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

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

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

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

There were 12,911,316 shares of the Registrant’s Common Stock outstanding as of the close of business on August 1, 2013.

ASSETS	June 30, 2013			September 30, 2012
		(unaudited)
Current assets:
Cash and cash equivalents	$	9,957		$	50,752
Short-term investments		—			19,960
Trade accounts receivable, net		33,164			16,229
Current portion of notes receivable, net		7,054			3,806
Inventories, net		137,503			83,894
Costs and estimated earnings in excess of billings		28,387			—
Deferred income tax assets		6,861			6,689
Prepaid expenses and other current assets		3,896			5,898

Total current assets		226,822			187,228

Rental equipment, net		33,572			27,853
Property, plant and equipment, net		45,686			34,433
Goodwill		1,843			1,843
Non-current deferred income tax assets		167			307
Non-current notes receivable, net		389			1,687
Prepaid income taxes		6,695			5,479
Other assets		110			192

Total assets	$	315,284		$	259,022

LIABILITIES AND STOCKHOLDERS’ EQUITY

Current liabilities:
Accounts payable trade	$	20,561		$	17,187
Accrued expenses and other current liabilities		14,367			13,978
Deferred revenue		734			8,641
Deferred income tax liabilities		—			111
Income taxes payable		2,457			1,275

Total current liabilities		38,119			41,192

Non-current deferred income tax liabilities		2,584			2,843

Total liabilities		40,703			44,035

Commitments and contingencies

Stockholders’ equity:
Preferred stock		—			—
Common stock		129			128
Additional paid-in capital		64,903			60,633
Retained earnings		210,324			154,451
Accumulated other comprehensive loss		(775	)		(225	)

Total stockholders’ equity		274,581			214,987

Total liabilities and stockholders’ equity	$	315,284		$	259,022

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

	Three Months Ended						Nine Months Ended
	June 30, 2013			June 30, 2012			June 30, 2013			June 30, 2012

Sales	$	78,148		$	55,201		$	232,319		$	154,715
Cost of sales		44,273			32,241			122,338			86,037

Gross profit		33,875			22,960			109,981			68,678

Operating expenses:
Selling, general and administrative		5,610			4,838			16,872			14,484
Research and development		3,327			2,800			10,460			9,198
Bad debt expense (recovery)		(53	)		(279	)		554			325
Total operating expenses		8,884			7,359			27,886			24,007

Income from operations		24,991			15,601			82,095			44,671

Other income (expense):
Interest expense		(62	)		(76	)		(192	)		(119	)
Interest income		236			118			695			561
Foreign exchange gains (losses)		(235	)		(9	)		(903	)		284
Other, net		11			(47	)		(8	)		(55	)

Total other income (expense), net		(50	)		(14	)		(408	)		671

Income before income taxes		24,941			15,587			81,687			45,342
Income tax expense		7,950			4,851			25,814			14,491

Net income	$	16,991		$	10,736		$	55,873		$	30,851

Basic earnings per share	$	1.32		$	0.84		$	4.34		$	2.42

Diluted earnings per share	$	1.31		$	0.83		$	4.32		$	2.40

Weighted average shares outstanding—Basic		12,911,316			12,748,166			12,873,677			12,726,252
Weighted average shares outstanding—Diluted		12,982,322			12,882,448			12,943,105			12,852,370

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

	Three Months Ended						Nine Months Ended
	June 30, 2013			June 30, 2012			June 30, 2013			June 30, 2012

Net income	$	16,991		$	10,736		$	55,873		$	30,851

Other comprehensive loss:
Change in unrealized gain on available- for-sale securities (net of tax)		(13	)		(9	)		(30	)		6
Foreign currency translations adjustments		(676	)		(972	)		(520	)		(769	)
Other comprehensive loss		(689	)		(981	)		(550	)		(763	)

Total comprehensive income	$	16,302		$	9,755		$	55,323		$	30,088

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

	Nine Months Ended June 30, 2013			Nine Months Ended June 30, 2012

Cash flows from operating activities:
Net income	$	55,873		$	30,851
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Deferred income tax expense (benefit)		(83	)		69
Depreciation and amortization		9,390			7,351
Accretion of discounts on short-term-investments		162			119
Stock-based compensation		434			555
Bad debt expense		554			325
Inventory obsolescence (recovery) provision		(77	)		1,395
Gross profit from the sale of used rental equipment		(12,180	)		(8,174	)
Loss on disposal of property, plant and equipment		14			3
Realized (gain) loss on short-term investments		(19	)		1
Effects of changes in operating assets and liabilities:
Trade accounts and notes receivable		(19,389	)		(2,873	)
Inventories		(58,404	)		(1,261	)
Costs and estimated earnings in excess of billings		(28,387	)		—
Prepaid expenses and other current assets		2,004			3,540
Prepaid income taxes		(1,216	)		(2,165	)
Accounts payable trade		3,384			567
Accrued expenses and other		3,270			2,572
Deferred revenue		(7,914	)		4,683
Income taxes payable		1,182			2,461

Net cash provided by (used in) operating activities		(51,402	)		40,019

Cash flows from investing activities:
Purchase of property, plant and equipment		(17,034	)		(3,049	)
Proceeds from the sale of property, plant and equipment		—			14
Investment in rental equipment		(19,579	)		(24,593	)
Proceeds from sale of used rental equipment		23,798			17,560
Purchases of short-term investments		(1,587	)		(15,336	)
Proceeds from the sale of short-term investments		21,139			1,580

Net cash provided by (used in) investing activities		6,737			(23,824	)

Cash flows from financing activities:
Excess tax benefit from stock-based compensation		2,948			493
Proceeds from exercise of stock options and other		917			636

Net cash provided by financing activities		3,865			1,129

Effect of exchange rate changes on cash		5			(6	)

Increase (decrease) in cash and cash equivalents		(40,795	)		17,318

Cash and cash equivalents, beginning of period		50,752			31,388

Cash and cash equivalents, end of period	$	9,957		$	48,706

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

The consolidated balance sheet of Geospace Technologies Corporation and its subsidiaries (the “Company”) at September 30, 2012 was derived from the Company’s audited consolidated financial statements at that date. The consolidated balance sheet at June 30, 2013 and the consolidated statements of operations and statements of comprehensive income for the three and nine months ended June 30, 2013 and 2012, and the consolidated statements of cash flows for the nine months ended June 30, 2013 and 2012 were prepared by the Company without audit. In the opinion of management, all adjustments, consisting of normal recurring adjustments, necessary to present fairly the consolidated financial position, results of operations and cash flows were made. The results of operations for the three and nine months ended June 30, 2013 are not necessarily indicative of the operating results for a full year or of future operations.

