Statements we make in the following discussion that express a belief, expectation or intention, as well as those that are not historical fact, are forward-looking statements that are subject to risks, uncertainties and assumptions. Our actual results, performance or achievements, or industry results, could differ materially from those we express in the following discussion as a result of a variety of factors, including general economic and business conditions and industry trends, the continued strength or weakness of the contract land drilling industry in the geographic areas in which we operate, decisions about onshore exploration and development projects to be made by oil and gas companies, the highly competitive nature of our business, the availability, terms and deployment of capital, the availability of qualified personnel, and changes in, or our failure or inability to comply with, government regulations, including those relating to the environment. We have discussed many of these factors in more detail elsewhere in this report and in our annual report on Form 10-K for the fiscal year ended March 31, 2007. These factors are not necessarily all the important factors that could affect us. Unpredictable or unknown factors we have not discussed in this report or in our annual report on Form 10-K could also have material adverse effects on actual results of matters that are the subject of our forward-looking statements. All forward-looking statements speak only as the date on which they are made and we undertake no duty to update or revise any forward-looking statements. We advise our shareholders that they should (1) be aware that important factors not referred to above could affect the accuracy of our forward-looking statements and (2) use caution and common sense when considering our forward-looking statements.

Company Overview

Pioneer Drilling Company provides contract land drilling services to independent and major oil and gas exploration and production companies. In addition to our drilling rigs, we provide the drilling crews and most of the ancillary equipment needed to operate our drilling rigs. We have focused our operations in selected oil and natural gas production regions in the United States and Colombia. Our company was incorporated in 1979 as the successor to a business that had been operating since 1968. We conduct our operations through our principal operating subsidiary, Pioneer Drilling Services, Ltd. We are an oil and gas services company. We do not invest in oil and natural gas properties. The drilling activity of our customers is highly dependent on the current and forecasted future price of oil and natural gas. Since November 2006, we have been experiencing a decline in the demand for drilling rigs and have experienced a decline in revenue rates on contract renewals due to an excess supply of drilling rigs within the industry, which is due to the substantial addition of new and refurbished drilling rigs during the past year. Any continued weakness in the demand for additional drilling rigs will likely result in lower revenue rates for our rigs as existing contracts expire and more drilling rigs are added to the market.

Our business strategy is to own and operate a high-quality fleet of land drilling rigs in active drilling markets, to position ourselves to maximize rig utilization and dayrates and to enhance shareholder value. We intend to continue making additions to our drilling fleet, either through acquisitions of businesses or selected assets or through the construction of new or refurbished drilling rigs, as attractive opportunities arise. We may explore acquiring businesses in other sectors within the oilfield services industry. In addition, we are evaluating opportunities for expansion into international markets beginning with Colombia. We commenced operations in Colombia with two contracts for which we exported two drilling rigs to Colombia that began operations in September 2007 and October 2007. Our immediate international business strategy is to continue our expansion in Colombia to include at least three drilling rigs by fiscal year end.

Since September 1999, we have significantly expanded our fleet of drilling rigs through acquisitions and the construction of new and refurbished rigs. As of October 31, 2007, our rig fleet consisted of 68 operating drilling rigs, of which 27 are premium electric rigs that drill in depth ranges between 6,000 and 18,000 feet. Seventeen of our rigs are operating in our South Texas division, 20 are operating in our East Texas division, ten are operating in our North Texas division, six are operating in our Western Oklahoma division, 13 are operating in our Rocky Mountain division consisting of locations in Utah and North Dakota and two are operating internationally in Colombia. Not included in our 68 operating rig count is a 1500 horsepower rig that we were upgrading at September 30, 2007 that we plan to deploy for further expansion into international markets.

