we have not paid any cash dividends on our common stock in the past, and we do not anticipate paying any dividends in the foreseeable future. Payment of any cash dividends in the future, however, is in the discretion of our board of directors and will depend on our financial condition, results of operations, capital and legal requirements and other factors deemed relevant by our board of directors. Earnings, if any, are expected to be retained to fund our future operations.

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FORWARD-LOOKING STATEMENTS

This prospectus includes “forward-looking statements” as defined in Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), which reflect our view with respect to future events. We base these forward-looking statements on our current expectations and projections about future events. These forward looking statements are subject to risks, uncertainties and assumptions about the Company, including:

·       dependence upon energy industry spending for seismic data acquisition services;

·       the unpredictable nature of forecasting weather;

·       the potential for contract delay or cancellation;

·       the potential for fluctuations in oil and natural gas prices; and

·       the availability of capital resources.

We use the words “may,” “will,” “can,” “could,” “should,” “expect,” “anticipate,” “estimate,” “believe,” “target,” “continue,” “intend,” “plan,” “budget” and other similar words to identify forward-looking statements. You should read statements that contain these words carefully because they discuss future expectations, contain projections of results of operations or of our financial condition and/or state other “forward-looking” information. We do not undertake any obligation to update or revise publicly any forward-looking statements, except as required by law. These statements also involve risks and uncertainties that could cause our actual results or financial condition to materially differ from our expectations in this prospectus.

We believe that it is important to communicate our expectations of future performance to our investors. However, events may occur in the future that we are unable to accurately predict, or over which we have no control. When considering our forward-looking statements, you should keep in mind the risk factors and other cautionary statements in this prospectus and other factors noted throughout this prospectus. There are many risks, uncertainties and events that may cause our actual results to differ materially from those contained in any forward-looking statement. Please read the section entitled “Risk Factors” for a discussion of certain risks of our business and an investment in our common stock.

MARKET DATA AND FORECASTS

Unless otherwise indicated, information in this prospectus concerning economic conditions and our industry is based on information from independent industry analysts and publications as well as our estimates. Our estimates are derived from publicly available information released by third-party sources, as well as data from our internal research, and are based on such data and our knowledge of our industry, which we believe to be reasonable. None of the independent industry publications used in this prospectus were prepared on our or our affiliates’ behalves, and none of the sources cited in this prospectus has consented to the inclusion of any data from its reports, nor have we sought consent from any of them.

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USE OF PROCEEDS

We estimate that our net proceeds from this offering will be approximately $      , or approximately $       if the underwriters’ over-allotment option is exercised in full (in each case after deducting underwriting discounts and commissions, the estimated offering expenses and, if the over-allotment option is exercised in full, the proceeds to be received by the selling shareholders from the exercise of the underwriters’ over-allotment option). We intend to use the net proceeds from this offering as follows:

·       approximately $         to repurchase and cancel stock purchase warrants exercisable into 3,516,645 shares of our common stock;

·       approximately $4,000,000 will be used to purchase one additional ARAM ARIES recording system;

·       approximately $3,000,000 will be used to purchase peripheral seismic equipment, including up to eight vibration vehicles, to be delivered by the end of the first quarter 2006; and

·       for working capital and general corporate purposes.

The amounts set forth above for the purchase of the ARAM ARIES recording system and peripheral seismic equipment, including up to eight vibration vehicles, are estimates, and the exact amount that we will spend cannot yet be determined. Accordingly, we will retain broad discretion in the allocation of the net proceeds from this offering, and we reserve the right to change the use of these proceeds as a result of contingencies such as change of market conditions, change of future contract requirements and change of equipment availability. Depending upon the outcome of these contingencies, we may allocate substantially greater or lesser amounts to working capital and general corporate purposes. Pending the uses described above, we will invest the net proceeds in short-term, interest-bearing, investment-grade securities.

We will enter into an agreement with all of our directors to repurchase outstanding warrants exercisable into 3,516,645 shares of our common stock at the public offering price less the exercise price (the “in the money value”) and an amount equal to the underwriting discounts and commissions on the in the money value. Our obligation to repurchase these warrants is conditioned on the closing of this offering.

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MARKET FOR COMMON STOCK AND RELATED SHAREHOLDER MATTERS

Market Prices

From May 25, 2002 through April 15, 2005, our common stock was traded over-the-counter on the National Association of Securities Dealers, Inc. Over-The-Counter Bulletin Board System (using the trading symbol “TGCI”). Because of our improved financial condition which has led to a substantial increase in our stock price and the market value of our publicly held shares, we qualified for, and began trading on, the American Stock Exchange on April 18, 2005, under our current trading symbol “TGE.”

The high and low bid prices shown below, through April 15, 2005, represent prices among the dealers and do not include retail mark-ups, mark-downs or commissions, and do not necessarily represent actual transactions. Beginning on April 18, 2005, the table shows the high and low sales prices reported for our common stock.

The last reported sales price for our common stock on August 30, 2005 was $9.90. The number of shareholders of record of our common stock as of August 30, 2005, was 119. Due to the number of shares held in nominee or street name, we believe that there are a significantly greater number of beneficial owners of our common stock. As of such date, Cede & Co. held 5,115,479 shares in street name.

DIVIDEND POLICY

While there are currently no restrictions prohibiting us from paying dividends to our shareholders, we have not paid any cash dividends on our common stock in the past, and we do not anticipate paying any dividends in the foreseeable future. Payment of any cash dividends in the future, however, is in the discretion of our board of directors and will depend on our financial condition, results of operations, capital and legal requirements and other factors deemed relevant by our board of directors. Earnings, if any, are expected to be retained to fund our future operations.

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CAPITALIZATION

The following table sets forth our cash, cash equivalents and short-term investments and our capitalization as of June 30, 2005:

·       on an historical basis, which reflects our actual capitalization as of June 30, 2005, without any adjustments to reflect subsequent or anticipated events;

·       on a pro forma as adjusted basis, which reflects our capitalization as of June 30, 2005 with adjustments to reflect the issuance of 126,100 shares of common stock resulting from the conversion of 126,100 shares of our 81¤2% Senior Convertible Preferred Stock, the issuance of 2,519,664 shares of common stock resulting from the expected conversion of the remaining shares of our 81¤2% Senior Convertible Preferred Stock into shares of our common stock and the sale of the 5,500,000 shares of common stock offered by us in this offering, after deducting estimated underwriting discounts and commissions, and after giving effect to our receipt and application of the estimated net proceeds from this offering.

You should read this table together with “Selected Financial Data,” and “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and our financial statements and notes thereto included elsewhere in this prospectus.

The number of shares of our common stock in the historical and pro forma as adjusted columns in the table above does not include the following securities outstanding as of June 30, 2005:

·       238,000 shares of our common stock issuable on June 30, 2005, upon exercise of outstanding options issued under our stock option plan at a weighted exercise price of $2.01 per share are excluded from the historical June 30, 2005 column, while 227,000 shares of our common stock currently issuable upon exercise of outstanding options issued under our stock option plan at a weighted exercise price of $2.06 per share are excluded from the pro forma as adjusted column.

·       26,000 shares of our common stock issuable upon exercise of outstanding warrants with a weighted exercise price of $1.00 per share. These warrants do not constitute part of the stock purchase warrants being repurchased and cancelled by the Company.

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SELECTED FINANCIAL DATA

The following table sets forth our summary financial data for the periods indicated. The summary financial data for the years ended December 31, 2002, 2003 and 2004 are derived from our audited financial statements. The summary financial data for the six months ended June 30, 2004 and 2005 are derived from our unaudited financial statements and includes, in management’s opinion, all adjustments necessary for a fair presentation of our financial position as of such date and our results of operations for such period. You should read the following summary financial data in conjunction with “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” and the financial statements and notes thereto, included elsewhere in this prospectus. Our results of operations for the six month period ended June 30, 2005, may not be indicative of results that may be expected for the full year. The following table presents a non-GAAP financial measure, EBITDA. This measure is not calculated or presented in accordance with GAAP. We explain this measure below and reconcile it to its most directly comparable financial measures calculated and presented in accordance with GAAP in “Non-GAAP Financial Measures” below.

(1)          In July 2005, we put into operation our second ARAM ARIES recording system which has 4,000 recording channels, increasing the total number of working crews to four and available recording channels to 14,000.

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The following table sets forth a summary of our balance sheet data as of June 30, 2005 on a historical basis and on a pro forma as adjusted basis to reflect our receipt of estimated net proceeds from our sale of 5,500,000 shares of common stock in this offering, after deducting underwriting discounts and commissions and estimated offering expenses and the application of those net proceeds.

(1)          On a pro forma as adjusted basis, which reflects our capitalization as of June 30, 2005 with adjustments to reflect the issuance of 126,100 shares of common stock resulting from the conversion of 126,100 shares of our 81¤2% Senior Convertible Preferred Stock, the issuance of 2,519,664 shares of common stock resulting from the expected conversion of the remaining shares of our 81¤2% Senior Convertible Preferred Stock into shares of our common stock and the sale of the 5,500,000 shares of common stock offered by us in this offering , after deducting estimated underwriting discounts and commissions, and after giving effect to our receipt and application of the estimated net proceeds from this offering.

