Edgar Filing: SEITEL INC

Large accelerated filer

Accelerated filer

Non-accelerated filer

ý (Do not check if a smaller reporting company)

Smaller reporting company

Emerging growth company

Document

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

_______________________________________________

FORM 10-Q

(Mark One)



ý	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2017



¨	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

Commission File Number: 001-10165

_______________________________________________

SEITEL, INC.

(Exact name of registrant as specified in its charter)

_______________________________________________



Delaware		76-0025431
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

10811 S. Westview Circle Drive Building C, Suite 100 Houston, Texas		77043
(Address of principal executive offices)		(Zip Code)

(713) 881-8900

(Registrant’s telephone number, including area code)

_______________________________________________

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 ¨ No ý

(Explanatory Note: The registrant is a voluntary filer and is therefore not subject to the filing requirements of the Securities Exchange Act of 1934. However, during the preceding 12 months, the registrant has filed all reports that it would have been required to file by Section 13 or 15(d) of the Securities Exchange Act of 1934 if the registrant was subject to the filing requirements of the Securities Exchange Act of 1934 during such timeframe.)

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 (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

Yes ý No ¨

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

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes ¨ No ý

As of August 7, 2017, there were 100 shares of the Company’s common stock outstanding, par value $.001 per share.

Table of Contents

TABLE OF CONTENTS




		Page
PART I.	FINANCIAL INFORMATION
	Item 1. Financial Statements	3
	Condensed Consolidated Balance Sheets (Unaudited)	3
	Condensed Consolidated Statements of Operations (Unaudited)	4
	Condensed Consolidated Statements of Comprehensive Loss (Unaudited)	5
	Condensed Consolidated Statement of Stockholder’s Equity (Unaudited)	6
	Condensed Consolidated Statements of Cash Flows (Unaudited)	7
	Notes to Condensed Consolidated Interim Financial Statements (Unaudited)	8
	Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	28
	Item 3. Quantitative and Qualitative Disclosures about Market Risk	35
	Item 4. Controls and Procedures	35
PART II.	OTHER INFORMATION
	Item 1. Legal Proceedings	35
	Item 1A. Risk Factors	35
	Item 6. Exhibits	36
	SIGNATURES	36

Table of Contents

PART I—FINANCIAL INFORMATION


Item 1.	FINANCIAL STATEMENTS

SEITEL, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands, except share and per share amounts)



	(Unaudited) June 30, 2017			December 31, 2016
ASSETS
Cash and cash equivalents	$	60,843		$	55,997
Receivables
Trade, net of allowance for doubtful accounts of $178 and $223, respectively	18,281			24,481
Notes and other	395			436
Due from Seitel Holdings, Inc.	1,185			1,177
Seismic data library, net of accumulated amortization of $1,229,789 and $1,176,828, respectively	91,286			115,922
Property and equipment, net of accumulated depreciation and amortization of $16,880 and $16,478, respectively	1,622			1,709
Prepaid expenses, deferred charges and other	2,497			1,762
Intangible assets, net of accumulated amortization of $48,858 and $47,826, respectively	900			1,418
Goodwill	184,368			182,012
Deferred income taxes	272			257
TOTAL ASSETS	$	361,649		$	385,171
LIABILITIES AND STOCKHOLDER’S EQUITY
LIABILITIES
Accounts payable and accrued liabilities	$	16,155		$	17,007
Income taxes payable	532			620
Senior Notes	247,484			246,857
Obligations under capital leases	1,443			1,510
Deferred revenue	12,914			15,904
Deferred income taxes	1,680			2,214
TOTAL LIABILITIES	280,208			284,112
COMMITMENTS AND CONTINGENCIES (Note G)
STOCKHOLDER’S EQUITY
Common stock, par value $.001 per share; 100 shares authorized, issued and outstanding	—			—
Additional paid-in capital	400,588			400,582
Retained deficit	(306,205		)	(283,190		)
Accumulated other comprehensive loss	(12,942		)	(16,333		)
TOTAL STOCKHOLDER’S EQUITY	81,441			101,059
TOTAL LIABILITIES AND STOCKHOLDER’S EQUITY	$	361,649		$	385,171

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

Table of Contents

SEITEL, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

(In thousands)



	Three Months Ended June 30,						Six Months Ended June 30,
	2017			2016			2017			2016
REVENUE	$	23,700		$	24,340		$	44,295		$	36,290
EXPENSES:
Depreciation and amortization	21,969			24,805			44,232			39,906
Cost of sales	33			11			43			33
Selling, general and administrative	5,005			4,668			10,651			10,627
	27,007			29,484			54,926			50,566
LOSS FROM OPERATIONS	(3,307		)	(5,144		)	(10,631		)	(14,276		)
Interest expense, net	(6,187		)	(6,334		)	(12,397		)	(12,690		)
Foreign currency exchange gains (losses)	(34		)	(10		)	(85		)	163
Other income	96			4			96			10
Loss before income taxes	(9,432		)	(11,484		)	(23,017		)	(26,793		)
Provision (benefit) for income taxes	204			(2,249		)	(2		)	(3,694		)
NET LOSS	$	(9,636	)	$	(9,235	)	$	(23,015	)	$	(23,099	)

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

Table of Contents

SEITEL, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS (Unaudited)

(In thousands)



	Three Months Ended June 30,						Six Months Ended June 30,
	2017			2016			2017			2016
Net loss	$	(9,636	)	$	(9,235	)	$	(23,015	)	$	(23,099	)
Foreign currency translation adjustments	2,569			(308		)	3,391			6,436
Comprehensive loss	$	(7,067	)	$	(9,543	)	$	(19,624	)	$	(16,663	)

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

Table of Contents

SEITEL, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENT OF STOCKHOLDER’S EQUITY (Unaudited)

(In thousands, except share amounts)



				Additional Paid-In Capital		Retained Deficit			Accumulated Other Comprehensive Loss
	Common Stock
	Shares	Amount
Balance, December 31, 2016	100	$	—	$	400,582	$	(283,190	)	$	(16,333	)
Amortization of stock-based compensation costs	—	—		6		—			—
Net loss	—	—		—		(23,015		)	—
Foreign currency translation adjustments	—	—		—		—			3,391
Balance, June 30, 2017	100	$	—	$	400,588	$	(306,205	)	$	(12,942	)

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

Table of Contents

SEITEL, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

(In thousands)