We earn our revenues by drilling oil and gas wells for our customers, as our rigs can be used by our customers to drill for either oil or natural gas. We obtain our contracts for drilling oil and gas wells either through competitive bidding or through direct negotiations with customers. Our drilling contracts generally provide for compensation on either a daywork, turnkey or footage basis. Contract terms generally depend on the complexity and risk of operations, the on-site drilling conditions, the type of equipment used and the anticipated duration of the work to be performed. Historically, our contracts provide for the drilling of a single well and typically permit the customer to terminate on short notice. As demand for drilling rigs improved during calendar year 2005 and 2006, we entered into more longer-term drilling contracts. As of October 31, 2007, we had 19 contracts with terms of six months to two years in duration, of which seven will expire by May 1, 2008, eight have a remaining term of seven to 12 months, three have a remaining term of 13 to 18 months and one has a remaining term in excess of 18 months.

For the three and six months ended September 30, 2007 and 2006 our rig utilization, revenue days and number of operating drilling rigs were as follows:

                                 Three Months Ended         Six Months Ended
                                    September 30,             September 30,
                                 2007           2006        2007         2006
           Utilization Rates         90 %           97 %        90 %        96 %

The primary reason for the increase in the number of revenue days in 2007 over 2006 is the increase in size of our rig fleet. Due to the current excess supply of drilling rigs available for work, we currently expect a 5% to 10% decrease in utilization rates for the remainder of fiscal year 2008 as compared to fiscal year 2007.

In addition to high commodity prices, we attribute our relatively high utilization rates to a strong sales effort, quality equipment, good field and operations personnel, a disciplined safety approach, and our generally successful performance of turnkey operations during periods of reduced demand for drilling rigs.

We devote substantial resources to maintaining and upgrading our rig fleet. In the short term, these actions result in fewer revenue days and slightly lower utilization; however, in the long term, we believe the upgrades will help the marketability of our rigs and improve their operating performance. Upgrades for the fiscal year ending March 31, 2008 will primarily focus on: replacing older engines with more modern, efficient engines; upgrading to higher horsepower mud pumps; upgrading to modern mud cleaning systems on some of our drilling rigs; and adding iron roughnecks to approximately 30 of our drilling rigs.

Market Conditions in Our Industry

The U.S. contract land drilling services industry is highly cyclical. Volatility in oil and gas prices can produce wide swings in the levels of overall drilling activity in the markets we serve and affect the demand for our drilling services and the dayrates we can charge for our rigs. The availability of financing sources, past trends in oil and gas prices and the outlook for future oil and gas prices strongly influence the number of wells oil and gas exploration and production companies decide to drill.

In addition, the availability of drilling rigs capable of working affects our revenue rates and utilization rates. For much of calendar year 2005 and 2006, our industry experienced a shortage of drilling rigs leading to revenue rates and utilization rates that were at historically high levels. However, our industry is currently experiencing an excess drilling rig supply due to new construction and refurbishments. This condition may correct itself over time if older drilling rigs are retired and if the outlook for natural gas pricing improves and results in an increase in drilling activity.

On October 19, 2007, the spot price for West Texas Intermediate crude oil was $88.60, the spot price for Henry Hub natural gas was $6.91 and the Baker Hughes land rig count was 1,687, a 3.6% increase from 1,629 on October 20, 2006. Since January 1, 2007, the Baker Hughes land rig count has been between 1,588 and 1,730.

The average weekly spot prices of West Texas Intermediate crude oil and Henry Hub natural gas and the average weekly domestic land rig count, per the Baker Hughes land rig count, for the quarter ended September 30, 2007 and each of the previous five years ended September 30, 2007 were:

                                  Three Months
                                     Ended
                                 September 30,               Years Ended September 30,
                                      2007         2007      2006      2005      2004      2003
 Oil (West Texas Intermediate)   $        75.73   $ 64.87   $ 67.46   $ 53.72   $ 37.10   $ 30.45

 Natural Gas (Henry Hub)         $         6.12   $  6.85   $  8.24   $  7.36   $  5.55   $  5.22

 U.S. Land Rig Count                      1,693     1,646     1,479     1,203     1,038       839