Non-GAAP Financial Measure

We define EBITDA as net income plus expenses of interest, income taxes, depreciation and amortization. We use EBITDA as a supplemental financial measure to assess:

·       the financial performance of our assets without regard to financing methods, capital structures, taxes or historical cost basis;

·       our liquidity and operating performance over time and in relation to other companies that own similar assets and that we believe calculate EBITDA in a manner similar to us; and

·       the ability of our assets to generate cash sufficient for us to pay potential interest expenses.

We also understand that such data is used by investors to assess our performance. However, EBITDA is not a measure of operating income, operating performance or liquidity presented in accordance with GAAP. When assessing our operating performance or our liquidity, you should not consider this data in isolation or as a substitute for our net income, cash flow from operating activities, or other cash flow data calculated in accordance with GAAP. EBITDA excludes some, but not all, items that affect net income and operating income, and these measures may vary among other companies. Therefore, EBITDA as presented below may not be comparable to similarly titled measures of other companies. Further, the results presented by EBITDA cannot be achieved without incurring the costs that the measure excludes: interest, taxes, depreciation and amortization.

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The following table reconciles our EBITDA to our net income (loss) (Unaudited):

The following table reconciles our EBITDA to our net cash provided by (used in) operating activities (Unaudited):

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MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS

The following discussion and analysis should be read in conjunction with “Selected Financial Data” and our financial statements and related notes thereto included elsewhere in this prospectus. Portions of this document that are not statements of historical or current fact are forward-looking statements that involve risk and uncertainties, such as statements of our plans, objectives, expectations and intentions. The cautionary statements made in this prospectus should be read as applying to all related forward-looking statements wherever they appear in this prospectus. Our actual results could differ materially from those anticipated in the forward-looking statements. Factors that could cause our actual results to differ materially from those anticipated include those discussed in “Risk Factors,” “Business” and “Forward-Looking Statements.”

Overview

We are one of the leading providers of seismic data acquisition services in the continental U.S. We currently operate four seismic data acquisition crews. Substantially all of our revenues are derived from the seismic data acquisition services which we provide to our customers, primarily major and independent oil and natural gas exploration and development companies in the continental U.S. Demand for our services depends upon the level of spending by these oil and natural gas companies for exploration, production and development, which activities depend, in part, on oil and natural gas prices. Fluctuations in domestic oil and natural gas exploration activities and commodity prices have affected the demand for our services and our results of operations in years past and continue to have a significant impact on our business and results of operations.

Our return to profitability in 2003 after several years of losses is directly related to an increase in the level of exploration and development for domestic oil and natural gas. The increased level of exploration and development is a function of higher prices for oil and natural gas. As a result of the increase in domestic exploration spending, we have experienced an increased demand for our seismic data acquisition services.

We continue to focus on increasing revenues and profitability. Due to the fixed costs we incur, primarily consisting of depreciation, a non-cash item, and maintenance expenses associated with seismic data acquisition equipment, and crew costs, we strive to maintain high utilization rates for our crews. While our revenues are mainly affected by the level of customer demand for our services, our revenues are also affected by the pricing for our services that we negotiate with our customers. As a result of the fixed cost structure of our business, our profitability is affected by the level of productivity of our seismic data acquisition crews, including crew downtime related to inclement weather, unplanned equipment repairs or delays in acquiring land access permits. Consequently, our continued growth in revenues and improved profitability is, in part, due to our successful efforts to negotiate more favorable weather protection provisions in our service agreements with our customers, our ability to mitigate access permit delays and our continued efforts to improve overall crew productivity by purchasing equipment that operates more efficiently in our markets. Although our customers may cancel their supplemental service agreements with us on short notice, we believe that we currently have sufficient contracts to sustain operations at full capacity into 2006.

How We Generate Our Revenues

Our contracts are obtained either through competitive bidding or as a result of negotiations with customers. Contract terms offered by us are generally dependent on the complexity and risk of operations, energy source technique being used (vibroseis or dynamite), type of equipment and the anticipated duration of the work to be performed. The majority of our contracts are typically subject to termination by the customer upon 60 days advance written notice to us with little or no penalty.

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Contracts

Our seismic data acquisition general service agreements define certain obligations for us and for our customers. A supplemental agreement setting forth the terms of a specific project, which may be cancelled by either party on short notice, is entered into for every project. We currently operate under supplemental agreements that are either “turnkey” agreements providing for a fixed fee to be paid to us for each unit of data acquired, or “term” agreements providing for a fixed hourly, daily or monthly fee during the term of the project or projects. Turnkey agreements generally provide us more profit potential, but involve more risks because of the potential of crew downtime or operational delays. Under the term agreements, we forego an increased profit potential in exchange for a more consistent revenue stream with improved protection from crew downtime or operational delays. We attempt to negotiate on a project-by-project basis some level of weather downtime protection within our agreements. We strive to manage our crews and equipment as a portfolio, balancing the mix of turnkey and term contracts and the type of equipment we use whenever possible.

Our contracts require either dynamite or vibroseis energy source techniques. We incur higher costs on our dynamite contracts than on our vibroseis contract, due to the costs of third parties that provide dynamite services. Since we recognize additional revenues equivalent to our third party costs, our EBITDA margins are lower on our dynamite contracts.

How We Manage Our Operations

Our management team uses a variety of tools to manage our operations. These tools include monitoring our: (1) seismic crew performance; (2) project scheduling calendar; (3) schedule of pending proposals; and (4) safety performance.

Seismic crew performance.   We monitor crew performance on a daily basis by monitoring the production obtained by each crew on the previous day in relation to the type of geography, weather and type of acquisition technique being employed, vibroseis or dynamite. This review allows us to monitor the profitability of turnkey contracts and reallocate resources if necessary to increase productivity.

Project scheduling calendar.   Our management team reviews our project scheduling calendar on a daily basis. Monitoring this schedule allows management to schedule or reschedule projects to most efficiently utilize our resources. This continuous monitoring allows us to limit our crews’ downtime between jobs and helps us effectively communicate with customers concerning the estimated start dates and completion dates of pending projects.

Schedule of pending proposals.   We monitor on a daily basis our list of outstanding proposals. By monitoring this list, we are able to more effectively schedule our future projects and determine whether we need to follow up with the customer on any of the pending proposals.

Safety performance.   Maintaining a strong safety record is a critical component of our operational success. Our field level management team holds a safety meeting every day to discuss any safety issues that arose the previous day. In an effort to maintain our historic levels of safety performance, we have engaged a safety specialist through our insurance agency to conduct our safety training courses and review our safety reports on a regular basis.

Our Growth Strategies

We believe that there are significant opportunities for us to increase our revenues and market position in the continental U.S. onshore seismic market by:

·       Optimizing equipment and crew utilization;

·       Maintaining our state-of-the-art technology position;

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·       Maintaining our efficient management structure;

·       Managing the mix and terms of our contracts; and

·       Maintaining a conservative balance sheet and disciplined capital spending program.

Results of Operations

Six Months Ended June 30, 2005 Compared to Six Months Ended June 30, 2004

Revenues.   Our revenues were $12,947,724 for the six months ended June 30, 2005 compared to $7,754,069 for the same period of 2004, an increase of 67.0%. This increase in revenues was attributable to several factors including operating three seismic data acquisition crews in 2005 compared with two crews for the same period of 2004, increased demand for our services due to increased exploration and development activity by domestic oil and natural gas companies, price improvements and more favorable contract terms in our agreements with customers and the increased productivity derived from a new ARAM ARIES recording system, which was put into service in the fourth quarter of 2004.

Cost of services.   Cost of services includes the wages and expenses directly related to our field crews and support operations, as well as third party costs associated with certain contracts provided by non-employee contractors but excludes depreciation expense. Our cost of services was $7,298,355 for the six months ended June 30, 2005 compared to $5,440,662 for the same period of 2004, an increase of 34.1%. This increase was principally attributable to our increase in revenues. However, as a percentage of revenues, cost of services was 56.3% for the six months ended June 30, 2005 compared to 70.2% for the same period of 2004, a decrease of 13.9%. This decrease was primarily attributable to the mix of contracts (dynamite or vibroseis), job specific equipment rental expense that occurred in the second quarter of 2004 and the increased productivity attributable to the new ARAM ARIES recording system.

Selling, general and administrative.   Selling, general and administrative (“SG&A”) expenses include the wages and salaries of administrative and sales personnel, as well as other general overhead costs not directly related to field operations. SG&A expenses were $924,625 for the six months ended June 30, 2005 compared to $562,532 for the same period of 2004, an increase of 64.4%. This increase was primarily attributable to additional expenses associated with the Company’s common stock being listed on the American Stock Exchange, additional compensation expense accrued for incentive bonuses, increased insurance costs and additional expenses associated with the operation of three crews during the first half of 2005 compared to two crews in the same period of 2004. However, SG&A expenses as a percent of revenues decreased to 7.1% for the first half of 2005 from 7.3% in the first half of 2004.