	Six Months Ended June 30,
	2017			2016
Cash flows from operating activities:
Reconciliation of net loss to net cash provided by operating activities:
Net loss	$	(23,015	)	$	(23,099	)
Depreciation and amortization	44,232			39,906
Deferred income tax benefit	(585		)	(3,703		)
Foreign currency exchange losses (gains)	85			(163		)
Amortization of deferred financing costs	627			628
Amortization of stock-based compensation	6			76
Decrease in allowance for doubtful accounts	—			(21		)
Gain on sale of seismic data and property and equipment	(96		)	(7		)
Non-cash revenue	(1,407		)	(1,364		)
Decrease (increase) in receivables	6,441			(10,413		)
Increase in other assets	(165		)	(10		)
Decrease in deferred revenue	(2,888		)	(1,160		)
Increase (decrease) in accounts payable and other liabilities	(2,381		)	4,084
Net cash provided by operating activities	20,854			4,754
Cash flows from investing activities:
Cash invested in seismic data	(16,101		)	(12,869		)
Cash paid to acquire property and equipment	(250		)	(145		)
Cash from sale of property and equipment	3			18
Advances to Seitel Holdings, Inc.	(8		)	(16		)
Net cash used in investing activities	(16,356		)	(13,012		)
Cash flows from financing activities:
Principal payments on capital lease obligations	(112		)	(100		)
Net cash used in financing activities	(112		)	(100		)
Effect of exchange rate changes	460			156
Net increase (decrease) in cash and cash equivalents	4,846			(8,202		)
Cash and cash equivalents at beginning of period	55,997			52,675
Cash and cash equivalents at end of period	$	60,843		$	44,473
Supplemental disclosure of cash flow information:
Cash paid during the period for:
Interest	$	11,940		$	12,102
Income taxes, net of refunds received	$	690		$	(187	)
Supplemental schedule of non-cash investing and financing activities:
Additions to seismic data library	$	1,250		$	1,022

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

Table of Contents

SEITEL, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED INTERIM FINANCIAL STATEMENTS (Unaudited)

June 30, 2017

NOTE A-BASIS OF PRESENTATION

The accompanying condensed consolidated financial statements of Seitel, Inc. and its subsidiaries (collectively, the “Company”) have been prepared in accordance with United States generally accepted accounting principles (“GAAP”) for interim financial information and with the instructions of Regulation S-X. Accordingly, they do not include all of the information and notes required by GAAP for complete financial statements. In the opinion of management, all adjustments (consisting of normal recurring adjustments) considered necessary for a fair presentation have been included. In preparing the Company’s financial statements, a number of estimates and assumptions are made by management that affect the accounting for and recognition of assets, liabilities, revenues and expenses. Operating results for the three and six months ended June 30, 2017 are not necessarily indicative of the results that may be expected for any other quarter of 2017 or for the year ending December 31, 2017. The condensed consolidated balance sheet of the Company as of December 31, 2016 has been derived from the audited balance sheet of the Company as of that date. These 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 fiscal year ended December 31, 2016.

NOTE B-REVENUE RECOGNITION

Revenue from Data Acquisition

The Company generates revenue when it creates a new seismic survey that is initially licensed by one or more of its customers to use the resulting data. The payments for the initial licenses are sometimes referred to as acquisition underwriting or prefunding. Customers make periodic payments throughout the new survey creation period, which generally correspond to costs incurred and work performed. These payments are non-refundable. Contracts which are signed up to the time the Company makes a firm commitment to create the new seismic survey are considered acquisition underwriting. Any subsequent license of the data while the survey is in progress or once it is completed is considered a resale license (see “Revenue from Non-Exclusive Data Licenses”).

Acquisition underwriting revenue is recognized throughout the new survey creation period using the proportional performance method based upon costs incurred and work performed to date as a percentage of total estimated costs and work required. Management believes that this method is the most reliable and representative measure of progress for its new survey creation projects. On average, the duration of the new survey creation process is approximately twelve to eighteen months. Under the contracts related to the new survey, the Company creates new seismic data designed in conjunction with its customers and specifically suited to the geology of the area using the most appropriate technology available.

The Company outsources the substantial majority of the work required to complete data acquisition projects to third party contractors. The Company’s payments to these third party contractors comprise the substantial majority of the total estimated costs of the projects and are paid throughout the new survey creation period. A typical survey includes specific activities required to complete the survey creation, each of which has value to the customers. Typical activities, that often occur concurrently, include:


•	permitting for land access, mineral rights, and regulatory approval;


•	surveying;


•	drilling for the placement of energy sources;


•	recording the data in the field; and


•	processing the data.

The customers paying for the initial licenses to the data created from a new survey receive legally enforceable rights to any resulting product of each activity described above. The customers also receive access to and use of the newly acquired, processed data.

The customers’ access to and use of the results of the work performed and of the newly acquired, processed data is governed by a master license agreement, which is a separate agreement from the acquisition contract. The Company’s acquisition contracts require the customer either to have a master license agreement in place or to execute one at the time the acquisition contract is signed. The Company typically maintains sole ownership of the newly acquired data, which is added to its library, and is free to license the data to other customers.

Table of Contents

Revenue from Non-Exclusive Data Licenses

The Company recognizes a substantial portion of its revenue from licensing of data once it is available for delivery. This revenue is sometimes referred to as resale licensing revenue, late sales or shelf sales.

These sales fall under the following four basic forms of non-exclusive license contracts, each of which is subject to the terms and conditions contained in a customer’s master license agreement.


•	Specific license contract—The customer licenses and selects specific data from the data library, including data currently in progress, at the time the contract is entered into and holds this license for a long-term period.


•	Library card license contract—The customer initially receives only the right to access a certain amount of data. The customer selects which data to access and hold long-term under its license agreement. The length of the selection periods under the library card contracts is limited in time and varies from customer to customer.


•	Review and possession license contract—The customer receives the right to review a certain quantity of data for a limited period of time. During the review period, the customer may select specific data from that available for review to hold long-term under its license agreement. Any data not selected for long-term licensing must be returned to the Company at the end of the review period.


•	Review only license contract—The customer obtains rights to review a certain quantity of data for a limited period of time, but does not obtain the right to select specific data to hold long-term.

The Company’s non-exclusive license contracts specify the following:


•	that all customers must also have in place or execute a master license agreement that governs the use of all data received under each non-exclusive license contract;


•	the specific payment terms, generally ranging from 30 days to 12 months, and that such payments are non-cancelable and non-refundable;


•	the actual data that is accessible to the customer; and


•	that the data is licensed in its present form, as is, where is, and that the Company is under no obligation to make any enhancements, modifications or additions to the data unless specific terms to the contrary are included.

Revenue from the non-exclusive licensing of seismic data is recognized when the following criteria are met:


•	the Company has an agreement with the customer that is validated by a signed contract;


•	the sales price is fixed and determinable;


•	collection is reasonably assured;


•	the customer has selected the specific data or the contract has expired without full selection;


•	the data is currently available for delivery; and


•	the license term has begun.