Certain information and footnote disclosures normally included in financial statements presented in accordance with accounting principles generally accepted in the United States of America were omitted. The accompanying consolidated financial statements should be read in conjunction with the financial statements and notes thereto contained in the Company’s Annual Report on Form 10-K for the year ended September 30, 2012.

Certain amounts previously presented in the consolidated financial statements have been reclassified to conform to the current year presentation. Effective October 1, 2012, the Company reports and categorizes its sales and products into two segments: Seismic and Non-Seismic. Prior year amounts have been reclassified to conform to the new presentation of the Company’s business segments. Such reclassifications had no effect on net income, stockholders’ equity or cash flows.

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires the use of estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. The Company considers many factors in selecting appropriate operational and financial accounting policies and controls, and in developing the estimates and assumptions that are used in the preparation of these financial statements. The Company continually evaluates its estimates, including those related to bad debt reserves, inventory obsolescence reserves, percentage-of-completion revenue recognition, self-insurance reserves, product warranty reserves, long-lived assets, intangible assets and deferred income tax assets. The Company bases its estimates on historical experience and various other factors that are believed to be reasonable under the circumstances. Actual results may differ from these estimates under different conditions or assumptions.

The Company considers all highly liquid investments purchased with an original or remaining maturity at the time of purchase of three months or less to be cash equivalents.

The Company classifies its short-term investments consisting of corporate bonds, government bonds and other such similar investments as available-for-sale securities. Available-for-sale securities are carried at fair market value with net unrealized holding gains and losses reported each period as a component of comprehensive income in stockholders’ equity. At June 30, 2013, the Company did not hold any short-term investments. See note 2 for additional information.

The Company records a write-down of its inventories when the cost basis of any manufactured product, including any estimated future costs to complete the manufacturing process, exceeds its net realizable value. Inventories are stated at the lower of cost or market value. Cost is determined on the first-in, first-out method, except that the Company’s subsidiary in the Russian Federation uses an average cost method to value its inventories.

The Company primarily derives revenue from the sale of its manufactured products, including revenues derived from the sale of its manufactured rental equipment. In addition, the Company generates revenue from the short-term rental under operating leases of its manufactured products. Except for revenues recognized using the percentage-of-completion method discussed below, the Company recognizes revenue from product sales, including the sale of used rental equipment, when (i) title passes to the customer, (ii) the customer assumes risks and rewards of ownership, (iii) the product sales price has been determined, (iv) collectability of the sales price is reasonably assured, and (v) product delivery occurs as directed by the customer. Except for certain of the Company’s reservoir characterization products, the Company’s products are generally sold without any customer acceptance provisions and the Company’s standard terms of sale do not allow customers to return products for credit. The Company recognizes rental revenues as earned over the rental period. Rentals of the Company’s equipment generally range from daily rentals to rental periods of up to six months or longer. Revenues from engineering services are recognized as services are rendered over the duration of a project, or as billed on a per hour basis. Field service revenues are recognized when services are rendered and are generally priced on a per day rate.

The Company utilizes the percentage-of-completion method (the “POC Method”) to recognize revenues and costs on contracts having the following characteristics:

The POC Method requires the Company’s senior management to make estimates, at least quarterly, of the (i) total costs of the contract, (ii) manufacturing progress against the contract and (iii) the estimated cost to complete the contract. These estimates impact the amount of revenue and gross profit the Company recognizes for each reporting period. Significant estimates that may affect the future cost to complete a contract include the cost and availability of raw materials and component parts, engineering services, manufacturing equipment, labor, manufacturing capacity, factory productivity, contract penalties and disputes, product warranties and other contingent factors. Change orders are included in the total estimated contract revenue when it is probable that the change order will result in additional value that can be reliably estimated and realized. The Company defers recognition of the entire amount of revenue or portion thereof associated with unapproved change orders if there is substantial uncertainty as to amounts involved or ultimate realization. The cumulative impact of periodic revisions to the future cost to complete a contract will be reflected in the period in which these changes become known, including, to the extent required, the recognition of losses at the time such losses are known and estimable. Due to the various estimates inherent in the POC Method, actual final results at the conclusion of a contract could differ from management’s previous estimates.

The Company analyzes a variety of indicators to determine manufacturing progress, including (i) actual costs incurred to date compared to total estimated costs, (ii) actual quantities produced to date compared to total contract quantities, and (iii) actual labor hours incurred to date compared to total estimated labor hours.

Cost of sales includes direct contract costs, such as materials and labor, and indirect costs that are attributable to a contract’s production activity. The timing of when the Company invoices its customer is dependent upon the completion of certain production milestones as defined in the contract. Cumulative contract costs and estimated earnings to date in excess of cumulative billings are reported as a current asset on the consolidated balance sheet as “costs and estimated earnings in excess of billings.” Cumulative billings in excess of cumulative costs and estimated earnings are reported as a current liability on the consolidated balance sheet as “billings in excess of costs and estimated earnings.” Any uncollected billed revenue, including contract retentions, is included in trade accounts receivable, net.

The Company records bill and hold arrangements consistent with guidance around bill and hold arrangements. As of June 30, 2013 and 2012, the Company had no sales under bill and hold arrangements.

The Company expenses research and development costs as incurred. Research and development costs include salaries, employee benefit costs, department supplies, direct project costs and other related costs.