Depreciation expense.   Depreciation expense was $1,026,733 for the six months ended June 30, 2005 compared to $432,709 for the same period of 2004, an increase of 137.3%. This increase was primarily attributable to capital expenditures of $5,794,553 in 2004 for which depreciation expense was realized for the six months ended June 30, 2005. As a result, depreciation as a percent of revenues was 7.9% during the first half of 2005 compared to 5.6% during the first half of 2004, an increase of 2.3%.

Income from operations.   Income from operations was $3,698,011 for the six months ended June 30, 2005 compared to $1,318,166 for the same period of 2004, an increase of 180.5%. This increase was primarily attributable to the increase in revenues and the improvement in our cost of services and SG&A expenses, partially offset by increases in depreciation expense. EBITDA increased $2,974,000 to $4,725,000 in the first half of 2005 from $1,751,000 in the first half of 2004, an increase of 169.8%. This increase was a result of factors mentioned above and greater absorption of our fixed operating costs. EBITDA as a percentage of revenues for the first six months of 2005 was 36.5% compared to 22.6% for the same period in 2004. For a definition of EBITDA, a reconciliation of EBITDA to net income and a discussion of EBITDA, please refer to the section entitled “EBITDA” found above in “Selected Financial Data.”

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Interest expense.   Interest expense was $79,362 for the six months ended June 30, 2005 compared to $8,402 for the same period of 2004. This increase was primarily attributable to the debt incurred for the purchase of our first ARAM ARIES recording system in October 2004.

Income tax expense.   Income tax expense was $753,252 for the six months ended June 30, 2005. No income tax expense was recorded in the same period of 2004. At December 31, 2004, we had net operating loss carryforwards of approximately $4,980,000 available to offset future taxable income that expire at various dates through 2024. The Company anticipates the net operating loss carryforwards will be utilized during 2005 and the Company will incur federal income taxes as well as income taxes from various states. See Note I of Notes to Financial Statements attached hereto.

Year Ended December 31, 2004 Compared to Year Ended December 31, 2003

Revenues.   Our revenues were $20,084,175 for the year ended December 31, 2004 compared to $8,468,051 for the year ended December 31, 2003, an increase of 137.2%. This increase in revenues was attributable to several factors including operating two seismic data acquisition crews the first half of 2004 and three crews the second half of 2004 compared with operating only one crew for the entire year of 2003 and increased demand for our services due to increased exploration and development activity by domestic oil and natural gas companies. In addition, beginning in the fourth quarter of 2004, market conditions allowed us to negotiate price improvements and more favorable contract terms in our agreements with customers.

Cost of services.   Our cost of services were $14,707,648 for the year ended December 31, 2004 compared to $5,654,868 for the year ended December 31, 2003, an increased of 160.1%. This increase was principally attributable to an increase in our revenues. However, as a percentage of revenues, cost of services was 73.2% for the year ended December 31, 2004 compared to 66.8% for the year ended December 31, 2003, an increase of 6.4%. This increase was primarily attributable to the mix of contracts and job specific equipment rental expense that occurred in 2004.

Selling, general and administrative.   SG&A expenses were $1,277,161 for the year ended December 31, 2004 compared to $912,684 for the year ended December 31, 2003, an increase of 39.9%. This increase was due to several factors including an increase in legal expenses associated with the filing of a resale registration statement for the common stock issuable upon conversion of our 81¤2% Senior Convertible Preferred Stock, an increase in public company expenses associated with the hiring of a public relations firm, an increase in incentive compensation for incentive bonuses and expenses associated with the higher level of revenues. However, SG&A expense as a percentage of revenues decreased to 6.4% for the year ended December 31, 2004 from 10.8% for the year ended December 31,2003.

Depreciation expense.   Depreciation expense was $1,106,022 for the year ended December 31, 2004 compared to $1,314,042 for the year ended December 31, 2003, a decrease of 15.8%. This decrease was primarily attributable to a low level of capital expenditures in 2003 and fixed assets that became fully depreciated in 2003. As a result, depreciation expense as a percent of revenues was 5.5% for the year ended December 31, 2004 compared to 15.5% for the year ended December 31, 2003.

Income from operations.   Income from operations was $2,993,344 for the year ended December 31, 2004 compared to $586,457 for the year ended December 31, 2003, an increase of 410.4%. This increase was primarily attributable to the increase in revenues, a decrease in depreciation expense but partially offset by an increase in SG&A. EBITDA increased $2,221,367 to $4,099,366 for the year ended December 31, 2004 from $1,877,999 for the year ended December 31, 2003, an increase of 118.3%. This increase was a result of factors mentioned above. EBITDA as a percentage of revenues for 2004 was 20.4% compared to 22.2% in 2003. For a definition of EBITDA, a reconciliation of EBITDA to net income and a discussion of EBITDA please refer to the section entitled “EBITDA” found above in “Selected Financial Data.”

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Interest expense.   Interest expense was $60,878 for the year ended December 31, 2004 compared to $8,792 for the year ended December 31, 2003. This increase was primarily attributable to the debt incurred for the purchase of our first ARAM ARIES recording system in October 2004.

Income tax expense.   Income tax expense was $64,127 for the year ended December 31, 2004. No income tax expense was recorded in the year ended December 31, 2003. At December 31, 2004, we had net operating loss carryforwards of approximately $4,980,000 available to offset future taxable income that expire at various dates through 2024.

Debt financing costs.   Debt financing costs were $22,500 for the year ended December 31, 2003. These debt financing costs were associated with 1,500,000 stock purchase warrants issued in 2003. We did not incur any debt financing costs in 2004. See “Capital Resources” below for a discussion of the stock purchase warrants issued in 2003.

Year Ended December 31, 2003 Compared to Year Ended December 31, 2002

Revenues.   Our revenues were $8,468,051 for the year ended December 31, 2003 compared to $6,262,206 for the year ended December 31, 2002, an increase of 35.2%. This increase in revenues was attributable to several factors including our successful entry into the vibroseis market with a significant portion of our 2003 revenues being generated from vibroseis contracts. As a result, we were able to operate one seismic data acquisition crew the entire year of 2003. We were unable to keep a crew employed all 12 months of 2002.

Cost of services.   Our cost of services was $5,654,868 for the year ended December 31, 2003 compared to $5,529,445 for the same year ended December 31, 2002, an increase of 2.3%. This increase was principally attributable to our increase in revenues. However, as a percentage of revenues, cost of services was 66.8% for the year ended December 31, 2003 compared to 88.3% for the same period of 2002, a decrease of 21.5%. This decrease was primarily attributable to the mix of contracts and the absorption of fixed costs as a result of the increase in revenues in 2003.

Selling, general and administrative.   SG&A expenses were $912,684 for the year ended December 31, 2003 compared to $859,648 for the year ended December 31, 2002, an increase of 6.2%. This increase was primarily attributable to additional expenses associated with the higher revenues in year 2003 compared with year 2002. However, SG&A expenses as a percent of revenues decreased to 10.8% for the year ended December 31, 2003 from 13.7% for the year ended December 31, 2002.

Depreciation expense.   Depreciation expense was $1,314,042 for the year ended December 31, 2003 compared to $1,522,815 for the year ended December 31, 2002, a decrease of 13.7%. This decrease was primarily attributable to a low level of capital expenditures in 2002 and fixed assets that became fully depreciated in 2002. As a result, depreciation as a percent of revenues was 15.5% for the year ended December 31, 2003, compared to 24.3% for the year ended December 31, 2002, a decrease of 8.8%.

Income (loss) from operations.   Income from operations was $586,457 for the year ended December 31, 2003 compared to a loss of $1,649,702 for the year ended December 31, 2003. This increase was primarily attributable to an increase in revenues and an improvement in our margins as a result of a larger portion of our revenues being generated from vibroseis contracts and a reduction in depreciation expense. EBITDA increased $2,049,886 to $1,877,999 in the year ended December 31, 2003 from $(171,887) for the year ended December 31, 2002. This increase was a result of factors mentioned above. EBITDA as a percentage of revenues for 2003 was 22.2% compared to (2.7)% in 2002. For a definition of EBITDA, a reconciliation of EBITDA to net income and a discussion of EBITDA, please refer to the section entitled “EBITDA” found above in “Selected Financial Data.”

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Interest expense.   Interest expense was $8,792 for the year ended December 31, 2003 compared to $16,807 for the ended December 31, 2002. This decrease was attributable to lower levels of debt in 2003 compared with 2002.

Debt financing costs.   Debt financing costs were $22,500 for the year ended December 31, 2003 compared to $45,000 for the same period of 2002. These debt financing costs were associated with 1,500,000 and 750,000 stock purchase warrants issued in 2003 and 2002, respectively. See “Capital Resources” below for a discussion of the stock purchase warrants issued in 2003 and 2002.