Copies of the licensed data are available to the customer immediately upon request.

For licenses that have been invoiced for which payment is due or has been received, but that have not met the aforementioned criteria, revenue is deferred along with the related direct costs (primarily consisting of sales commissions). This normally occurs under the library card, review and possession or review only license contracts because the data selection may occur over time. Additionally, if the contract allows licensing of data that is not currently available or enhancements, modifications or additions to the data are required per the contract, revenue is deferred until such time that the data is available.

Revenue from Non-Monetary Exchanges

In certain cases, the Company will take ownership of a customer’s seismic data or revenue interest (collectively referred to as “data”) in exchange for a non-exclusive license to selected seismic data from the Company’s library or, in some cases, reproduction or data processing services. In connection with specific data acquisition contracts, the Company may choose to receive both cash and ownership of seismic data from the customer as consideration for the underwriting of new data acquisition. In addition, the Company may receive advanced data processing services from a customer on selected existing data in exchange for a non-exclusive license to selected data from the Company’s library. These transactions are referred to as non-monetary exchanges. A non-monetary exchange for data always complies with the following criteria:


•	the data licensed to a customer is always distinct from the data received from that customer;

Table of Contents


•	the customer forfeits ownership of the data received by the Company; and


•	the Company retains ownership in the data licensed.

In non-monetary exchange transactions, the Company records a data library asset for the seismic data received or processed at the time the contract is entered into or the data is completed, as applicable, and recognizes revenue on the transaction in equal value in accordance with its policy on revenue from data licenses or data acquisition, or as services are provided by our Seitel Solutions business unit (“Solutions”), as applicable. The data license to the customer is in the form of one of the four basic forms of contracts discussed above. These transactions are valued at the fair value of the data received by the Company or the fair value of the license granted or services provided to the customer, whichever is more readily determinable.

Fair value of the data exchanged is determined using a multi-step process as follows:

•

First, the Company considers the value of the data or services received from the customer. In determining the value of the data received, the Company considers the age, quality, current demand and future marketability of the data and, in the case of 3D seismic data, the cost that would be required to create the data. In addition, the Company applies a limitation on the value it assigns per square mile on the data received. In determining the value of the services received, the Company considers the cost of such similar services that it could obtain from a third party provider.


•	Second, the Company determines the value of the license granted to the customer. Typically, the range of cash transactions by the Company for licenses of similar data during the prior six months are evaluated. In evaluating the range of cash transactions, the Company does not consider transactions that are disproportionately high or low.

Due to the Company’s revenue recognition policies, revenue recognized on non-monetary exchange transactions may not occur at the same time that the seismic data acquired is recorded as an asset. The activity related to non-monetary exchanges was as follows (in thousands):



	Three Months Ended June 30,				Six Months Ended June 30,
	2017		2016		2017		2016
Seismic data library additions	$	1,000	$	800	$	1,250	$	1,022
Revenue recognized on specific data licenses or selections of data	1,000		1,340		1,250		1,340
Revenue recognized related to acquisition contracts	87		23		126		24
Revenue recognized related to Solutions and other revenue	31		—		31		—

Revenue from Solutions

Revenue from Solutions is recognized as the services for reproduction and delivery of seismic data are provided to customers.

NOTE C-SEISMIC DATA LIBRARY

The Company’s seismic data library consists of seismic surveys that are offered for license to customers on a non-exclusive basis. Costs associated with creating, acquiring or purchasing the seismic data library are capitalized and amortized principally on the income forecast method subject to a straight-line amortization period of four years, applied on a quarterly basis at the individual survey level.

Costs of Seismic Data Library

For newly created data, the capitalized costs include costs paid to third parties for the acquisition of data and related permitting, surveying and other activities associated with the data creation activity. In addition, the Company capitalizes certain internal costs related to processing the created data and reprocessing existing data. Such costs include salaries and benefits of the Company’s processing personnel and certain other costs incurred for the benefit of the processing activity. The Company believes that the internal processing costs capitalized are not greater than, and generally are less than, those that would be incurred and capitalized if such activity were performed by a third party. Capitalized costs for internal data processing were $0.6 million and $0.8 million for the three months ended June 30, 2017 and 2016, respectively and $1.3 million and $1.5 million for the six months ended June 30, 2017 and 2016, respectively.

For data received through a non-monetary exchange, the Company capitalizes an amount equal to the fair value of the data received by the Company or the fair value of the license granted or services provided to the customer, whichever is more readily determinable. See Note B – “Revenue Recognition – Revenue from Non-Monetary Exchanges” for discussion of the process used to determine fair value.

For purchased seismic data, the Company capitalizes the purchase price of the acquired data.

Table of Contents

Data Library Amortization

The Company amortizes each survey in its seismic data library using the greater of the amortization that would result from the application of the income forecast method to each survey’s revenue, subject to a minimum amortization rate, or a straight-line basis over four years, commencing at the time such survey is completed and available for licensing to customers on a non-exclusive basis.

The Company applies the income forecast method by forecasting the ultimate revenue expected to be derived from a particular data library component over the estimated useful life of each survey comprising part of such component. This forecast is made by the Company annually and reviewed quarterly. If, during any such review, the Company determines that the ultimate revenue for a library component is expected to be significantly different than the most recent estimate of total revenue for such library component, the Company revises the amortization rate attributable to future revenue from each survey in such component. The Company applies a minimum amortization rate of 70%. In addition, in connection with the forecast reviews and updates, the Company evaluates the recoverability of its seismic data library investment, and if required, records an impairment charge with respect to such investment. See discussion on “Seismic Data Library Impairment” below.

The greater of the income forecast or straight-line amortization policy is applied quarterly on a cumulative basis at the individual survey level. Under this policy, the Company first records amortization using the income forecast method. The cumulative amortization recorded for each survey is then compared with the cumulative straight-line amortization. If the cumulative straight-line amortization is higher for any specific survey, additional amortization expense is recorded, resulting in accumulated amortization being equal to the cumulative straight-line amortization for such survey. This requirement is applied regardless of future-year revenue estimates for the library component of which the survey is a part and does not consider the existence of deferred revenue with respect to the library component or to any survey.

The actual aggregate rate of amortization depends on the specific seismic surveys licensed and selected by the Company’s customers during the period and the amount of straight-line amortization recorded. The income forecast amortization rates can vary by component and, as of July 1, 2017, is 70% for all components. For those seismic surveys which have been fully amortized, no amortization expense is required on revenue recorded.