Most of the Company’s products do not require installation assistance or sophisticated instructions. The Company offers a standard product warranty obligating it to repair or replace equipment with manufacturing defects. The Company maintains a reserve for future warranty costs based on historical experience or, in the absence of historical product experience, management’s estimates. Reserves for future warranty costs are included within accrued expenses and other current liabilities on the consolidated balance sheets.

Changes in the warranty reserve are reflected in the following table (in thousands):

	As of September 30, 2012 (in thousands)
	Amortized Cost		Unrealized Gains		Unrealized Losses		Estimated Fair Value

Short-term investments:
Corporate	$	11,072	$	37	$	—	$	11,109
Government		8,842		9		—		8,851

Total	$	19,914	$	46	$	—	$	19,960

Periodically the Company enters into foreign currency hedge arrangements. At June 30, 2013, the Company’s Canadian subsidiary had $28.1 million of Canadian dollar denominated intercompany accounts payable owed to the Company’s U.S. subsidiaries. In order to mitigate its exposure to movements in foreign currency rates between the U.S. dollar and Canadian dollar, during its third quarter ended June 30, 2013, the Company entered into a $20.0 million foreign currency forward contract to hedge a portion of the Canadian subsidiary’s Canadian dollar denominated debt. This contract reduces the impact on cash flows from movements in the Canadian dollar/U.S. dollar currency exchange rate. At June 30, 2013, the Company had accrued unrealized foreign exchange gains of $0.6 million under this contract.

The following table summarizes the gross fair value of all derivative instruments, which are not designated as hedging instruments and their location in the consolidated balance sheets (in thousands):

The following table summarizes the impact of the Company’s derivatives on the consolidated statements of operations for the three and nine month periods ended June 30, 2013 and 2012 (in thousands):

Amounts in the above table include realized and unrealized derivative gains and losses.

At June 30, 2013, the Company’s financial instruments included cash and cash equivalents, short-term investments, foreign currency forward contract, trade and notes receivables, other current assets, accounts payable and other current liabilities. Due to the short-term maturities of cash and cash equivalents, trade and other receivables, other current assets, accounts payable and other current liabilities, the carrying amounts approximate fair value on the respective balance sheet dates.

The Company measures its short-term investments and derivative instruments at fair value on a recurring basis.

The fair value measurement of the Company’s short-term investments and derivative instruments was determined using the following inputs:

	As of June 30, 2013 (in thousands)
	Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable (Level 2)		Significant Unobservable (Level 3)

Short-term investments:
Corporate bonds	$	—	$	—	$	—	$	—
Government bonds		—		—		—		—
Foreign currency forward contract		590		—		590		—

Total	$	590	$	—	$	590	$	—

	As of September 30, 2012 (in thousands)
	Total			Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable (Level 2)			Significant Unobservable (Level 3)

Short-term investments:
Corporate bonds	$	11,109		$	11,109	$	—		$	—
Government bonds		8,851			8,851		—			—
Foreign currency forward contract		(215	)		—		(215	)		—

Total	$	19,745		$	19,960	$	(215	)	$	—

The Company’s reserve for slow moving and obsolete inventories is analyzed and adjusted periodically to reflect the Company’s best estimate of the net realizable value of such inventories.

During the nine months ended June 30, 2013 and 2012, the Company made non-cash transfers of $4.7 million and $0.9 million, respectively, of inventories to its rental equipment fleet.

The allowance for doubtful accounts represents the Company’s best estimate of probable credit losses. The Company determines the allowance based upon historical experience and a review of its balances. Accounts receivable balances are charged off against the allowance whenever it is probable that the receivable will not be recoverable.

The Company provides long-term financing in the form of promissory notes when competitive conditions require such financing. Notes receivable bear interest and are generally collateralized by the products sold.

In October 2012, the Company implemented a 2-for-1 split of its common stock effected in the legal form of a stock dividend. All share and per-share disclosures for periods prior to October 2012 have been adjusted to give effect to the stock split.

The following table summarizes the calculation of net earnings and weighted average common shares and common equivalent shares outstanding for purposes of the computation of earnings per share (in thousands, except share and per share data):

	Three Months Ended				Nine Months Ended
	June 30, 2013		June 30, 2012		June 30, 2013		June 30, 2012

Net earnings available to common stockholders	$	16,991	$	10,736	$	55,873	$	30,851

Weighted average number of common share equivalents:
Common shares used in basic earnings per share		12,911,316		12,748,166		12,873,677		12,726,252
Common share equivalents outstanding related to stock options		71,006		134,282		69,428		126,118

Total weighted average common shares and common share equivalents used in diluted earnings per share		12,982,322		12,882,448		12,943,105		12,852,370

Basic earnings per common share	$	1.32	$	0.84	$	4.34	$	2.42

Diluted earnings per common share	$	1.31	$	0.83	$	4.32	$	2.40

There were no stock options excluded from the computation of weighted average shares outstanding due to antidilution.

Effective October 1, 2012, the Company reports and categorizes its sales and products into two business segments: Seismic and Non-Seismic. Prior to October 1, 2012, the Company reported its business segments as Seismic and Thermal Solutions. Effective October 1, 2012, the Seismic product lines include land and marine wireless data acquisition systems, seabed reservoir characterization products and services, geophones and hydrophones, leader wire, geophone string and acquisition system connectors, telemetry cables, marine streamer retrieval and steering devices and various other products. The Non-Seismic product lines include thermal imaging products and industrial products. The Company frequently has a minor amount of Seismic product sales to its Non-Seismic customers.