Income tax expense.   No income tax expense was recorded for the years ended December 31, 2003 and 2002. At December 31, 2003, we had net operating loss carryforwards of approximately $7,900,000 available to offset future taxable income that expire at various dates through 2023.

General Trends and Outlook

We expect that the primary factor influencing demand for seismic data acquisition services in our industry will continue to be the level of exploration and development activity by oil and natural gas companies, which in turn, depends largely on current and anticipated crude oil and natural gas prices and depletion and consumption rates. In addition, the EIA recently forecast that U.S. oil and natural gas consumption will increase at an average annual rate of 1.5% through 2025. Conversely, the EIA forecasts that U.S. oil production will continue to decline at an average annual rate of (0.8%) and natural gas production will increase at an average annual rate of only 0.6%.

We believe that historical data and industry forecasts suggest an increasing demand for oil and natural gas coupled with a flat or declining production curve, which should result in the continuation of historically high oil and natural gas prices. We anticipate that oil and natural gas exploration and development companies will continue to respond to sustained increases in demand and declines in production by expanding their exploration activities and increasing their capital spending and need for seismic data acquisition services.

Liquidity and Capital Resources

Liquidity

Cash flows from operating activities.

Net cash provided by operating activities was $5,662,587 for the six months ended June 30, 2005 compared to $4,711,473 for the same period of 2004. The $951,114 increase in the first six months of 2005 was principally due to a $1,555,633 increase in net income and a $594,024 increase in depreciation expense offset by a gain on the disposal of equipment of $102,950 and a net decrease in operating assets and liabilities of $1,078,762.

Net cash provided by operating activities was $4,165,754 for the year ended December 31, 2004 compared to $1,066,743 for the year ended December 31, 2003. The $3,099,011 increase in 2004 was principally due to a $2,313,234 increase in net income, a decrease in depreciation expense of $208,020 and a net increase in operating assets and liabilities of $982,266.

Net cash provided by operating activities was $1,066,743 for the year ended December 31, 2003 compared to net cash used in operating activities of $404,100 for the year ended December 31, 2002. The $1,470,843 increase in the year 2003 was principally due to a $2,266,674 increase in net income offset by a decrease in depreciation expense of $208,773 and a net decrease in operating assets and liabilities of $550,609.

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Cash flows used in investing activities.

Net cash used in investing activities was $1,227,158 for the six months ended June 30, 2004 and $2,350,779 for the six months ended June 30, 2005. This increase was due to cash capital expenditures of $2,453,729 in the six months ended June 30, 2005 compared to $1,227,158 for the same period of 2004 offset by proceeds from the sale of equipment of $102,950. The non-cash capital expenditures, consisting of capital lease obligations and financed equipment purchases, for the six months ended June 30, 2005 and 2004 were $3,621,711 and $411,869, respectively.

Net cash used in investing activities was $2,636,741 for the year ended December 31, 2004 and $295,610 for the year ended December 31, 2003. This increase was due to cash capital expenditures of $2,637,991 in 2004 compared to cash capital expenditures of $314,959 in 2003 offset by proceeds from the sale of equipment of $1,250 in 2004 and $19,349 in 2003. The non-cash capital expenditures, consisting of capital lease obligations and financed equipment purchases, for the years ended December 31, 2004 and 2003 were $3,156,562 and $174,315, respectively.

Net cash used in investing activities was $295,610 for the year ended December 31, 2003 and $70,377 for the year ended December 31, 2002. This increase was due to cash capital expenditures of $314,959 in 2003 compared to cash capital expenditures of $70,377 in 2002 offset by proceeds from the sale of equipment of $19,349 in 2003. The non-cash capital expenditures, consisting of capital lease obligations and financed equipment purchases, for the years ended December 31, 2003 and 2002 were $174,315 and $100,419, respectively.

Cash flows used in financing activities.

Net cash used in financing activities was $252,355 for the six months ended June 30, 2004 and $789,793 for the six months ended June 30, 2005. This increase was primarily due to an increase in the amount of principal payments on our outstanding notes payable and capital lease obligations of $555,537 in the aggregate.

Net cash used in financing activities was $724,330 for the year ended December 31, 2004 and $269,032 for the year ended December 31, 2003. This increase was primarily due to an increase in the amount of principal payments on our outstanding notes payable and capital lease obligations of $192,293 in the aggregate and the payment of preferred stock dividends of $289,830.

Net cash used in financing activities was $269,032 for the year ended December 31, 2003 and $46,364 for the year ended December 31, 2002. This increase was due primarily to an increase in the amount of principal payments on our outstanding notes payable and capital lease obligations of $72,668 in the aggregate, offset by the proceeds from the issuance of debt of $150,000 in 2002.

Capital expenditures.

The seismic data acquisition services business is capital intensive, requiring significant investment to maintain state-of-the-art equipment and expand operations. Our capital expenditures have consisted primarily of acquisitions of new recording systems and the replacement of equipment that has reached the end of its useful life.

During the six months ended June 30, 2005, capital expenditures of $6,075,440 were used to acquire additional seismic equipment and vehicles. In addition, in May 2005 we entered into an equipment sales contract to purchase three new vibration vehicles for a cost of approximately $1,026,000. We anticipate delivery of these vibration vehicles will be prior to September 30, 2005. We have a verbal commitment from a lender to finance these vibration vehicles for a period of 36 months at a fixed per annum interest rate of 7.25%.

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During the year ended December 31, 2004, capital expenditures of $5,794,553 were used to acquire additional seismic equipment needed to operate three seismic crews and replace certain vehicles and equipment. In October 2004, we completed a $2,386,649 loan transaction with a commercial lender for the purpose of providing funds for the purchase of a new ARAM ARIES recording system. The loan is repayable over a period of 36 months at a fixed per annum interest rate of 6.85%. The loan is collateralized by the new recording system equipment and the recording vehicle and two semi-trailers that transport the equipment between projects.

During the year ended December 31, 2003 and 2002, capital expenditures of $489,274 and $170,796, respectively, were used to replace certain vehicles and equipment.

From the proceeds of this offering, we anticipate purchasing one new ARAM ARIES recording system for approximately $4,000,000 and peripheral seismic equipment, including up to eight new vibration vehicles, for approximately $3,000,000 to be delivered in the first quarter 2006. See “Use of Proceeds.’’

Capital Resources

Historically, we have relied on cash generated from operations and short-term borrowings from commercial banks and equipment lenders and loans from directors to fund our working capital requirements and capital expenditures.

Several years ago we experienced an inadequacy of cash to enable us to sustain our desired level of operations. We sought financing from third parties to meet our cash needs but found such financing unavailable. As a result, certain of our directors have provided us with the necessary funds. In 1999, we issued subordinated promissory notes payable in an aggregate principal amount of $312,500 to certain of our directors for debt financing provided and, in connection therewith, we issued stock purchase warrants to such persons exercisable into an aggregate of 850,000 shares of our common stock at an exercise price of $0.30 per share and with a termination date of July 31, 2009. The subordinated promissory notes bore interest at 8% per annum and were paid in full in December 1999. In 2002 and 2003, certain of our directors agreed to provide us with a needed line of credit in exchange for the issuance of stock purchase warrants. In September 2002, we issued an aggregate of 1,500,000 stock purchase warrants to these directors in exchange for a line of credit that expired December 31, 2002, in an amount up to $300,000. The warrants initially covered 1,500,000 shares of common stock, expire on September 10, 2012 and initially were exercisable at $.20 per share. During September 2002, we borrowed $150,000 of the available funds. The promissory notes, which bore interest at 6.75% per annum, were paid in full during December 2002 and January 2003. In March 2003, the same group of directors committed to provide a line of credit up to $300,000 through December 31, 2003. The warrants initially covered an aggregate of 750,000 shares of common stock, were issued in consideration for the commitment to provide the line of credit, expire on June 12, 2013 and initially were exercisable at $.20 per share. The Company had no borrowings against the line of credit in 2003. In addition, our majority shareholder, at the time, chose not to provide the lines of credit and approved the transactions in 2002 and 2003. Pursuant to the terms of the warrants issued in 2002 and 2003, the number of shares into which such warrants are issuable and the exercise price have been adjusted due to the issuance of dividends on the shares of our Series 81¤2% Senior Convertible Preferred Stock in the form of additional shares of Series 81¤2% Senior Convertible Preferred Stock such that the warrants issued in 2002 are currently exercisable into an aggregate of 1,855,000 shares of our common stock at an exercise price of $0.16 per share and the warrants issued in 2003 are currently exercisable into an aggregate of 811,645 shares of our common stock at an exercise price of $0.18 per share.

In October 2004, we completed a $2,386,649 loan transaction with a commercial lender for the purpose of providing funds for the purchase of a new ARAM ARIES recording system. The loan is repayable over a period of 36 months at a fixed per annum interest rate of 6.85%. The loan is collateralized by the new recording system equipment and the recording vehicle and two semi-trailers that transport the equipment between projects.