Seismic Data Library Impairment

The Company evaluates its seismic data library investment by grouping individual surveys into components based on its operations and geological and geographical trends, resulting in the following data library segments for purposes of evaluating impairments: (I) North America 3D onshore comprised of the following components: (a) Texas Gulf Coast, (b) Eastern Texas, (c) Permian, (d) Anadarko Basin in North Texas/Oklahoma, (e) Southern Louisiana/Mississippi, (f) Northern Louisiana, (g) Rocky Mountains, (h) Utica/Marcellus in Pennsylvania, Ohio and West Virginia, (i) other United States, (j) Montney in British Columbia and Alberta, (k) Horn River in British Columbia, (l) Duvernay in Alberta and (m) other Canada; (II) United States 2D; (III) Canada 2D; (IV) Mexico; (V) Gulf of Mexico offshore; and (VI) international data outside North America. The Company believes that these library components constitute the lowest levels of independently identifiable cash flows.

The Company evaluates its seismic data library investment for impairment whenever events or changes in circumstances indicate that the carrying amounts may not be recoverable. The Company considers the level of sales performance in each component compared to projected sales, as well as industry conditions, among others, to be key factors in determining when its seismic data investment should be evaluated for impairment. In evaluating sales performance of each component, the Company generally considers five consecutive quarters of actual performance below forecasted sales to be an indicator of potential impairment.

The impairment evaluation is based first on a comparison of the undiscounted future cash flows over each component’s remaining estimated useful life with the carrying value of each library component. If the undiscounted cash flows are equal to or greater than the carrying value of such component, no impairment is recorded. If undiscounted cash flows are less than the carrying value of any component, the forecast of future cash flows related to such component is discounted to fair value and compared with such component’s carrying amount. The difference between the library component’s carrying amount and the discounted future value of the expected revenue stream is recorded as an impairment charge.

For purposes of evaluating potential impairment losses, the Company estimates the future cash flows attributable to a library component by evaluating, among other factors, historical and recent revenue trends, oil and gas prospectivity in particular regions, general economic conditions affecting its customer base and expected changes in technology and other factors that the Company deems relevant. The cash flow estimates exclude expected future revenues attributable to non-monetary data exchanges and future data creation projects.

The estimation of future cash flows and fair value is highly subjective and inherently imprecise. Estimates can change materially from period to period based on many factors, including those described in the preceding paragraph. Accordingly, if

Table of Contents

conditions change in the future, the Company may record impairment losses relative to its seismic data library investment, which could be material to any particular reporting period.

The Company did not have any impairment charges during the six months ended June 30, 2017 or 2016.

NOTE D-DEBT

The following is a summary of the Company’s debt (in thousands):



	June 30, 2017			December 31, 2016
9½% Senior Notes	$	250,000		$	250,000
Less: unamortized debt issuance costs	(2,516		)	(3,143		)
	$	247,484		$	246,857

9½% Senior Unsecured Notes: On March 20, 2013, the Company issued, in a private placement, $250.0 million aggregate principal amount of 9½% senior notes (the “9½% Senior Notes”). As required by their terms, the 9½% Senior Notes were exchanged for senior notes of like amounts and terms in a publicly registered exchange offer in August 2013. The 9½% Senior Notes mature on April 15, 2019. Interest is payable in cash, semi-annually on April 15 and October 15 of each year. The 9½% Senior Notes are unsecured and are jointly and severally guaranteed by substantially all of the Company’s significant 100% owned U.S. subsidiaries on a senior basis. The 9½% Senior Notes contain restrictive covenants which limit the Company’s ability to, among other things, incur additional indebtedness, incur liens, pay dividends and make other restricted payments, engage in transactions with affiliates, and complete mergers, acquisitions and sales of assets.

Upon a change of control (as defined in the indenture), each holder of the 9½% Senior Notes will have the right to require the Company to offer to purchase all of such holder's notes at a price equal to 101% of the principal amount, plus accrued and unpaid interest.

NOTE E-FAIR VALUE MEASUREMENTS

Authoritative guidance on fair value measurements provides a framework for measuring fair value and establishes a fair value hierarchy that prioritizes the inputs used to measure fair value, giving the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 inputs) and the lowest priority to unobservable inputs (Level 3 inputs).

The Company uses valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. In measuring the fair value of the Company’s assets and liabilities, market data or assumptions are used that the Company believes market participants would use in pricing an asset or liability, including assumptions about risk when appropriate. The Company’s assets that are measured at fair value on a recurring basis include the following (in thousands):



			Fair Value Measurements Using
	Total		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Unobservable Inputs (Level 3)
At June 30, 2017:
Cash equivalents	$	59,481	$	59,481	$	—	$	—
At December 31, 2016:
Cash equivalents	$	55,674	$	55,674	$	—	$	—

The Company had no transfers of assets between any of the above levels during the six months ended June 30, 2017 or 2016.

Cash equivalents include treasury bills and money market funds that invest in United States government obligations and a Canadian dollar investment account, all with original maturities of three months or less. The original costs of these assets approximate fair value due to their short-term maturities.

Table of Contents

Other Financial Instruments:

At June 30, 2017, the carrying value of the Company’s debt was $247.5 million, net of $2.5 million of unamortized debt issuance costs. At December 31, 2016, the carrying value was $246.9 million, net of $3.1 million of unamortized debt issuance costs. The estimated fair value of the debt was approximately $248.8 million at June 30, 2017 and $232.6 million at December 31, 2016. The fair value of the Company’s 9½% Senior Notes is based on quoted market prices (Level 1 inputs).

NOTE F-STATEMENT OF CASH FLOW INFORMATION

Cash and cash equivalents at June 30, 2017 and December 31, 2016 included $0.5 million of restricted cash related to collateral on seismic operations bonds. The balance at June 30, 2017 also included $0.9 million of restricted cash related to proceeds from broker sales held in escrow by the Company for specific use by an E&P client.

For purposes of the statement of cash flows, the Company considers all highly liquid investments or debt instruments with an original maturity of three months or less to be cash equivalents. The Company maintains its day-to-day operating cash and temporary excess cash with various banking institutions that, in turn, invest in time deposits and U.S. Treasury bills.

The Company had non-cash additions to its seismic data library comprised of the following (in thousands):



	Six Months Ended June 30,
	2017		2016
Non-monetary exchanges related to resale licensing	$	1,250	$	222
Non-monetary exchanges from underwriting of new data acquisition	—		408
Non-monetary exchanges related to data processing and reproduction services	—		392
	$	1,250	$	1,022

Non-cash revenue consisted of the following (in thousands):



	Six Months Ended June 30,
	2017		2016
Acquisition revenue on underwriting from non-monetary exchange contracts	$	126	$	24
Licensing revenue from specific data licenses and selections on non-monetary exchange contracts	1,250		1,340
Solutions and other revenue recognized from non-monetary exchange contracts	$	31	$	—
Total non-cash revenue	$	1,407	$	1,364

NOTE G-COMMITMENTS AND CONTINGENCIES

The Company is involved from time to time in ordinary, routine claims and lawsuits incidental to its business. In the opinion of management, uninsured losses, if any, resulting from the ultimate resolution of these matters should not be material to the Company’s financial position, results of operations or cash flows. However, it is not possible to predict or determine the outcomes of the legal actions brought against it or by it, or to provide an estimate of all additional losses, if any, that may arise. At June 30, 2017, the Company has recorded the estimated amount of potential exposure it may have with respect to claims. Such amounts are not material to the financial statements.