The following table summarizes the Company’s segment information (in thousands):

	Three Months Ended						Nine Months Ended
	June 30, 2013			June 30, 2012			June 30, 2013			June 30, 2012

Net sales:
Seismic	$	71,261		$	47,919		$	213,103		$	133,928
Non-Seismic		6,683			7,082			18,594			20,186
Corporate		204			200			622			601

Total	$	78,148		$	55,201		$	232,319		$	154,715

Income (loss) from operations:
Seismic	$	26,932		$	16,840		$	88,735		$	48,518
Non-Seismic		972			1,146			2,329			3,464
Corporate		(2,913	)		(2,385	)		(8,969	)		(7,311	)

Total	$	24,991		$	15,601		$	82,095		$	44,671

On March 2, 2011, the Company entered into a credit agreement (as amended, the “Credit Agreement”) with a bank. Under the Credit Agreement, the Company can borrow up to $25.0 million principally secured by its accounts receivable, inventories and equipment. In addition, certain domestic subsidiaries of the Company have guaranteed the obligations of the Company under the Credit Agreement and such subsidiaries have secured the obligations by the pledge of certain of the assets of such subsidiaries. The Credit Agreement expires on March 2, 2015. The Credit Agreement limits the incurrence of additional indebtedness, requires the maintenance of certain financial ratios, restricts the Company and its subsidiaries’ ability to pay dividends and contains other covenants customary in agreements of this type. The interest rate for borrowings under the Credit Agreement is a LIBOR based rate with a margin spread of 250 to 350 basis points depending upon the maintenance of certain ratios. At June 30, 2013, the Company was in compliance with all covenants. At June 30, 2013, there were no borrowings outstanding, there were $15,000 of standby letters of credit outstanding, and available borrowings under the Credit Agreement were $25.0 million.

The United States statutory tax rate for the three and nine months ended June 30, 2013 and 2012 was 35%. The Company’s effective tax rates for the three months ended June 30, 2013 and 2012 were 31.9% and 31.1%, respectively. The Company’s effective tax rates for the nine months ended June 30, 2013 and 2012 were 31.6% and 32.0%, respectively. Compared to the United States statutory rate of 35%, the Company’s lower effective tax rates for each of the periods ended June 30, 2013 and 2012 primarily resulted from a manufacturers’/producers’ deduction available to U.S. manufacturers.

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

The following is management’s discussion and analysis of the major elements of our consolidated financial statements. You should read this discussion and analysis together with our consolidated financial statements, including the accompanying notes, and other detailed information appearing elsewhere in this Quarterly Report on Form 10-Q.

This Quarterly Report on Form 10-Q and the documents incorporated by reference herein, if any, contain “forward-looking” statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. These forward-looking statements can be identified by terminology such as “may”, “will”, “should”, “intend”, “expect”, “plan”, “budget”, “forecast”, “anticipate”, “believe”, “estimate”, “predict”, “potential”, “continue”, “evaluating” or similar words. Statements that contain these words should be read carefully because they discuss our future expectations, contain projections of our future results of operations or of our financial position or state other forward-looking information. Examples of forward-looking statements include, among others, statements that we make regarding our expected operating results, the adoption and sale of our products in various geographic regions, anticipated levels of capital expenditures and the sources of funding therefore, and our strategy for growth, product development, market position, financial results and reserves. These forward-looking statements reflect our best judgment about future events and trends based on the information currently available to us. However, there will likely be events in the future that we are not able to predict or control. The factors listed under the caption “Risk Factors” in our Annual Report on Form 10-K for the fiscal year ended September 30, 2012 and the Quarterly Report on Form 10-Q for the fiscal quarter ended March 31, 2013, as well as other cautionary language in such Annual Report and Quarterly Report and this Quarterly Report, provide examples of risks, uncertainties and events that may cause our actual results to differ materially from the expectations we describe in our forward-looking statements. The occurrence of the events described in these risk factors and elsewhere in this Quarterly Report on Form 10-Q could have a material adverse effect on our business, results of operations and financial position, and actual events and results of operations may vary materially from our current expectations. We assume no obligation to revise or update any forward-looking statement, whether written or oral, that we may make from time to time, whether as a result of new information, future developments or otherwise.

Geospace Technologies Corporation is a Delaware corporation incorporated on September 27, 1994. Unless otherwise specified, the discussion in this Quarterly Report on Form 10-Q refers to Geospace Technologies Corporation and its subsidiaries. We design and manufacture instruments and equipment used in the acquisition and processing of seismic data as well as in the characterization and monitoring of producing oil and gas reservoirs. Demand for our products has been, and will likely continue to be, vulnerable to downturns in the economy and the oil and gas industry in general. For more information, please refer to the risks discussed under the heading “Risk Factors” in our Annual Report on Form 10-K for the fiscal year ended September 30, 2012 and the Quarterly Report on Form 10-Q for the fiscal quarter ended March 31, 2013.

We have engaged in the seismic instrument and equipment business since 1980 and market our products primarily to the oil and gas industry. We also design, manufacture and distribute non-seismic equipment including thermal imaging equipment and industrial products. We report and categorize our customers and products into two different segments: Seismic and Non-Seismic.

In February 2012 we received an order from Shell Brasil Petróleo Ltda for a $14.9 million seabed seismic reservoir monitoring system which was delivered in the second fiscal quarter. In November 2012, we received an order from Statoil for a $160 million seabed seismic reservoir monitoring system to be delivered over a three year period through fiscal year 2015 (the “Statoil Order”). As a result of these orders, we expect our future revenues from the sale of seismic reservoir products to increase significantly compared to historical sales levels.

Our seismic business segment accounts for the majority of our sales. Geoscientists use seismic data primarily in connection with the exploration, development and production of oil and gas reserves to map potential and known hydrocarbon bearing formations and the geologic structures that surround them. Our seismic product lines currently consist of land and marine nodal data acquisition systems, seabed reservoir characterization products and services, geophones and hydrophones, leader wire, geophone string and acquisition system connectors, telemetry cables, marine streamer retrieval and steering devices and various other products. Many of our seismic products are compatible with most major competitive seismic data acquisition systems currently in use. We believe that our seismic products are among the most technologically advanced instruments and equipment available for seismic data acquisition.