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In April 2005, we entered into a revolving line of credit loan agreement with a commercial bank under which we may borrow, repay and re-borrow, from time to time until April 2006, up to $500,000. Our obligations under this agreement are secured by a security interest in our accounts receivable. Interest on the outstanding amount under the line of credit loan agreement is payable monthly at a rate of prime plus 1.0%. As of June 30, 2005, we had no borrowings outstanding under the line of credit loan agreement. We are currently negotiating with our lender to increase our line of credit to $3,500,000 for working capital purposes.

In June 2005, we completed a $3,366,253 loan transaction with a commercial lender for the purpose of providing funds for the purchase of a new ARAM ARIES recording system. The loan is repayable over a period of 36 months at a fixed per annum interest rate of 7.25%. The loan is collateralized by the new recording system equipment and the recording vehicles and two semi-trailers that transport the newly purchased equipment between jobs. In addition, in May 2005 the Company entered into an equipment sales contract with an equipment manufacturer to purchase three new vibration vehicles for a cost of approximately $1,026,000. It is anticipated that delivery of these vibration vehicles will be prior to September 30, 2005. We have a verbal commitment from a lender to finance these vibration vehicles for a period of 36 months at a fixed per annum simple interest rate of 7.25%.

The board of directors determined to eliminate unnecessary administrative expenses and dividend payments with respect to our outstanding Series C Preferred Stock by redeeming all of such preferred stock. As a result, the board of directors, at its regular meeting held on June 7, 2005, approved the redemption by the Company of the Series C Preferred Stock. The redemption privilege was contained in the resolution establishing such preferred stock. The redemption price was $5.00 per share plus a premium of 40% per share (i.e., $2.00 per share). In addition, each share was entitled to receive the regular $.20 dividend that had accrued for the first half of the year. Thus, the redemption price was $7.20 per share. On June 30, 2005, the Company redeemed all 5,250 shares of its Series C Preferred Stock for $36,750 plus accrued dividends of $1,050.

Our board of directors has approved a resolution providing for redemption of all of our outstanding 81¤2% Senior Preferred Stock. We expect to send a notice of redemption to each holder of our 81¤2% Senior Convertible Preferred Stock prior to the completion of this offering. Under the terms of the resolution creating such 81¤2% Senior Convertible Preferred Stock, each share is redeemable at $1.75 per share and each holder of our 81¤2% Senior Convertible Preferred Stock has an option to convert each share of our 81¤2% Senior Convertible Preferred Stock into one share of our common stock. Assuming that the market price of our common stock remains substantially above $1.75 per share, we anticipate that all of the holders of our 81¤2% Senior Convertible Preferred Stock will convert their shares of 81¤2% Senior Convertible Preferred Stock into shares of our common stock prior to redemption.

In October 2001, the Company entered into a three-year operating lease for the Company’s headquarters facility located in Plano, Texas. In April 2004, the Company executed an addendum to its operating lease. The addendum extended the term of the lease until March 31, 2009, and increased the square footage of the office and outdoor storage area. Additionally, in August 2005, the Company entered into a 38 month operating lease for additional office and warehouse space in Plano, Texas. This lease becomes effective on September 1, 2005.

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Contractual Obligations

The following table summarizes payments due in specific periods related to our contractual obligations as of June 30, 2005:

(1)          Approximately $858,000 will be financed over a 36 month period at 7.25% interest rate per annum for the purchase of three new vibration vehicles to be delivered in the third quarter of 2005.

(2)   We have entered into a new 38 month operating lease, effective as of September 1, 2005, for an additional 10,000 square feet of office and warehouse space and an additional 10,000 square feet of outdoor storage space. The payments on this lease will be $4,816 per month.

We believe that our capital resources, including our short-term investments, funds available under our line of credit loan agreement and cash flow from operations, are adequate to meet our current operational needs. We believe that we will be able to finance our 2005 capital expenditures through cash flow from operations, borrowings from commercial lenders and the proceeds from this offering. However, our ability to satisfy working capital requirements, meet debt repayment obligations and fund future capital requirements will depend principally upon our future operating performance, which is subject to the risks inherent in our business.

Off-Balance Sheet Arrangements

As of June 30, 2005, we had no off-balance sheet arrangements.

Critical Accounting Policies

The preparation of our financial statements in conformity with GAAP requires us to make certain assumptions and estimates that affect the reported amounts of assets and liabilities at the date of our financial statements and the reported amounts of revenues and expenses during the reporting period. Because of the use of assumptions and estimates inherent in the reporting process, actual results could differ from those estimates.

Revenue Recognition.

Our services are provided under cancelable service contracts. These contracts are either “turnkey” or “term” agreements. The Company recognizes revenues when services are performed under both types of agreements. Services are defined as the commencement of seismic data acquisition. Under turnkey agreements, revenue is recognized on a-per unit of data acquired rate, as services are performed. Under term agreements, revenue is recognized on a-per unit of time worked rate, as services are performed. In the case of a cancelled service contract, we recognize revenue and bill our customer for services performed up to the date of cancellation.

In some instances, we bill customers in advance of the services performed. In those cases, we recognize the liability as deferred revenue.

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Allowance for Doubtful Accounts.

We prepare our allowance for doubtful accounts receivable based on our past experience of historical write-offs, our current customer base and our review of past due accounts. The inherent volatility of the energy industry’s business cycle can cause swift and unpredictable changes in the financial stability of our customers.

Impairment of Long-lived Assets.

We review long-lived assets for impairment when triggering events occur suggesting deterioration in the assets recoverability or fair value. Recognition of an impairment charge is required if future expected net cash flows are insufficient to recover the carrying value of the asset. Our forecast of future cash flows used to perform impairment analysis includes estimates of future revenues and profitability based on our historical results and analysis of future oil and natural gas prices which is fundamental in assessing demand for our services. If we are unable to achieve these cash flows, our estimates would be revised, potentially resulting in an impairment charge in the period of revision.

Depreciable Lives of Property, Plant and Equipment.

Our property, plant and equipment are capitalized at historical cost and depreciated over the useful life of the asset. Our estimation of this useful life is based on circumstances that exist in the seismic industry and information available at the time of the purchase of the asset. The technology of the equipment used to gather data in the seismic industry has historically evolved such that obsolescence does not occur quickly. As circumstances change and new information becomes available, these estimates could change. We amortize these capitalized items using the straight-line method. Capital assets are depreciated over their useful lives ranging from one to seven years, depending on the classification of the asset.

Tax Accounting.

We account for our income taxes in accordance with SFAS No. 109, “Accounting for Income Taxes,” which requires the recognition of amounts of taxes payable or refundable for the current year and an asset and liability approach in recognizing the amount of deferred tax liabilities and assets for the future tax consequences of events that have been recognized in our financial statements or tax returns. We determine deferred taxes by identifying the types and amounts of existing temporary differences, measuring the total deferred tax asset or liability using the applicable tax rate and reducing the deferred tax asset by a valuation allowance if, based on available evidence, it is more likely than not that some portion or all of the deferred tax assets will not be realized. Our methodology for recording income taxes requires judgment regarding assumptions and the use of estimates, including determining our annual effective tax rate and the valuation of deferred tax assets, which can create variance between actual results and estimates. The process involves making forecasts of current and future years’ taxable income and unforeseen events may significantly affect these estimates. Those factors, among others, could have a material impact on our provision or benefit for income taxes.

Stock Based Compensation.

In accordance with the Accounting Principles Board (APB) Opinion No. 25, “Accounting for Stock Issued to Employees,” we do not record compensation for stock options or other stock-based awards that are granted to employees or non-employee directors with an exercise price equal to or above the common stock market price on the grant date.

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Recently Issued Accounting Pronouncements

In December 2004, the Financial Accounting Standards Board (FASB) issued FASB Statement No. 123R, “Share Based Payment” (FAS 123R), which requires that compensation costs relating to share-based payments be recognized in our financial statements. We currently account for those payments under the recognition and measurement principles of APB Opinion No. 25, “Accounting for Stock Issued to Employees,” and related interpretations. The final requirements are effective for periods beginning after June 15, 2005. Although the transition method to be used to adopt the standard has not been selected, the impact of adoption is expected to have minimal impact on our results of operations, financial position and liquidity.

In December 2004, the FASB issued FASB Statement No. 153, “Exchange of Nonmonetary
Assets,—an Amendment of APB Opinion No. 29,” (FAS 153), which is effective for our asset-exchange transactions beginning July 1, 2005. Under APB 29, assets received in certain types of nonmonetary exchanges were permitted to be recorded at the carrying value of the assets that were exchanged (i.e., recorded on a carryover basis). As amended by FAS 153, assets received in some circumstances will have to be recorded instead at their fair values. In the past, we have not engaged in the nonmonetary asset exchanges for significant amounts.

Effect of Inflation

We do not believe that inflation has had a material effect on our business, results of operations or financial condition during the past two years.

Qualitative and Quantitative Disclosure about Market Risk

We have not entered into any hedging agreements or swap agreements. Our principal market risk is the risk related to the concentration of our customers in the oil and natural gas industry. Since all of our customers are involved in the oil and natural gas industry, there may be a positive or a negative effect on our exposure to credit risk, in that our customers may be similarly affected by changes in economic and industry conditions. For the years ended December 31, 2002, 2003 and 2004, our top two customers in each of those years accounted for approximately 38.8% and 11.5%, 15.3% and 12.5% and 33.6% and 14.8%, respectively, of our annual revenues.