NOTE H-RECENT ACCOUNTING PRONOUNCEMENTS

In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2014-09, “Revenue from Contracts with Customers (Topic 606)”. The objective of the ASU is to establish a single comprehensive model of accounting for revenue arising from contracts with customers and will supersede most of the existing revenue recognition guidance, including industry-specific guidance. The core principle of the guidance is that an entity recognizes revenue to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. This ASU also significantly expands disclosure requirements concerning revenues for most entities. In August 2015, the FASB issued ASU No. 2015-14, “Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date” which deferred the effective date of ASU 2014-09 by one year. In March 2016, the FASB issued ASU No. 2016-08, “Revenue from Contracts with Customers (Topic 606): Principal versus Agent Considerations (Reporting Revenue Gross versus Net)”, amending the principal-versus-agent implementation guidance set forth in ASU 2014-09. Among other things, ASU 2016-08 clarifies that an entity should evaluate whether it is the principal or the agent for each specified good or service promised in a contract with a customer. In April 2016, the FASB issued ASU No. 2016-10,

Table of Contents

“Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing”, which amends certain aspects of the guidance related to identifying performance obligations and licensing implementation. In May 2016, the FASB issued ASU No. 2016-12, “Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients” to address certain issues in the guidance on assessing collectibility, presentation of sales taxes, noncash consideration, and completed contracts and contract modifications at transition. The Company is required to adopt the guidance set forth by these ASUs on January 1, 2018. Entities have the option of using either a full retrospective or modified retrospective approach to adopt the new guidance. The Company will utilize the modified retrospective approach when adopting the new revenue recognition guidance effective January 1, 2018 which will result in the application of the new guidance retrospectively with the cumulative effect of adoption recognized at January 1, 2018. The Company has reviewed its different types of customer contracts and has compared its current revenue recognition policies to the provisions of the new standard for each of its revenue categories, noting no significant differences. While the Company has not identified any material differences in the amount and timing of revenue recognition to date, the Company’s evaluation is not yet fully complete. The FASB has issued, and may issue in the future, interpretive guidance which may cause the Company’s evaluation to change. The Company continues to evaluate the impact the new standard will have on its consolidated financial statements, including expanded footnote disclosure requirements, and believes it is following an appropriate timeline to allow for proper recognition, presentation and disclosure upon adoption effective January 1, 2018.

In February 2016, the FASB issued ASU No. 2016-02, “Leases (Topic 842)” with the objective of increasing transparency and comparability among organizations by requiring lessees to recognize assets and liabilities on the balance sheet for the present value of the rights and obligations created by all leases with terms of more than 12 months. The ASU will also require disclosures designed to give financial statement users information on the amount, timing and uncertainty of cash flows arising from leases. The amendments in this ASU are to be applied using a modified retrospective approach and will be effective for the Company as of January 1, 2019, but early adoption is permitted. The Company is currently evaluating the impact of adopting this new standard on its consolidated financial statements as of January 1, 2019 and believes that the most significant change will be to the Company's balance sheet as its asset and liability balances will increase for operating leases that are currently off-balance sheet.

In January 2017, the FASB issued ASU No. 2017-04, “Intangibles - Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment” in order to simplify the measurement of goodwill impairment by eliminating Step 2 from the goodwill impairment test. Currently, Step 2 measures a goodwill impairment loss by comparing the implied fair value of a reporting unit’s goodwill with the carrying amount of that goodwill. In computing the implied fair value of goodwill under Step 2, an entity had to perform procedures to determine the fair value at the impairment testing date of its assets and liabilities following the same procedure that would be required for purchase price allocation in a business combination. Under the amendments in this ASU, a goodwill impairment loss will be measured using the difference between the carrying amount and the fair value of the reporting unit limited to the total carrying amount of that reporting unit’s goodwill. The guidance in this ASU also eliminates the requirements for any reporting unit with a zero or negative carrying amount to perform a qualitative assessment and, if it fails that qualitative test, to perform Step 2 of the goodwill impairment test. However, entities must disclose the amount of goodwill allocated to each reporting unit with a zero or negative carrying amount. The amendments in this ASU are to be applied on a prospective basis and will be effective for the Company as of January 1, 2020, but early adoption is permitted for any impairment tests performed after January 1, 2017. The Company is currently evaluating the impact of adopting this new standard but does not expect that it will have a material effect on its consolidated financial statements.

NOTE I-SUPPLEMENTAL GUARANTORS CONSOLIDATING CONDENSED FINANCIAL INFORMATION

On March 20, 2013, the Company completed a private placement of 9½% Senior Notes in the aggregate principal amount of $250.0 million. The Company’s payment obligations under the 9½% Senior Notes are jointly and severally guaranteed on a senior basis by substantially all of the Company’s significant 100% owned U.S. subsidiaries (“Guarantor Subsidiaries”). All subsidiaries of the Company that do not guarantee the 9½% Senior Notes are referred to as Non-Guarantor Subsidiaries.

The indenture governing the 9½% Senior Notes provides that the guarantees by the Guarantor Subsidiaries will be released in the following customary circumstances: (i) upon a sale or other disposition, whether by merger, consolidation or otherwise, of the equity interests of that guarantor to a person that is not the Company or a restricted subsidiary of the Company; (ii) the guarantor sells all or substantially all of its assets to a person that is not the Company or a restricted subsidiary of the Company; (iii) the guarantor is properly designated as an unrestricted subsidiary or ceases to be a restricted subsidiary; (iv) upon legal defeasance of the 9½% Senior Notes or satisfaction and discharge of the indenture governing the 9½% Senior Notes; (v) the guarantor becomes an immaterial subsidiary or (vi) the guarantor, having also been a guarantor under a credit facility, is released from its guarantee obligations under a credit facility and does not guarantee any indebtedness of the Company or the Guarantor Subsidiaries.

The consolidating condensed financial statements are presented below and should be read in connection with the condensed consolidated financial statements of the Company. Separate financial statements of the Guarantor Subsidiaries are not presented

Table of Contents

because (i) the Guarantor Subsidiaries are wholly-owned and have fully and unconditionally guaranteed the 9½% Senior Notes on a joint and several basis and (ii) the Company’s management has determined such separate financial statements are not material to investors.