Critical Accounting Policies and Estimates

Revenue and cost recognition - We earn our revenues by drilling oil and gas wells for our customers under daywork, turnkey or footage contracts, which usually provide for the drilling of a single well. We recognize revenues on daywork contracts for the days completed based on the dayrate each contract specifies. We recognize revenues from our turnkey and footage contracts on the percentage-of-completion method based on our estimate of the number of days to complete each contract. Individual contracts are usually completed in less than 60 days. The risks to us under a turnkey contract and, to a lesser extent, under footage contracts, are substantially greater than on a contract drilled on a daywork basis. Under a turnkey contract, we assume most of the risks associated with drilling operations that are generally assumed by the operator in a daywork contract, including the risks of blowout, loss of hole, stuck drill pipe, machinery breakdowns and abnormal drilling conditions, as well as risks associated with subcontractors' services, supplies, cost escalations and personnel operations.

Our management has determined that it is appropriate to use the percentage-of-completion method, as defined in the American Institute of Certified Public Accountants' Statement of Position 81-1, to recognize revenue on our turnkey and footage contracts. Although our turnkey and footage contracts do not have express terms that provide us with rights to receive payment for the work that we perform prior to drilling wells to the agreed-on depth, we use this method because, as provided in applicable accounting literature, we believe we achieve a continuous sale for our work-in-progress and believe, under applicable state law, we ultimately could recover the fair value of our work-in-progress even in the event we were unable to drill to the agreed-on depth in breach of the applicable contract. However, in the event we were unable to drill to the agreed-on depth in breach of the contract, ultimate recovery of that value would be subject to negotiations with the customer and the possibility of litigation.

If a customer defaults on its payment obligation to us under a turnkey or footage contract, we would need to rely on applicable law to enforce our lien rights, because our turnkey and footage contracts do not expressly grant to us a security interest in the work we have completed under the contract and we have no ownership rights in the work-in-progress or completed drilling work, except any rights arising under the applicable lien statute on foreclosure. If we were unable to drill to the agreed-on depth in breach of the contract, we also would need to rely on equitable remedies outside of the contract, including quantum meruit, available in applicable courts to recover the fair value of our work-in-progress under a turnkey or footage contract.

We accrue estimated contract costs on turnkey and footage contracts for each day of work completed based on our estimate of the total costs to complete the contract divided by our estimate of the number of days to complete the contract. Contract costs include labor, materials, supplies, repairs and maintenance, operating overhead allocations and allocations of depreciation and amortization expense. In addition, the occurrence of uninsured or under-insured losses or operating cost overruns on our turnkey and footage contracts could have a material adverse effect on our financial position and results of operations. Therefore, our actual results for a contract could differ significantly if our cost estimates for that contract are later revised from our original cost estimates for a contract in progress at the end of a reporting period which was not completed prior to the release of our financial statements.

With most drilling contracts, we receive payments contractually designated for the mobilization of rigs and other equipment. Payments received, and costs incurred for the mobilization services are deferred and recognized on a straight line basis over the contract term of certain drilling contracts. Costs incurred to relocate rigs and other drilling equipment to areas in which a contract has not been secured are expensed as incurred. Reimbursements that we receive for out-of-pocket expenses are recorded as revenue and operating costs.

Asset impairments - We assess the impairment of property and equipment whenever events or circumstances indicate that the carrying value may not be recoverable. Factors that we consider important and which could trigger an impairment review would be our customers' financial condition and any significant negative industry or economic trends. More specifically, among other things, we consider our contract revenue rates, our rig utilization rates, cash flows from our drilling rigs, current oil and gas prices and trends in the price of used drilling equipment observed by our management. If a review of our drilling rigs indicates that our carrying value exceeds the estimated undiscounted future net cash flows, we are required under applicable accounting standards to write down the drilling equipment to its fair market value. A one percent write-down in the cost of our drilling equipment, at September 30, 2007, would have resulted in a corresponding decrease in our net earnings of approximately $3,470,000 for the six months ended September 30, 2007.