A seismic energy source and a seismic data recording system are combined to acquire seismic data. We provide many of the components of seismic data recording systems, including geophones, hydrophones, multi-component sensors, seismic leader wire, geophone strings, connectors, seismic telemetry cables and other seismic related products. On land, our customers use geophones, leader wire, cables and connectors to receive and measure seismic reflections resulting from an energy source to data recording units, which store information for processing and analysis. In the marine environment, large ocean-going vessels tow long seismic cables known as “streamers” containing hydrophones which are used to detect pressure changes. Hydrophones transmit electrical impulses back to the vessel’s data recording unit where the seismic data is stored for subsequent processing and analysis. Our marine seismic products help steer streamers while being towed and help recover streamers if they become disconnected from the vessel.

Our seismic sensor, cable and connector products are compatible with most major competitive seismic data acquisition systems currently in use, and sales result primarily from seismic contractors purchasing our products as components of new seismic data acquisition systems or to repair and replace components of seismic data acquisition systems already in use.

Our products used in marine seismic data acquisition include our marine seismic streamer retrieval devices (“SRDs”). Occasionally, streamer cables are severed and become disconnected from the vessel as a result of obstacles, inclement weather, vessel traffic or human error. Our SRDs, which are attached to the streamer cables, contain air bags which are designed to inflate automatically at a given depth, bringing the severed streamer cables to the surface. These SRDs save the seismic contractors significant time and money compared to the alternative of losing the streamer cable. We also produce seismic streamer steering devices, or “birds,” which are finlike devices that attach to the streamer cable. These birds help maintain the streamer cable at a certain desired depth as it is being towed through the water.

Our wholly-owned subsidiary in the Russian Federation manufactures international standard geophones, sensors, seismic leader wire, seismic telemetry cables and related seismic products for customers in the Russian Federation and other international seismic marketplaces. We have a branch office in Colombia that primarily rents seismic equipment to our customers in the South American market. Operating in foreign locations involves certain risks as discussed under the heading “Risk Factors – Our Foreign Subsidiaries and Foreign Marketing Efforts Face Additional Risks and Difficulties” in our Annual Report on Form 10-K for the fiscal year ended September 30, 2012.

We have developed a land-based wireless (or nodal) seismic data acquisition system. Each wireless station operates independently and therefore can be deployed in virtually unlimited channel configurations. Rather than utilizing interconnecting cables as required by most traditional land data acquisition systems, each wireless station operates as an independent data collection system. As a result, our wireless system requires less maintenance, which we believe allows our customers to operate more effectively and efficiently because of its reduced environmental impact, lower weight and ease of operation. Our wireless system is designed into configurations ranging from one to four channels per station. Since its introduction in 2008 and through June 30, 2013, we sold approximately 230,000 wireless channels and had approximately 71,000 wireless channels in our rental fleet available for rent. With the recent opening of a branch office in Bogotá, Colombia and the prospect for increasing demand for wireless rental equipment elsewhere in the world, we expect further increases in the size of our wireless product rental fleet during the remainder of fiscal year 2013.

We have also developed a marine-based wireless seismic data acquisition system. Similar to our land wireless system, the marine wireless system can be deployed in virtually unlimited channel configurations and does not require interconnecting cables between each station. Our deepwater versions of this marine wireless system can be deployed in depths of up to 3,000 meters.

Seismic surveys repeated over selected time intervals show dynamic changes within the reservoir and can be used to monitor the effects of oil and gas production. In this regard, we have developed permanently installed high-definition reservoir characterization products for ocean-bottom applications in producing oil and gas fields. We also produce a retrievable version of this ocean-bottom system for use on fields where permanently installed systems are not appropriate or economical. Utilizing these tools, producers can enhance the recovery of oil and gas deposits over the life of a reservoir.

Our high-definition reservoir characterization products include the HDSeis™ product line and a suite of borehole and reservoir characterization products and services. Our HDSeis™ System is a high-definition seismic data acquisition system with flexible architecture that allows it to be configured as a borehole seismic system or as a subsurface system for both land and marine reservoir-monitoring projects. The scalable architecture of the HDSeis™ System enables custom designed system configuration for applications ranging from low-channel engineering and environmental-scale surveys requiring a minimum number of recording channels to high-channel surveys required to efficiently conduct permanent reservoir imaging and monitoring. Modular architecture allows virtually unlimited channel expansion. In addition, multi-system synchronization features make the HDSeis™ System well suited for multi-well or multi-site acquisition, simultaneous surface and downhole acquisition and continuous reservoir monitoring projects.

Reservoir characterization requires special purpose or custom designed systems in which portability becomes less critical and functional reliability assumes greater importance. This reliability factor helps assure successful operations in inaccessible locations over a considerable period of time. Additionally, reservoirs located in deepwater or harsh environments require special instrumentation and new techniques to maximize recovery. Reservoir characterization also requires high-bandwidth, high-resolution seismic data for engineering project planning and reservoir management. We believe our HDSeis™ System and tools, designed for cost-effective deployment and lifetime performance, will make borehole and seabed seismic acquisition a cost-effective and reliable process for the challenges of reservoir characterization and monitoring. Our multi-component seismic product developments include an omni-directional geophone for use in reservoir monitoring, a compact marine three-component or four-component gimbaled sensor and special-purpose connectors, connector arrays and cases.

In addition, we produce seismic borehole acquisition systems which employ a fiber optic augmented wireline capable of very high data transmission rates. These systems are used for several reservoir characterization applications, including an application pioneered by us allowing operators and service companies to monitor and measure the results of fracturing operations.

Our non-seismic businesses leverage upon our existing manufacturing facilities and engineering capabilities. We have found that many of our seismic products, with little or no modification, have direct application to industries beyond those involved in oil and gas exploration and development. For example, our customers utilize our borehole tools to monitor subsurface carbon dioxide injections and for mine safety applications.

Our non-seismic products include thermal imaging products targeted at the commercial graphics industry as well as various industrial products. Our industrial products include (i) sensors and tools for vibration monitoring, mine safety application and earthquake detection, (ii) cables for power and communication for the offshore oil and gas and offshore construction industries, and (iii) water meter cables and other specialty cable and connector products.