The following consolidating condensed financial information presents the consolidating condensed balance sheets as of June 30, 2017 and December 31, 2016, the consolidating condensed statements of operations and statements of comprehensive income (loss) for the three and six months ended June 30, 2017 and June 30, 2016 and the consolidating condensed statements of cash flows for the six months ended June 30, 2017 and 2016 of (a) the Company; (b) the Guarantor Subsidiaries; (c) the Non-Guarantor Subsidiaries; (d) elimination entries; and (e) the Company, the Guarantor Subsidiaries and the Non-Guarantor Subsidiaries on a consolidated basis.

Investments in subsidiaries are accounted for under the equity method. The principal elimination entries eliminate investments in subsidiaries, intercompany balances, intercompany transactions and intercompany sales.

Table of Contents

CONSOLIDATING CONDENSED BALANCE SHEET

As of June 30, 2017

(In thousands)



	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Consolidating Eliminations			Consolidated Total
ASSETS
Cash and cash equivalents	$	—		$	43,601		$	17,242		$	—		$	60,843
Receivables
Trade, net	—			18,016			265			—			18,281
Notes and other	—			128			267			—			395
Due from Seitel Holdings, Inc.	—			1,185			—			—			1,185
Intercompany receivables (payables)	(63,688		)	61,392			2,296			—			—
Investment in subsidiaries	409,544			420,301			678			(830,523		)	—
Net seismic data library	—			72,201			19,085			—			91,286
Net property and equipment	—			522			1,100			—			1,622
Prepaid expenses, deferred charges and other	119			1,628			750			—			2,497
Intangible assets, net	900			—			—			—			900
Goodwill	—			107,688			76,680			—			184,368
Deferred income taxes	—			96			176			—			272
TOTAL ASSETS	$	346,875		$	726,758		$	118,539		$	(830,523	)	$	361,649
LIABILITIES AND STOCKHOLDER’S EQUITY
LIABILITIES
Accounts payable and accrued liabilities	$	5,008		$	8,258		$	2,889		$	—		$	16,155
Income taxes payable	—			25			507			—			532
Senior Notes	247,484			—			—			—			247,484
Obligations under capital leases	—			—			1,443			—			1,443
Deferred revenue	—			11,157			1,757			—			12,914
Deferred income taxes	—			—			1,680			—			1,680
TOTAL LIABILITIES	252,492			19,440			8,276			—			280,208
STOCKHOLDER’S EQUITY
Common stock	—			—			—			—			—
Additional paid-in capital	400,588			—			—			—			400,588
Parent investment	—			764,105			156,728			(920,833		)	—
Retained deficit	(306,205		)	(56,787		)	(33,171		)	89,958			(306,205		)
Accumulated other comprehensive loss	—			—			(13,294		)	352			(12,942		)
TOTAL STOCKHOLDER’S EQUITY	94,383			707,318			110,263			(830,523		)	81,441
TOTAL LIABILITIES AND STOCKHOLDER’S EQUITY	$	346,875		$	726,758		$	118,539		$	(830,523	)	$	361,649

Table of Contents

CONSOLIDATING CONDENSED BALANCE SHEET

As of December 31, 2016

(In thousands)



	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Consolidating Eliminations			Consolidated Total
ASSETS
Cash and cash equivalents	$	—		$	47,971		$	8,026		$	—		$	55,997
Receivables
Trade, net	—			14,819			9,662			—			24,481
Notes and other	—			412			24			—			436
Due from Seitel Holdings, Inc.	—			1,177			—			—			1,177
Intercompany receivables (payables)	(51,982		)	51,262			720			—			—
Investment in subsidiaries	420,308			420,456			630			(841,394		)	—
Net seismic data library	—			94,039			21,907			(24		)	115,922
Net property and equipment	—			611			1,098			—			1,709
Prepaid expenses, deferred charges and other	30			1,413			319			—			1,762
Intangible assets, net	900			402			116			—			1,418
Goodwill	—			107,688			74,324			—			182,012
Deferred income taxes	—			92			165			—			257
TOTAL ASSETS	$	369,256		$	740,342		$	116,991		$	(841,418	)	$	385,171
LIABILITIES AND STOCKHOLDER’S EQUITY
LIABILITIES
Accounts payable and accrued liabilities	$	5,007		$	8,559		$	3,441		$	—		$	17,007
Income taxes payable	—			24			596			—			620
Senior Notes	246,857			—			—			—			246,857
Obligations under capital leases	—			—			1,510			—			1,510
Deferred revenue	—			13,574			2,330			—			15,904
Deferred income taxes	—			—			2,214			—			2,214
TOTAL LIABILITIES	251,864			22,157			10,091			—			284,112
STOCKHOLDER’S EQUITY
Common stock	—			—			—			—			—
Additional paid-in capital	400,582			—			—			—			400,582
Parent investment	—			764,105			156,594			(920,699		)	—
Retained deficit	(283,190		)	(45,920		)	(33,120		)	79,040			(283,190		)
Accumulated other comprehensive loss	—			—			(16,574		)	241			(16,333		)
TOTAL STOCKHOLDER’S EQUITY	117,392			718,185			106,900			(841,418		)	101,059
TOTAL LIABILITIES AND STOCKHOLDER’S EQUITY	$	369,256		$	740,342		$	116,991		$	(841,418	)	$	385,171

Table of Contents

CONSOLIDATING CONDENSED STATEMENT OF OPERATIONS

For the Three Months Ended June 30, 2017

(In thousands)



	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Consolidating Eliminations			Consolidated Total
REVENUE	$	—		$	19,291		$	5,010		$	(601	)	$	23,700
EXPENSES:
Depreciation and amortization	—			18,366			3,615			(12		)	21,969
Cost of sales	—			317			(8		)	(276		)	33
Selling, general and administrative	137			4,010			1,183			(325		)	5,005
	137			22,693			4,790			(613		)	27,007
INCOME (LOSS) FROM OPERATIONS	(137		)	(3,402		)	220			12			(3,307		)
Interest expense, net	(6,039		)	(145		)	(3		)	—			(6,187		)
Foreign currency exchange gains (losses)	—			2			(36		)	—			(34		)
Other income	—			—			96			—			96
Income (loss) before income taxes and equity in income (loss) of subsidiaries	(6,176		)	(3,545		)	277			12			(9,432		)
Provision for income taxes	—			1			203			—			204
Equity in income (loss) of subsidiaries	(3,460		)	74			—			3,386			—
NET INCOME (LOSS)	$	(9,636	)	$	(3,472	)	$	74		$	3,398		$	(9,636	)