Deferred taxes - We provide deferred taxes for the basis differences in our property and equipment between financial reporting and tax reporting purposes and other costs such as compensation, employee benefit and other accrued liabilities which are deducted in different periods for financial reporting and tax reporting purposes. For property and equipment, basis differences arise from differences in depreciation periods and methods and the value of assets acquired in a business acquisition where we acquire an entity rather than just its assets. For financial reporting purposes, we depreciate the various components of our drilling rigs over five to 15 years and refurbishments over three to five years, while federal income tax rules require that we depreciate drilling rigs and refurbishments over five years. Therefore, in the first five years of our ownership of a drilling rig, our tax depreciation exceeds our financial reporting depreciation, resulting in our providing deferred taxes on this depreciation difference. After five years, financial reporting depreciation exceeds tax depreciation, and the deferred tax liability begins to reverse.

Accounting estimates- We consider the recognition of revenues and costs on turnkey and footage contracts to be critical accounting estimates. On these types of contracts, we are required to estimate the number of days needed for us to complete the contract and our total cost to complete the contract. Our actual costs could substantially exceed our estimated costs if we encounter problems such as lost circulation, stuck drill pipe or an underground blowout on contracts still in progress subsequent to the release of the financial statements.

We receive payment under turnkey and footage contracts when we deliver to our customer a well completed to the depth specified in the contract, unless the customer authorizes us to drill to a more shallow depth. Since 1995, we have completed all our turnkey or footage contracts. Although our initial cost estimates for turnkey and footage contracts do not include cost estimates for risks such as stuck drill pipe or loss of circulation, we believe that our experienced management team, our knowledge of geologic formations in our areas of operations, the condition of our drilling equipment and our experienced crews have previously enabled us to make reasonable cost estimates and complete contracts according to our drilling plan. While we do bear the risk of loss for cost overruns and other events that are not specifically provided for in our initial cost estimates, our pricing of turnkey and footage contracts takes such risks into consideration. When we encounter, during the course of our drilling operations, conditions unforeseen in the preparation of our original cost estimate, we increase our cost estimate to complete the contract. If we anticipate a loss on a contract in progress at the end of a reporting period due to a change in our cost estimate, we accrue the entire amount of the estimated loss, including all costs that are included in our revised estimated cost to complete that contract, in our consolidated statement of operations for that reporting period. During the six months ended September 30, 2007, we experienced losses on five of the 43 turnkey and footage contracts completed, with losses exceeding $25,000 each on three contracts. During the six months ended September 30, 2006, we experienced losses on two of 26 footage contracts completed, and those losses were each less than $25,000. We are more likely to encounter losses on turnkey and footage contracts in periods in which revenue rates are lower for all types of contracts. During periods of reduced demand for drilling rigs, our overall profitability on turnkey and footage contracts has historically exceeded our profitability on daywork contracts.

Revenues and costs during a reporting period could be affected for contracts in progress at the end of a reporting period which have not been completed before our financial statements for that period are released. We had four footage contracts in progress at September 30, 2007, which were completed prior to the release of the financial statements included in this report. Our contract drilling in progress totaled approximately $13,808,000 at September 30, 2007. Of that amount accrued, footage contract revenues were approximately $1,040,000. The remaining balance of approximately $12,768,000

We estimate an allowance for doubtful accounts based on the creditworthiness of our customers as well as general economic conditions. We evaluate the creditworthiness of our customers based on commercial credit reports, trade references, bank references, financial information, production information and any past experience we have with the customer. Consequently, an adverse change in those factors could affect our estimate of our allowance for doubtful accounts. In some instances, we require new customers to establish escrow accounts or make prepayments. We typically invoice our customers at 15-day intervals during the performance of daywork contracts and upon completion of the daywork contract. Turnkey and footage contracts are invoiced upon completion of the contract. Our typical contract provides for payment of invoices in 10 to 30 days. We generally do not extend payment terms beyond 30 days and have not extended payment terms beyond 90 days for any of our contracts in the last three fiscal years. We had an allowance for doubtful accounts of $3,627,000 at September 30, 2007 and $1,000,000 at March 31, 2007.