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BUSINESS

History

In April 1980, Supreme Industries, Inc., formerly ESI Industries, Inc., (“Supreme”) formed a wholly owned subsidiary that acquired certain equipment, instruments and related supplies of Tidelands Geophysical Co., Inc. (“Tidelands”), a Houston-based corporation that had been organized in 1967 and was engaged in the business of conducting seismic, gravity and magnetic surveys under contracts for oil and natural gas companies. In July 1986, our name was changed from Tideland’s Geophysical Co. Inc. to “TGC Industries, Inc.” On June 30, 1986, the Boards of Directors of Supreme and TGC Industries, Inc. approved a spin-off of substantially all of the shares of TGC Industries, Inc., owned by Supreme which were distributed as a stock dividend to Supreme’s security holders.

We are a leading provider of seismic data acquisition services throughout the continental U.S. We have four seismic crews that supply seismic data to companies engaged in the domestic exploration and development of oil and natural gas on land and in land-to-water transition areas. Our customers rely on seismic data to identify areas where subsurface conditions are favorable for the accumulation of existing hydrocarbons, to optimize the development and production of hydrocarbon reservoirs, to better delineate existing oil and natural gas fields and to augment reservoir management techniques.

We acquire geophysical data using the latest in 3-D survey techniques. We introduce acoustic energy into the ground by using vibration equipment or dynamite detonation, depending on the surface terrain and subsurface requirements. The reflected energy, or echoes, is received through geophones, converted into a digital signal at a multi-channel recording unit and then transmitted to a central recording vehicle. Subsurface requirements dictate the number of channels necessary to perform our services. With our state-of-the-art seismic equipment, including computer technology and multiple channels, we acquire, on a cost effective basis, immense volumes of seismic data that when processed and interpreted produce more precise images of the earth’s subsurface. Our customers then use our seismic data to generate 3-D geologic models that help reduce finding costs and improve recovery rates from existing wells.

Competitive Strengths

Despite the historically cyclical challenges of the seismic industry, we have operated continuously since 1967 due to our prudent operating strategy. We believe that the key strengths of our business include the following:

·       Solid customer base.   Our customers consist of major and independent oil and natural gas exploration and development companies. In 2004, approximately 40.0% of our customers from 2003 utilized our services. We believe that the quality and loyalty of our customer base is attributable to our record for performance, safety and customer service.

·       Strong management team.   Our senior management team has extensive experience in providing both land, and land-to-water transition areas, seismic data acquisition services. Wayne Whitener, our President and Chief Executive Officer, has over 30 years of industry expertise, including 21 years with us. Our other key operations executives and managers each have approximately 30 years of industry experience. Because of our management team’s experience in the industry, we have developed and maintain strong relationships with our customers and their consultants.

·       Investment in state-of-the-art technologies.   We have recently purchased two new ARAM ARIES recording systems (one 3,000 channel system and one 4,000 channel system) and intend to purchase a third new ARAM ARIES recording system with 4,000 channels with the proceeds of this offering. These ARAM ARIES recording systems significantly increase our capacity to meet the needs of our customers and complement our Opseis Eagle systems’ capabilities. The ARAM ARIES recording systems are state-of-the-art and allow us to record seismic data faster, enhancing the effectiveness and productivity of our crews and our revenue opportunities. We also have three new vibration vehicles scheduled for delivery in the third quarter of 2005 and are in discussions to acquire up to eight additional vibration vehicles in the first quarter of 2006.

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·       Skilled and experienced seismic data acquisition crews.   Our crew managers have at least 20 years of industry experience and are trained to operate all of our seismic equipment and recording systems. Our crew managers focus on maintaining crew productivity and the quality of the acquired data. We have experienced minimal turnover of our crew personnel.

·       Cost effective operations, favorable margins and strong financial position.   We believe we are able to offer seismic data acquisition services at competitive prices due to our well-trained and supervised crews, state-of-the-art, well-maintained equipment and low corporate overhead. Because we do not process seismic data for our customers, we do not incur the personnel and other costs associated with that service. In addition, we believe the nature of our seismic recording equipment requires us to have fewer operating personnel. For the six months ended June 30, 2005, we had a favorable mix of contracts which resulted in an EBITDA margin of 36.5%, which we believe is among the highest in the industry. Adjusted for the proceeds of this offering, as of June 30, 2005, our funded debt to total capital, would have been       %. Our financial strength is important to our customers who undertake major seismic programs and make sizable pre-payments to us for our services.

The Industry

Technological advances in seismic equipment and computing allow the seismic industry to economically acquire and process immense volumes of seismic data which produce more precise images of the earth’s subsurface. The latest accepted method of seismic data acquisition, processing and the subsequent interpretation of the processed data is the 3-D seismic method. Geophysicists use computer workstations to interpret 3-D data volumes, identify subsurface anomalies and generate a geologic model of subsurface features.

3-D seismic data are used in the exploration and development for new reserves and enable oil and natural gas companies to better delineate existing fields and to augment their reservoir management techniques. Benefits of incorporating high resolution 3-D seismic surveys into exploration and development programs include reducing drilling risk, decreasing oil and natural gas finding costs and increasing the efficiencies of reservoir location, delineation and management. In order to meet the requirements necessary to fully realize the benefits of 3-D seismic data, there is an increasing demand for improved data quality with greater subsurface resolution.

Currently, the seismic data acquisition industry is made up of a number of companies divided into two groups. The first group is made up of four publicly traded companies with long operating histories who field numerous crews and work in a number of different regions and terrain, this group includes us, Dawson Geophysical Company, Quantum Geophysical Services, Inc., a subsidiary of Geo Kinetics, Inc. and Veritas DGC, Inc. These companies field approximately 50% of the approximately 48 seismic crews currently operating in the continental U.S. The second group is made up of smaller companies who generally run one seismic crew and often specialize in specific regions or type of operation.

We provide our seismic data acquisition services primarily to domestic onshore oil and natural gas exploration and development companies for use in the onshore drilling and production of oil and natural gas in the continental U.S. The main factors influencing demand for seismic data acquisition services in our industry is the level of drilling activity by oil and natural gas companies and the size of such companies’ exploration and development budget, which, in turn, depends largely on current and anticipated future crude oil and natural gas prices and depletion rates. Current market indicators suggest an increasing demand for oil and natural gas coupled with a flat or declining production curve, which we believe should result in the continuation of historically high oil and natural gas commodity prices. From 2003 through 2025, consumption of oil and natural gas in the U.S. are each projected to grow at an annual rate of 1.5%. However, U.S. domestic production of oil is projected to decrease (0.8)% annually and natural gas is projected to grow at an annual rate of 0.6% over the same period. Additionally, the EIA recently estimated

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that U.S. domestic consumption of oil and natural gas will outpace domestic production by 13.4% and 4.9% by 2010, respectively. By 2025, EIA forecasts that these supply and demand gaps for oil and natural gas may expand to 19.1% and 8.7%, respectively. The majority of the wells drilled by our customers have been wells drilled in search of natural gas reserves.

Increased decline rates in natural gas basins in the U.S. have also led to an increase in the price of oil and natural gas. Over the past 10 years, the number of U.S. natural gas wells drilled has increased significantly; however, a corresponding increase in production has not been realized. We believe that a significant reason for the limited supply response, even as drilling activities have increased, is the accelerating decline rates of production from new natural gas wells drilled. A study published by the National Petroleum Council in September 2003 concluded, from analysis of production data over the preceding 10 years, that as a result of domestic natural gas decline rates of 25% to 30% per year, 80% of natural gas production in 10 years will be from wells that have not yet been developed. We believe that this tends to support a sustained higher natural gas price environment, which should create incentives for exploration and development companies to increase seismic activities in the U.S. As a result of improvements in extraction technologies along with general increases in prices, oil and natural gas companies increasingly are exploring for and developing “unconventional” resources, including hydrocarbons from tight sands and shales in new areas.

We anticipate that oil and natural gas exploration and development companies will continue to respond to sustained increases in demand and corresponding higher future oil and natural gas commodity prices by expanding their exploration and drilling activities through increased capital spending. According to RigData, weekly average onshore well permits issued in 2004 and 2003 were 1,122 and 961, respectively, an increase of 16.8%. Based upon Baker-Hughes rig count data, the 2004 and 2003 domestic onshore rig count averaged 1,095 and 924 rigs, respectively, an increase of 18.5%. Based on the strong oil and natural gas prices and increasing exploration and development budgets of oil and natural gas companies, we anticipate continued growth in the industry.

In addition, beginning January 1, 2006, new energy legislation will permit the tax deduction of seismic data acquisition services over a 24 month period, instead of the longer write-off period previously in effect. We believe that this accelerated tax write-off may encourage additional exploration and development activity.