We report and evaluate financial information for two segments: Seismic and Non-Seismic. Certain items prior to October 1, 2012 have been reclassified to conform to the new segment reporting. Summary financial data by business segment follows (in thousands):

	Three Months Ended						Nine Months Ended
	June 30, 2013			June 30, 2012			June 30, 2013			June 30, 2012

Seismic
Traditional exploration product revenues	$	10,818		$	17,162		$	38,727		$	53,395
Wireless exploration product revenues		15,967			28,898			78,545			68,244
Reservoir product revenues		44,476			1,859			95,831			12,289

Total seismic sales		71,261			47,919			213,103			133,928
Operating income		26,932			16,840			88,735			48,518

Non-Seismic
Net sales		6,683			7,082			18,594			20,186
Operating income		972			1,146			2,329			3,464

Corporate
Net sales		204			200			622			601
Operating loss		(2,913	)		(2,385	)		(8,969	)		(7,311	)

Consolidated Totals
Net sales		78,148			55,201			232,319			154,715
Operating income		24,991			15,601			82,095			44,671

Three and nine months ended June 30, 2013 compared to three and nine months ended June 30, 2012

Consolidated sales for the three months ended June 30, 2013 increased by $22.9 million, or 41.6%, from the corresponding period of the prior fiscal year. Consolidated sales for the nine months ended June 30, 2013 increased by $77.6 million, or 50.2%, from the corresponding period of the prior fiscal year. This increase reflects greater demand for our seismic permanent reservoir monitoring products.

Consolidated gross profit for the three months ended June 30, 2013 increased by $10.9 million, or 47.5%, from the corresponding period of the prior fiscal year. Consolidated gross profit for the nine months ended June 30, 2013 increased by $41.3 million, or 60.2%, from the corresponding period of the prior fiscal year. This increase in gross profit resulted from increased sales of our seismic permanent monitoring products which generally yield higher than average profit margins.

Consolidated operating expenses for the three months ended June 30, 2013 increased by $1.5 million, or 20.7%, from the corresponding period of the prior fiscal year. Consolidated operating expenses for the nine months ended June 30, 2013 increased by $3.9 million, or 16.2%, from the corresponding period of the prior fiscal year. Selling, general and administrative expenses increased by $2.4 million and research and development expenses increased by $1.3 million from the corresponding period of the prior fiscal year. The increase in operating expenses reflects higher personnel costs and other general increases associated with increased sales and asset expansion.

Other income (expense) for the three months ended June 30, 2013 decreased $36,000 from the corresponding period of the prior fiscal year due to larger foreign exchange losses and partially offset by an increase in interest income. Other income for the nine months ended June 30, 2013 decreased $1.1 million from the corresponding period of the prior fiscal year. The decrease in other income (expense) primarily resulted from foreign exchange losses on intercompany transactions and higher levels of interest expense related to our foreign exchange hedging activities.

The United States statutory tax rate for the three and nine months ended June 30, 2013 and 2012 was 35%. Our effective tax rates for the three months ended June 30, 2013 and 2012 were 31.9% and 31.1%, respectively. Our effective tax rates for the nine months ended June 30, 2013 and 2012 were 31.6% and 32.0%, respectively. Compared to the United States statutory rate of 35%, our lower effective tax rates for each of the periods ended June 30, 2013 and 2012 primarily resulted from a manufacturers’/producers’ deduction available to U.S. manufacturers.

Sales of our seismic products for the three months ended June 30, 2013 increased by $23.3 million, or 48.7%, from the corresponding period of the prior fiscal year. Sales of our seismic products for the nine months ended June 30, 2013 increased by $79.2 million, or 59.1%, from the corresponding period of the prior fiscal year. The components of this increase include the following:

The rate of new customer orders for our seismic products, especially our wireless products and large orders for our subsea reservoir products, generally occur irregularly thereby making it difficult for us to predict our sales and production levels each quarter. Furthermore, product shipping dates are generally determined by our customers and are not at our discretion. As a result, these factors have caused past sales of our seismic products to vary from period to period and we expect this trend to continue into the future.

Our operating income associated with sales of our seismic products for the three months ended June 30, 2013 increased by $10.1 million, or 59.9%, from the corresponding period of the prior fiscal year. The increase in operating income primarily resulted from the recognition of revenues from our reservoir products. Our operating income associated with sales of our seismic products for the nine months ended June 30, 2013 increased by $40.2 million, or 82.9%, from the corresponding period of the prior fiscal year. The higher level of operating income resulted from increased wireless product sales and the recognition of revenues from our reservoir products.

Sales of our non-seismic products for the three months ended June 30, 2013 decreased by $0.4 million, or 5.6%, from the corresponding period of the prior fiscal year. The decrease in sales is primarily due to a decline in deliveries of our offshore products. Sales of our non-seismic products for the nine months ended June 30, 2013 decreased by $1.6 million, or 7.9%, from the corresponding period of the prior fiscal year. This decrease is primarily due to lower sales of our industrial sensor products to our European customers which appear to have been impacted by the region’s economic crisis. We expect the European market for sales of our non-seismic products to remain challenging for the remainder of fiscal year 2013.

Our operating income associated with sales of our non-seismic products for the three months ended June 30, 2013 decreased $0.2 million, or 15.3%, from the corresponding period of the prior fiscal year. Our operating income associated with sales of our non-seismic products for the nine months ended June 30, 2013 decreased $1.1 million, or 32.8%, from the corresponding period of the prior fiscal year. The decrease in operating income for both periods resulted from lower sales levels, and lower profit margins due to less favorable sales mix and lower manufacturing volume for our thermal imaging business.

We adopted an incentive compensation program for fiscal year 2013 whereby most employees will be eligible to begin earning incentive compensation if the Company reaches a five percent pretax return on stockholders’ equity, determined as of September 30, 2012. To be eligible to participate in this incentive compensation program, employees must participate in our Core Values Program. Based on our experience in prior years, we expect one hundred percent of our eligible employees to participate in the Core Values Program. The incentive compensation program does not apply to the employees of our Russian subsidiary as such employees participate in a locally administered bonus program. Certain non-executive employees are required to achieve specific goals to earn a significant portion of their total incentive compensation award. Any bonus awards earned under this program in fiscal year 2013 will be paid out to eligible employees after the end of the fiscal year.