Table of Contents

CONSOLIDATING CONDENSED STATEMENT OF COMPREHENSIVE INCOME (LOSS)

For the Three Months Ended June 30, 2017

(In thousands)



	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries		Consolidating Eliminations		Consolidated Total
Net income (loss)	$	(9,636	)	$	(3,472	)	$	74	$	3,398	$	(9,636	)
Foreign currency translation adjustments	—			—			2,569		—		2,569
Comprehensive income (loss)	$	(9,636	)	$	(3,472	)	$	2,643	$	3,398	$	(7,067	)

Table of Contents

CONSOLIDATING CONDENSED STATEMENT OF OPERATIONS

For the Three Months Ended June 30, 2016

(In thousands)



	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Consolidating Eliminations			Consolidated Total
REVENUE	$	—		$	18,806		$	5,903		$	(369	)	$	24,340
EXPENSES:
Depreciation and amortization	—			20,256			4,561			(12		)	24,805
Cost of sales	—			62			5			(56		)	11
Selling, general and administrative	360			3,370			1,266			(328		)	4,668
	360			23,688			5,832			(396		)	29,484
INCOME (LOSS) FROM OPERATIONS	(360		)	(4,882		)	71			27			(5,144		)
Interest expense, net	(5,646		)	(599		)	(89		)	—			(6,334		)
Foreign currency exchange losses	—			—			(10		)	—			(10		)
Other income	—			3			1			—			4
Loss before income taxes and equity in income (loss) of subsidiaries	(6,006		)	(5,478		)	(27		)	27			(11,484		)
Provision (benefit) for income taxes	—			16			(2,265		)	—			(2,249		)
Equity in income (loss) of subsidiaries	(3,229		)	2,238			—			991			—
NET INCOME (LOSS)	$	(9,235	)	$	(3,256	)	$	2,238		$	1,018		$	(9,235	)

Table of Contents

CONSOLIDATING CONDENSED STATEMENT OF COMPREHENSIVE INCOME (LOSS)

For the Three Months Ended June 30, 2016

(In thousands)



	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Consolidating Eliminations		Consolidated Total
Net income (loss)	$	(9,235	)	$	(3,256	)	$	2,238		$	1,018	$	(9,235	)
Foreign currency translation adjustments	—			—			(308		)	—		(308		)
Comprehensive income (loss)	$	(9,235	)	$	(3,256	)	$	1,930		$	1,018	$	(9,543	)

Table of Contents

CONSOLIDATING CONDENSED STATEMENT OF OPERATIONS

For the Six Months Ended June 30, 2017

(In thousands)



	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Consolidating Eliminations			Consolidated Total
REVENUE	$	—		$	33,093		$	12,144		$	(942	)	$	44,295
EXPENSES:
Depreciation and amortization	—			34,482			9,775			(25		)	44,232
Cost of sales	—			327			6			(290		)	43
Selling, general and administrative	260			8,637			2,406			(652		)	10,651
	260			43,446			12,187			(967		)	54,926
LOSS FROM OPERATIONS	(260		)	(10,353		)	(43		)	25			(10,631		)
Interest expense, net	(11,913		)	(466		)	(18		)	—			(12,397		)
Foreign currency exchange gains (losses)	—			2			(87		)	—			(85		)
Other income	—			—			96			—			96
Loss before income taxes and equity in loss of subsidiaries	(12,173		)	(10,817		)	(52		)	25			(23,017		)
Benefit for income taxes	—			(1		)	(1		)	—			(2		)
Equity in loss of subsidiaries	(10,842		)	(51		)	—			10,893			—
NET LOSS	$	(23,015	)	$	(10,867	)	$	(51	)	$	10,918		$	(23,015	)

Table of Contents

CONSOLIDATING CONDENSED STATEMENT OF COMPREHENSIVE INCOME (LOSS)

For the Six Months Ended June 30, 2017

(In thousands)



	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Consolidating Eliminations		Consolidated Total
Net loss	$	(23,015	)	$	(10,867	)	$	(51	)	$	10,918	$	(23,015	)
Foreign currency translation adjustments	—			—			3,280			111		3,391
Comprehensive income (loss)	$	(23,015	)	$	(10,867	)	$	3,229		$	11,029	$	(19,624	)

Table of Contents

CONSOLIDATING CONDENSED STATEMENT OF OPERATIONS

For the Six Months Ended June 30, 2016

(In thousands)



	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Consolidating Eliminations			Consolidated Total
REVENUE	$	—		$	29,280		$	7,722		$	(712	)	$	36,290
EXPENSES:
Depreciation and amortization	—			29,166			10,765			(25		)	39,906
Cost of sales	—			77			12			(56		)	33
Selling, general and administrative	573			7,457			3,253			(656		)	10,627
	573			36,700			14,030			(737		)	50,566
LOSS FROM OPERATIONS	(573		)	(7,420		)	(6,308		)	25			(14,276		)
Interest expense, net	(11,302		)	(1,206		)	(182		)	—			(12,690		)
Foreign currency exchange gains	—			—			163			—			163
Other income	—			9			1			—			10
Loss before income taxes and equity in loss of subsidiaries	(11,875		)	(8,617		)	(6,326		)	25			(26,793		)
Benefit for income taxes	—			(11		)	(3,683		)	—			(3,694		)
Equity in loss of subsidiaries	(11,224		)	(2,643		)	—			13,867			—
NET LOSS	$	(23,099	)	$	(11,249	)	$	(2,643	)	$	13,892		$	(23,099	)

Table of Contents

CONSOLIDATING CONDENSED STATEMENT OF COMPREHENSIVE INCOME (LOSS)

For the Six Months Ended June 30, 2016

(In thousands)



	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Consolidating Eliminations		Consolidated Total
Net loss	$	(23,099	)	$	(11,249	)	$	(2,643	)	$	13,892	$	(23,099	)
Foreign currency translation adjustments	—			—			6,353			83		6,436
Comprehensive income (loss)	$	(23,099	)	$	(11,249	)	$	3,710		$	13,975	$	(16,663	)

Table of Contents

CONSOLIDATING CONDENSED STATEMENT OF CASH FLOWS

For the Six Months Ended June 30, 2017

(In thousands)