We anticipate that oil and natural gas exploration and development companies will continue to respond to sustained increases in demand by expanding their exploration and drilling activities and increasing capital spending. We believe that a continued increase in U.S. seismic work will be required for the oil and natural gas industry to help meet the expected increased demand for oil and natural gas in the U.S.

Growth Stategies

We believe that there are significant opportunities for us to increase our revenues and market position in the continental U.S. onshore seismic market. The major factors influencing our future growth are:

Optimizing equipment and crew utilization.   We will continue to focus on full utilization and productivity improvements of our crews. We believe that the acquisition of a third ARAM ARIES recording system with the proceeds of this offering will further increase our productivity given its rapid seismic data acquisition characteristics. We will train one of our Opseis Eagle crews to use the new ARAM ARIES recording system and redeploy that Opseis Eagle system with a new crew as customer demand dictates.

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Maintaining our state-of-the-art technology position.   Our recent acquisition of the two new ARAM ARIES recording systems and planned acquisition of one additional new ARAM ARIES recording system and up to eight new vibration vehicles with the proceeds of this offering, combined with our current Opseis Eagle systems, position us as a leader in our industry in terms of technology. Our ARAM ARIES recording systems incorporate real-time Windows based data recording, which gives our crews the capacity to complete more projects and generate more revenues. Our Opseis Eagle systems will continue to be utilized to support the needs of our customers particularly in markets and geographies better suited to their capabilities, such as in land-to-water transition and shallow gas areas. The continued operation of both of these systems will allow us to take advantage of the strengths of each system.

Maintaining our efficient management structure.   Our crew level managers have significant local knowledge of numerous operating areas and have developed solid relationships with our customers at the field level. Senior management at the corporate level is responsible for sales, logistical, administrative and strategic decisions. While we may add crews and selectively hire additional corporate personnel, we will vigorously maintain an efficient and cost effective management structure. We believe that this structure will continue to allow us to be highly responsive to our customers’ needs.

Managing the mix and terms of our contracts.   We plan on managing our crews and equipment as a portfolio, balancing the mix of turnkey and term contracts and the type of equipment we use whenever possible. We will also continue to negotiate for some level of weather downtime protection.

Maintaining a conservative balance sheet and disciplined capital spending program.   We believe that our post-offering balance sheet will allow us the financial flexibility to pursue opportunities to grow our business. We will continue to evaluate opportunities to purchase new equipment and expand the number of crews as customer demand and market conditions permit.

Equipment and Crews

In 2002, we downsized from two crews to one crew because of a reduced demand for our services. As a result, we began exploring ways of increasing bidding opportunities in existing markets. In February 2002, we entered into an agreement to trade in our shot hole drilling equipment for five buggy-mounted vibroseis units. The purchase of these units have opened up a new market opportunity for us, thereby increasing our bidding opportunities. We have been successful in the vibroseis market with a significant portion of our 2003 and 2004 revenues being generated from vibroseis contracts. We announced in January 2004 that, given that oil and natural gas exploration and development companies had increased the level of activity in their domestic oil and natural gas exploration programs, we had acquired three new vibroseis units and deployed a second seismic crew. In June 2004, in response to the continued increased level of activity in the domestic oil and natural gas market, we deployed a third seismic crew, and in July 2005, we deployed a fourth seismic crew.

Two of our crews utilize the Opseis Eagle data gathering system. This system employs radio-frequency (“RF”) telemetry technology providing seismic data-gathering services to land-to-water transition areas, rivers, lakes, inaccessible terrain, deserts and man-made barriers such as highways and cities. RF telemetry transmits data in “real time” via remote units set up on a shot line. These lightweight units, called Seismic Acquisition Remove (“SAR”) units, can be set up and repositioned quickly and easily without cumbersome cables. Multiple SAR units represent the first surface mount technology and the ability to gather data from any terrain through any obstacle. Our crews have great flexibility in energy sources and placement of SAR units in the field.

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In each of October 2004 and June 2005 we purchased new state-of-the-art ARAM ARIES recording systems. These systems employ cable telemetry technology enhanced by multiple baseline and redundant cable connections that provide seismic data acquisition services with increased reliability. This allows our crews to record data faster, thereby increasing their productivity and freeing up equipment for use by our other crews. Subsurface requirements dictate the number of channels necessary to perform our services and the increased number of recording channels we obtained with these new recording systems give us greater operational flexibility. Each new ARAM ARIES recording system comes with a 24 month warranty and system upgrades.

We currently own equipment for four land-based seismic data acquisition crews and 18 Hemi-50, 50,000 pound vibration vehicles equipped with Pelton electronics. Each crew consists of approximately 35 to 45 technicians with associated vehicles, geophones, a seismic recording system, energy sources, cables and a variety of other equipment. Each crew has one central recording vehicle which captures seismic data. This data is recorded on a CD ROM or data tape, which is delivered to a data processing center selected by the customer.

Additionally, we plan to purchase another ARAM ARIES recording system and peripheral seismic equipment, including up to eight additional vibration vehicles, with the proceeds from this offering. We will train one of our Opseis Eagle crews to use the new ARAM ARIES recording system and redeploy that Opseis Eagle system with a new crew as customer demand dictates.

Capital Expenditures

We believe that it is essential to take advantage of advances in seismic technology and to commit capital to purchase and update our equipment cost effectively. Purchasing and updating seismic equipment and technology involves a continuing commitment to capital spending. For fiscal year 2004 capital expenditures were approximately $5,795,000 and are forecast to be approximately $12,497,000 for 2005 if this offering is successful. Capital expenditures for 2005 through June 30, 2005 were approximately $6,075,000. With the proceeds from this offering, we plan to purchase another ARAM ARIES recording system for approximately $4,000,000 and peripheral seismic equipment, including up to eight vibration vehicles, for approximately $3,000,000.

Customers and Consultants

Our customers are major and independent oil and natural gas exploration and development companies. The services we provide to our customers vary according to the size and needs of each customer. Our services are marketed by supervisory and executive personnel who contact customers to determine their needs and respond to customer inquiries regarding the availability of crews. Contacts are based principally upon professional relationships developed over a number of years. There are a number of consultants in the oil and natural gas industry who process and interpret seismic data for oil and natural gas companies. These consultants can have an influence in determining which company their customers use to acquire seismic data.

For the year ended December 31, 2004, two customers accounted for approximately 33.6% and 14.8% of our revenues, respectively. Because of our relatively large customer base, our largest customers have varied from year to year. In 2004, approximately 40.0% of our customers from 2003 utilized our services again.

In order to avoid potential conflicts of interest with our customers, we do not participate in oil and natural gas ventures. The results of a seismic survey conducted for a customer belong to that customer. All of our customer’s information is maintained in strictest confidence.

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Contracts

Our contracts are obtained either through competitive bidding or as a result of customer negotiations. Our services are conducted under general service agreements for seismic data acquisition services which define certain obligations for us and for our customers. A supplemental agreement setting forth the terms of a specific project, which may be cancelled by either party upon 60 days of advanced written notice, is entered into for every project. We currently operate under supplemental agreements that are either “turnkey” agreements providing for a fixed fee to be paid to us for each unit of data acquired, or “term” agreements providing for a fixed hourly, daily or monthly fee during the term of the project or projects. Turnkey agreements generally provide us more profit potential, but involve more risks because of the potential of crew downtime or operational delays. Under the term agreements, we forego an increased profit potential in exchange for a more consistent revenue stream with improved protection from crew downtime or operational delays. We attempt to negotiate on a project-by-project basis some level of weather downtime protection within our agreements. We strive to manage our crews and equipment as a portfolio, balancing the mix of turnkey and term contracts and the type of equipment we use whenever possible.

The energy source for each contract is determined by the surface terrain and the sub-surface requirements. Although our contracts involving dynamite make up a small percentage of the total number of contracts, they have historically ranged between 10% to 50% of our annual revenues. The range of revenues is influenced by the number of dynamite projects we conduct in a given year. We incur higher costs on our dynamite projects that we pass on to our customers, and as a result, we recognize both higher revenues and higher costs of services, thereby reducing our EBITDA margin.

Sub-Contractors and Equipment Rental

We engage a number of sub-contractors to perform specialized services related to the use of dynamite that is required on some projects. These sub-contractors provide services that include supplying dynamite, drilling holes in connection with the use of dynamite and specialized surveying crews that can clear heavy brush and trees in order to complete the survey. There are a number of contractors that provide these types of services, as a result, we are not dependent on any single contractor or group of contractors for the successful completion of our projects.

In addition, we rent certain specialized equipment on a project by project basis, such as boats and specialized geophones.

Competition

The acquisition of seismic data for the oil and natural gas industry is a highly competitive business. There are approximately 48 seismic crews in the continental United States. Contracts for such services generally are awarded on the basis of price quotations, crew experience and the availability of crews to perform in a timely manner, although factors other than price, such as crew safety performance history, technological and operational expertise, are often determinative. Our competitors include companies with financial resources that are significantly greater than our own as well as companies of comparable and smaller size. Our primary competitors are Dawson Geophysical Company and Quantum Geophysical Services, Inc., a subsidiary of Geo Kinetics, Inc. and to a lesser extent, Veritas DGC, Inc. In addition to the previously named companies, we also compete for projects from time to time with smaller seismic companies who operate in local markets with only one or two crews. We believe that our long term industry expertise and the customer relationships developed over our history combined with our financial stability give us an advantage over most of our competitors in the industry.