Upon reaching the five percent pretax return threshold, an incentive compensation accrual is established equal to 16.7 percent of the amount of any consolidated pretax profits above the five percent pretax return threshold. The initial maximum aggregate bonus available under the program for fiscal year 2013 will be $6.5 million. Under this program, for the three months ended June 30, 2013 and 2012, we had accrued $1.4 million and $1.2 million, respectively, of incentive compensation expense. Under this program, for the nine months ended June 30, 2013 and 2012, we had accrued $5.3 million and $5.7 million, respectively, of incentive compensation expense.

At June 30, 2013, we had approximately $10.0 million in cash and cash equivalents. For the nine months ended June 30, 2013, we used approximately $51.4 million of cash from operating activities. Sources of cash generated in our operating activities included our net income of $55.9 million. Additional sources of cash included (i) net non-cash charges of $10.4 million for deferred income taxes, depreciation, amortization, accretion, stock-based compensation, inventory obsolescence and bad debts, (ii) a $3.4 million increase in accounts payable due to increases in our rental equipment fleet and the timing of payments to our vendors, (iii) a $3.3 million increase accrued expenses and other, (iv) a $2.0 million decrease in prepaid expenses and other current assets due to vendor prepayment requirements and tax deposits and (v) a $1.2 million increase in income tax payable resulting from the timing of our income tax payments. These sources of cash were offset by uses of cash which included (i) a $58.4 million increase in inventories due to current and expected future production for the Statoil order and production of our new marine wireless nodal products and our land wireless products in anticipation of future product orders, (ii) a $28.4 million increase in costs and estimated earnings in excess of billings for the Statoil order, (iii) a $19.4 million increase in trade accounts and notes receivable primarily resulting from increased sales and the timing of cash collections, (iv) a $12.2 million adjustment to transfer gross profits from rental equipment sales to investing activities since such transactions involve the sale of long-lived assets, (v) a $7.9 million decrease in deferred revenue primarily due to the revenue recognition of advance payments received from Shell Brasil Petróleo Ltda and (vi) a $1.2 million increase in prepaid income taxes related to intercompany product sales.

For the nine months ended June 30, 2013, we generated approximately $6.7 million of cash in investing activities. We used $19.6 million of cash to expand our rental equipment fleet to meet customer demand. This investment in rental equipment was offset by $23.8 million of proceeds from the sale of rental equipment. We currently estimate that our total gross fiscal year 2013 investments in rental equipment capital could exceed $30 million or more depending on future customer demand for land and marine wireless systems during the remainder of the year. We used $17.0 million of cash for investments in property and equipment, including $6.1 million of real property acquisitions in Houston and Bogotá. We estimate that our total fiscal year 2013 investments in property and equipment could be approximately $20 million. We expect these capital expenditures will be financed from our cash on hand, internal cash flow, rental equipment sales proceeds and/or from borrowings under our Credit Agreement. These uses of cash were partially offset by $19.6 million of net proceeds from the sale of short-term investments.

For the nine months ended June 30, 2013, we generated approximately $3.9 million of cash in financing activities resulting from cash proceeds received from the exercise of stock options and the associated tax benefit related to such exercised stock options.

On March 2, 2011, we entered into a credit agreement (as amended, the “Credit Agreement”) with a bank. Under the Credit Agreement, we can borrow up to $25.0 million principally secured by our accounts receivable, inventories and equipment. In addition, certain of our domestic subsidiaries have guaranteed our obligations under the Credit Agreement and such subsidiaries have secured

the obligations by the pledge of certain of the assets of such subsidiaries. The Credit Agreement expires on March 2, 2015. The Credit Agreement limits the incurrence of additional indebtedness, requires the maintenance of certain financial ratios, restricts us and our subsidiaries’ ability to pay cash dividends and contains other covenants customary in agreements of this type. The interest rate for borrowings under the Credit Agreement is a LIBOR based rate with a margin spread of 250-350 basis points depending upon the maintenance of certain ratios. At June 30, 2013, the interest rate was 2.7%. At June 30, 2013, there were no borrowings outstanding, $15,000 of standby letters of credit outstanding, and available borrowings under the Credit Agreement were $25.0 million. Please see “Risk Factors – The Credit Agreement Imposes Restrictions on Our Business” in our Annual Report on Form 10-K for the fiscal year ended September 30, 2012 for more information about the restrictive covenants imposed on us by the Credit Agreement.

Critical Accounting Policies are included in Financial Note 1, “Significant Accounting Policies,” in the Financial Notes in Item 1 of Part I of this Quarterly Report on Form 10-Q.

We have some market risk relative to sensitive instruments entered into for trading purposes and have only very limited risk as to arrangements entered into other than for trading purposes. We do not engage in commodity or commodity derivative instrument purchase or sales transactions. Because of the inherent unpredictability of foreign currency rates and interest rates, as well as other factors, actual results could differ materially from those projected in this Item.

One of our wholly-owned subsidiaries, Geospace Technologies Eurasia, is located in the Russian Federation. In addition, another of our wholly-owned subsidiaries, Geospace Technologies Sucursal Sudamericana, is located in Colombia. Our financial results for these entities may be affected by factors such as changes in foreign currency exchange rates, weak economic conditions, or changes in the political climate. Our consolidated balance sheet at June 30, 2013 reflected approximately $6.8 million and $0.6 million of net working capital related to our Russian and Colombian operations, respectively. Both of these entities receive a portion of their revenues and pay a majority of their expenses primarily in their local currency. To the extent that transactions of these entities are settled in their local currency, a devaluation of these currencies versus the U.S. dollar could reduce any contribution from these entities to our consolidated results of operations and total comprehensive income as reported in U.S. dollars. We do not hedge the market risk with respect to our operations in these countries; therefore, such risk is a general and unpredictable risk of future disruptions in the valuation of such currencies versus U.S. dollars to the extent such disruptions result in any reduced valuation of these foreign entities’ net working capital or future contributions to our consolidated results of operations. At June 30, 2013, the foreign exchange rate for $1.00 (one U.S. dollar) was equal to 32.9 Russian Rubles and 1,930 Colombian Pesos, respectively. If the value of the U.S. dollar were to decline by ten percent against these foreign currencies, our working capital in the Russian Federation and Colombia could decline by $0.7 million and $63,000, respectively.