Another critical estimate is our determination of the useful lives of our depreciable assets, which directly affects our determination of depreciation expense and deferred taxes. A decrease in the useful life of our drilling equipment would increase depreciation expense and reduce deferred taxes. We provide for depreciation of our drilling, transportation and other equipment on a straight-line method over useful lives that we have estimated and that range from three to 15 years. We record the same depreciation expense whether a rig is idle or working. Our estimates of the useful lives of our drilling, transportation and other equipment are based on our more than 35 years of experience in the drilling industry with similar equipment.

Our accrued insurance premiums and deductibles as of September 30, 2007 include accruals of approximately $752,000 and $6,792,000 for costs incurred under the self-insurance portion of our health insurance and under our workers' compensation insurance, respectively. We have a deductible of (1) $125,000 per covered individual per year under the health insurance and (2) $250,000 per occurrence under our workers' compensation insurance, except in North Dakota, where we do not have a deductible. Our deductible under our workers' compensation insurance increased to $500,000 in October 2007. We accrue for these costs as claims are incurred based on historical claim development data, and we accrue the costs of administrative services associated with claims processing. We also evaluate our claim cost estimates based on estimates provided by the insurance companies that provide claims processing services.

Liquidity and Capital Resources

Sources of Capital Resources

Our rig fleet has grown from eight rigs in August 2000 to 68 operating rigs as of October 31, 2007. We have financed this growth with a combination of debt and equity financing and internal cash flows. We have raised additional equity or used equity for growth nine times since January 2000. We plan to continue to grow our rig fleet and we may pursue other business opportunities that are complementary to our U.S. contract land drilling business. We may finance these growth opportunities through the issuance of debt and the issuance of additional shares of our common stock.

We have a $20,000,000 credit facility with Frost National Bank consisting of a $10,000,000 revolving line and letter of credit facility and a $10,000,000 acquisition facility for the acquisition of drilling rigs, drilling rig transportation equipment and associated equipment. Borrowings under the credit facility bear interest at a rate equal to Frost National Bank's prime rate (7.75% at September 30, 2007) or, at our option, at LIBOR plus a percentage ranging from 1.5% to 2.25%, based on our operating leverage ratio. Borrowings are secured by most of our assets, including all our United States drilling rigs and associated equipment and receivables. At September 30, 2007, we had no borrowings under the acquisition facility and we had used approximately $4,267,000 of availability under the revolving line and letter of credit facility through the issuance of letters of credit in the ordinary course of business. The remaining availability under the revolving line and letter of credit facility is $5,733,000. Both the revolving line and letter of credit facility and acquisition facility are scheduled to mature in October 2008.

Uses of Capital Resources

For the three and six months ended September 30, 2007, the additions to our
property and equipment consisted of the following:



                                          Three Months     Six Months
               Drilling rigs              $  20,940,696   $  56,598,615
               Other drilling equipment      28,222,095      43,464,982
               Transportation equipment       1,081,609       1,799,374
               Other                            213,357         500,915

                                          $  50,457,757   $ 102,363,886

Property and equipment additions for the six months ended September 30, 2007 include approximately $3,240,000 of purchases recorded in accounts payable at March 31, 2007.

As of March 31, 2007, we were constructing one 1000-horsepower mechanical rig. We placed this rig into service in April 2007 and incurred approximately $2,173,000 of rig construction costs during the six months ended September 30, 2007. In addition, we incurred approximately $53,609,000 during the six months ended September 30, 2007 to purchase and upgrade the three drilling rigs acquired for expansion into international markets. We expect to incur approximately $3,000,000 on additional acquisition and upgrade costs for these three drilling rigs during the remainder of fiscal year 2008.

For the remainder of fiscal year 2008, we project capital expenditures (excluding the new rig acquisition and upgrade costs for the three drilling rigs noted above) to be approximately $22,700,000, comprised of routine rig capital expenditures of approximately $16,300,000, rig upgrade expenditures of approximately $4,600,000, and other capital expenditures of approximately $1,800,000. We expect to fund these capital expenditures primarily from operating cash flow in excess of our working capital and other normal cash flow requirements.

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