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Employees

As of August 30, 2005, we employed a total of 254 non-union employees, of which nine consisted of management, sales and administrative personnel with the remainder being crew personnel. We believe our relationship with our employees to be satisfactory.

Data Bank

We own a data bank which contains gravity data, and to a lesser extent magnetic data, from many of the major oil and natural gas producing areas located within the U.S. We do not have a seismic data bank. Our data bank information has been amassed through participatory surveys as well as speculative surveys historically funded by us alone. All data and interpretations may be licensed to customers at a fraction of the cost of newly acquired data. However, the licensing of this data is not a significant portion of our revenues.

Operating Risks and Insurance

Our business is subject to the hazards inherent in conducting seismic data acquisition activities in hostile environments with dangerous machinery, and in some instances explosives. These conditions can cause personal injury or loss of life, damage to or destruction of property, equipment, the environment and marine life, and suspension of operations.

In addition, we could be subject to personal injury or real property damage claims in the normal operation of our business. Such claims may not be covered under the indemnification provisions in our general service agreements to the extent that the damage is due to our negligence, gross negligence or intentional misconduct.

We do not carry insurance against certain risks that we could experience, including business interruption resulting from equipment maintenance or weather delays. We obtain insurance against certain property and personal casualty risks and other risks when such insurance is available and when our management considers it advisable to do so. Currently we maintain employers liability with limits of $1,000,000 per accident and $2,000,000 in aggregate, commercial general liability of $1,000,000 per accident and $2,000,000 in aggregate, pollution liability of $1,000,000 per accident and $2,000,000 in aggregate, automobile liability with a $1,000,000 combined single limit and a $10,000,000 umbrella policy. Our general service agreements require us to have specific amounts of insurance. There can be no assurance, however, that any insurance obtained by us will be adequate to cover any losses or liabilities, or that this insurance will continue to be available or available on terms which are acceptable to us. Liabilities for which we are not insured, or which exceed the policy limits of our applicable insurance, could have a materially adverse effect on us.

Litigation

On December 28, 2004, one of our employees was killed in a work-related accident. On July 11, 2005, the deceased employee’s widow filed suit against us in a state court in Harris County, Texas. Our insurance company is currently providing legal counsel to represent us in this case, and we do not believe that the case’s disposition will have a material affect on our financial results.

We are a defendant in various other legal actions that arise out of the normal course of business. In our opinion, none of these actions will result in any significant loss to us.

Property

Our headquarters are in leased facilities located in Plano, Texas, from which we conduct all of our current operations. These facilities include approximately 10,500 square feet of office and warehouse space

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and an outdoor storage area of approximately 20,000 square feet. This facility is used to house our corporate offices and serves as the headquarters for our seismic data acquisition services business. We have recently added an additional 10,000 square feet of office and warehouse space and an additional 10,000 square feet of outdoor storage to accomodate our recent growth. This facility will be used to store equipment and it will provide additional office space for our administrative personnel. The condition of our facilities is good, and we believe that these properties are suitable and adequate for our foreseeable needs. However, we have engaged a leasing agent to investigate alternatives to our current facilities that would provide additional space that may be necessary as our operations continue to grow.

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MANAGEMENT

The following table shows information as of August 26, 2005 with respect to each person who is an executive officer or director.

(1)   Member of the Executive Committee

(2)   Member of the Audit Committee

(3)   Member of the Stock Option Committee

All of the directors hold office until the next annual meeting of shareholders or until their successors are duly elected and qualified, and all executive officers hold office at the discretion of the board of directors.

Wayne A. Whitener has served as the Company’s Chief Executive Officer since January 1999 and as a director of the Company since 1986. Prior to his current position, Mr. Whitener served as our Chief Operating Officer from July 1986 to December 1998, President of the geophysical division from 1984 to 1986 and our Vice President from 1983 to 1984.

Daniel G. Winn, has served as the Vice President of the Company since June 2004. He also served as our Operations Manager from August 1997 to June 2004 and our Operations Supervisor from January 1990 to August 1997. Prior to joining the Company, Mr. Winn served as the Operations Supervisor for Halliburton Geophysical from January 1988 to January 1990.

Kenneth W. Uselton has served as our Chief Financial Officer since 1995, Treasurer since August 1996 and Secretary since March 2004. Prior to joining the Company, Mr. Uselton served as Vice President and Chief Financial Officer of Texstar, Inc., a plastics manufacturer from May 1990 to August 1995.

William J. Barrett has served as a director of the Company since 1986 and previously served as the Company’s Secretary from 1986 to November 1997. Mr. Barrett is President of Barrett-Gardner Associates, Inc., an investment banking firm, a position he has held since November 2002. Mr. Barrett also serves as a director and Executive Vice President of Supreme Industries, Inc., a manufacturer of specialized truck bodies and shuttle buses, and as Chairman of the Board of Rumson-Fair Haven Bank and Trust, a New Jersey independent, commercial bank and trust company. From 1978 to 2002, Mr. Barrett served as Senior Vice President of Janney Montgomery Scott LLC, an investment banking firm.

Edward L. Flynn has served as a director of the Company since January 1999. Mr. Flynn has owned Flynn Meyer Company, a restaurant management company since 1976. Mr. Flynn also serves as a director and Treasurer of Citri-Lite Co., a soft drink company.

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Herbert M. Gardner has served as a director of the Company since 1986. Mr. Gardner has also served as the Executive Vice President of Barrett-Gardner Associates, Inc., an investment banking firm, since November 2002 and as Chairman of the Board and President of Supreme Industries, Inc., a manufacturer of specialized truck bodies and shuttle buses, since 1979 and 1992, respectively. Mr. Gardner currently serves as a member of the board of directors of: Nu Horizons Electronics Corp., an electronic component distributor; Co-Active Marketing Group, Inc., a marketing and sales promotion company; and Rumson-Fair Haven Bank and Trust Company, a New Jersey independent, commercial bank and trust company. Mr. Gardner previously served as the Senior Vice President of Janney Montgomery Scott LLC, an investment banking firm from 1978 to 2002.

William C. Hurtt, Jr. has served as a director of the Company since June 2003. Mr. Hurtt is currently retired, but has served as the manager of Blue Lake Properties, LLC, Tuscaloosa, Alabama, since November 1998. Mr. Hurtt was formerly a Director of River Gas Corporation, from October 1998 to September 2000.

Allen T. McInnes has served as a director of the Company since 1993 and served as the Chairman of the Company’s board of directors from July 1993 to March 2004. Mr. McInnes also served as the Company’s Secretary from November 1997 to March 2004 and Chief Executive Officer from August 1993 to March 1996. Mr. McInnes’ experience outside the company includes serving as the Executive Vice-President and as a director of Tenneco, Inc. from 1960 to 1992; President and Chief Executive Officer of Tetra Technologies, Inc. from April 1996 to September 2001; Director of Tetra Technologies, from 1996 to the present; and Director of Alamosa PCS, a wireless communication company which is an affiliate of Sprint, from February 2003 to the present. Mr. McInnes also currently serves as the Dean of the Rawls College of Business, Texas Tech University and has held that position since August 2001.

Director Committees

We have three committees: the Executive Committee consisting of Messrs. McInnes, Barrett and Gardner; the Audit Committee consisting of Messrs. McInnes, Gardner and Hurtt; and the Stock Option Committee Consisting of Messrs. McInnes, Barrett and Gardner. Due to the small size of the company, we received permission from the American Stock Exchange not to have a nominating or compensation committee.

The Executive Committee is charged by our bylaws with the responsibility of exercising the authority of the board of directors as is specifically delegated to it by the board of directors, subject to certain limitations contained in the bylaws.

The Audit Committee’s purpose and function are to appoint or terminate the independent auditors; evaluate and determine compensation of the independent auditors; review the scope of the audit proposed by the independent auditors; review year-end financial statements prior to the issuance; consult with the independent auditors on matters relating to internal financial controls and procedures; and make appropriate reports and recommendations to the board of directors. The board of directors has determined that Mr. McInnes qualifies as an “audit committee financial expert” under applicable SEC and American Stock Exchange regulations.

The Stock Option Committee is responsible for awarding stock options to employees or individuals who provide substantial advice or other assistance to the Company.

The board of directors has determined that Messrs. McInnes, Gardner and Hurtt are independent directors since they do not have material relationships with the Company that would interfere with the exercise of their independent judgment.

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EXECUTIVE COMPENSATION

The table below sets forth, on an accrual basis, the total compensation paid by us for the periods indicated to our President and Chief Executive Officer. No other executives had salaries and bonuses that exceeded $100,000.

Summary Compensation Table