From time to time, we provide access to capital to our foreign subsidiaries through U.S. dollar denominated interest bearing promissory notes. Such funds are generally used by our foreign subsidiaries to purchase capital assets and for general working capital needs. In addition, we sell products to our foreign subsidiaries on trade credit terms in both U.S. dollars and in the subsidiary’s local currency. Because we have intercompany debts denominated in foreign currencies, any appreciation or devaluation of such foreign currencies against the U.S. dollar will result in a gain or loss, respectively, to our consolidated statement of operations. At June 30, 2013, we had outstanding intercompany accounts receivable of $28.1 million from our Canadian subsidiary which are denominated in Canadian dollars. We entered into an agreement with a United States bank to hedge $20.0 million of this foreign exchange exposure, resulting in a net Canadian dollar denominated intercompany accounts payable exposure to the U.S. dollar of $8.1 million at June 30, 2013. At June 30, 2013, the foreign exchange rate of the U.S. dollar to the Canadian dollar was 1:0.95. If the U.S. dollar exchange rate were to strengthen by ten percent against the Canadian dollar, we would recognize a foreign exchange loss of $0.8 million in our consolidated financial statements.

The Credit Agreement contains a floating interest rate, which subjects us to the risk of increased interest costs associated with any upward movements in bank market interest rates. Under the Credit Agreement our borrowing interest rate is a LIBOR based rate plus 250-350 basis points. As of June 30, 2013, we had no borrowings under the Credit Agreement.

Our management is responsible for establishing and maintaining a system of disclosure controls and procedures that are designed to ensure that information required to be disclosed in our reports filed under the Exchange Act is recorded, processed, summarized and reported within the time periods specified under the Securities and Exchange Commission’s rules and forms, and that such information is accumulated and communicated to our management, including our Chief Executive Officer (“CEO”) and Chief Financial Officer (“CFO”). Notwithstanding the foregoing, there can be no assurance that the Company’s disclosure controls and procedures will detect or uncover all failures of persons within the Company and its consolidated subsidiaries to report material information otherwise required to be set forth in the Company’s reports.

In connection with the preparation of this Quarterly Report on Form 10-Q, the Company carried out an evaluation under the supervision and with the participation of the Company’s management, including the CEO and CFO, as of June 30, 2013 of the effectiveness of the Company’s disclosure controls and procedures, as such term is defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act. Based on that evaluation, the CEO and CFO concluded that our disclosure controls and procedures were effective as of June 30, 2013.

There were no changes in the Company’s internal control over financial reporting that occurred during the Company’s fiscal quarter ended June 30, 2013 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

Delaware		76-0447780
(State or Other Jurisdiction of Incorporation or Organization)		(I.R.S. Employer Identification No.)

Large accelerated filer	x	Accelerated filer	¨

Non-accelerated filer	¨ (Do not check if a smaller reporting company)	Smaller reporting company	¨

		Page Number
PART I. FINANCIAL INFORMATION

Item 1.	Financial Statements	3

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	16

Item 3.	Quantitative and Qualitative Disclosures about Market Risk	23

Item 4.	Controls and Procedures	24

PART II. OTHER INFORMATION


Item 6.	Exhibits	25

Balance at October 1, 2012	$	2,308
Accruals for warranties issued during the period		288
Settlements made (in cash or in kind) during the period		(583	)
Balance at June 30, 2013	$	2,013

Derivative Instrument	Location of Gain on Derivative Instrument		Three Months Ended June 30				Nine Months Ended June 30
Derivative Instrument	Location of Gain on Derivative Instrument		2013		2012		2013		2012

Foreign Currency Forward Contracts		Other Income (Expense)		657		285		812		137

			$	657	$	285	$	812	$	137

Derivative Instrument	Location		June 30, 2013		September 30, 2012

Foreign Currency Exchange Contracts		Prepaid and other	$	590	$	—
Foreign Currency Exchange Contracts		Accrued Expenses		—		215

			$	590	$	215

	June 30, 2013			September 30, 2012

Change in unrealized gains (losses) on available-for-sale securities (net of tax)	$	—		$	30
Foreign currency translation adjustments		(775	)		(255	)

	$	(775	)	$	(225	)

	June 30, 2013			September 30, 2012

Finished goods	$	23,653		$	32,845
Work-in-process		34,788			19,585
Raw materials		86,221			40,788
Obsolescence reserve		(7,159	)		(9,324	)

	$	137,503		$	83,894

	June 30, 2013			September 30, 2012

Trade accounts receivable	$	33,911		$	16,509
Allowance for doubtful accounts		(747	)		(280	)

	$	33,164		$	16,229

	June 30, 2013		September 30, 2012

Notes receivable	$	7,443	$	5,493
Allowance for doubtful notes		—		—
		7,443		5,493
Less current portion		7,054		3,806

Long-term portion	$	389	$	1,687

31.1		Certification of the Company’s Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

31.2		Certification of the Company’s Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

32.1		Certification of the Company’s Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

32.2		Certification of the Company’s Chief Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

101		Interactive data file.

				GEOSPACE TECHNOLOGIES CORPORATION

Date:	August 7, 2013	By:		/s/ Gary D. Owens
				Gary D. Owens, Chairman of the Board, President and Chief Executive Officer (duly authorized officer)

Date:	August 7, 2013		By:	/s/ Thomas T. McEntire
				Thomas T. McEntire, Vice President, Chief Financial Officer and Secretary (principal financial officer)