	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Consolidating Eliminations		Consolidated Total
Cash flows from operating activities:
Net cash provided by (used in) operating activities	$	(12,220	)	$	17,498		$	15,576		$	—	$	20,854
Cash flows from investing activities:
Cash invested in seismic data	—			(9,491		)	(6,610		)	—		(16,101		)
Cash paid to acquire property and equipment	—			(149		)	(101		)	—		(250		)
Cash from sale of property and equipment	—			—			3			—		3
Advances to Seitel Holdings, Inc.	—			(8		)	—			—		(8		)
Net cash used in investing activities	—			(9,648		)	(6,708		)	—		(16,356		)
Cash flows from financing activities:
Principal payments on capital lease obligations	—			—			(112		)	—		(112		)
Intercompany transfers	12,220			(12,220		)	—			—		—
Net cash provided by (used in) financing activities	12,220			(12,220		)	(112		)	—		(112		)
Effect of exchange rate changes	—			—			460			—		460
Net increase (decrease) in cash and cash equivalents	—			(4,370		)	9,216			—		4,846
Cash and cash equivalents at beginning of period	—			47,971			8,026			—		55,997
Cash and cash equivalents at end of period	$	—		$	43,601		$	17,242		$	—	$	60,843

Table of Contents

CONSOLIDATING CONDENSED STATEMENT OF CASH FLOWS

For the Six Months Ended June 30, 2016

(In thousands)



	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Consolidating Eliminations		Consolidated Total
Cash flows from operating activities:
Net cash provided by (used in) operating activities	$	(12,262	)	$	15,018		$	1,998		$	—	$	4,754
Cash flows from investing activities:
Cash invested in seismic data	—			(11,947		)	(922		)	—		(12,869		)
Cash paid to acquire property and equipment	—			(145		)	—			—		(145		)
Cash from sale of property and equipment	—			17			1			—		18
Advances to Seitel Holdings, Inc.	—			(16		)	—			—		(16		)
Net cash used in investing activities	—			(12,091		)	(921		)	—		(13,012		)
Cash flows from financing activities:
Principal payments on capital lease obligations	—			—			(100		)	—		(100		)
Intercompany transfers	12,262			(12,063		)	(199		)	—		—
Net cash provided by (used in) financing activities	12,262			(12,063		)	(299		)	—		(100		)
Effect of exchange rate changes	—			—			156			—		156
Net increase (decrease) in cash and cash equivalents	—			(9,136		)	934			—		(8,202		)
Cash and cash equivalents at beginning of period	—			51,192			1,483			—		52,675
Cash and cash equivalents at end of period	$	—		$	42,056		$	2,417		$	—	$	44,473

Table of Contents


Item 2.	MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following discussion should be read in conjunction with our condensed consolidated financial statements and the related notes to the condensed consolidated financial statements included elsewhere in this document. When we use the terms “we”, “us”, “our” or similar words in this disclosure, we are referring to Seitel, Inc. and its subsidiaries, unless the context otherwise requires.

CAUTIONARY STATEMENT CONCERNING FORWARD-LOOKING INFORMATION

This Quarterly Report on Form 10-Q (this “Quarterly Report”) contains forward-looking statements within the meaning of 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”). Statements contained in this report about our future outlook, prospects, strategies and plans, and about industry conditions, demand for seismic services and the future economic life of our seismic data are forward-looking, among others. All statements that express belief, expectation, estimates or intentions, as well as those that are not statements of historical fact, are forward-looking. The words “believe”, “expect”, “anticipate”, “estimate”, “project”, “propose”, “plan”, “target”, “foresee”, “should”, “intend”, “may”, “will”, “would”, “could”, “potential” and similar expressions are intended to identify forward-looking statements. Forward-looking statements are not guarantees of future performance, but represent our present belief, based on our current expectations and assumptions, with respect to future events and their potential effect on us. While we believe our expectations and assumptions are reasonable, they involve risks and uncertainties beyond our control that could cause the actual results or outcome to differ materially from the expected results or outcome reflected in our forward-looking statements. Such risks and uncertainties include, without limitation, actual customer demand for our seismic data and related services, the timing and extent of changes in commodity prices for natural gas, crude oil and condensate and natural gas liquids, conditions in the capital markets during the periods covered by the forward-looking statements, the effect of economic conditions, our ability to obtain financing on satisfactory terms if internally generated cash flows are insufficient to fund our capital needs, the impact on our financial condition as a result of our debt and our debt service, our ability to obtain and maintain normal terms with our vendors and service providers, our ability to maintain contracts that are critical to our operations, changes in the oil and gas industry or the economy generally and changes in the capital expenditure budgets of our customers, as well as the risk factors identified in our Annual Report on Form 10-K for the fiscal year ended December 31, 2016 filed with the Securities and Exchange Commission (“SEC”).

The forward-looking statements contained in this report speak only as of the date hereof and readers are cautioned not to place undue reliance or project future results based on such forward-looking statements or present or prior earnings levels. Except as required by applicable law, we disclaim any duty to update or revise any forward-looking statements, whether as a result of new information, future events or any other reason. All forward-looking statements attributable to the Company or any person acting on its behalf are expressly qualified in their entirety by the cautionary statements contained or referred to herein, in our Annual Report on Form 10-K for the fiscal year ended December 31, 2016 filed with the SEC and in our future periodic reports filed with the SEC.

Overview

General

We are a leading provider of onshore seismic data to the oil and gas industry in North America. We own an extensive library of onshore and offshore seismic data that we have accumulated since our inception in 1982 that we offer for license to exploration and production (“E&P”) companies. Our primary areas of focus are onshore United States and Canada and, to a lesser extent, offshore U.S. Gulf of Mexico. In addition, we began to expand our data library coverage into Mexico in 2015 as a result of the energy reform in Mexico. We believe our data library is one of the largest onshore three-dimensional (“3D”) databases available for licensing in North America and includes leading positions in oil, liquids-rich and natural gas unconventional plays as well as conventional areas.

Our products and services are used by E&P companies in oil and gas exploration and development efforts to increase the probability of drilling success, to better delineate existing oil and gas fields and to augment their reservoir completion and management techniques. In unconventional plays, E&P companies use seismic data as a development tool to better identify efficient drilling plans and maximize production by identifying and understanding a series of critical characteristics of the targeted resource. We generate revenue primarily by licensing data from our data library and from new data creation projects, which are substantially underwritten or paid for by our clients. By participating in underwritten, non-exclusive surveys or purchasing licenses to existing data, E&P companies can obtain access to surveys at reduced costs as compared to acquiring seismic data on a proprietary basis.

Table of Contents

Crude oil prices reached their lowest levels year-to-date in late June as inventory levels continued to cause downward pressure. Although there has been some recovery in crude oil prices since then, uncertainty in the crude oil price outlook remains. As a result, we believe that seismic spending will continue to fluctuate quarter to quarter as E&P companies continue to closely evaluate spending levels. We believe our asset-light business model, variable cost structure and streamlined support structure allow us to respond to changes, both positive and negative, in the industry environment.

Principal Factors Affecting Our Business

Our business is dependent upon a variety of factors, many of which are beyond our control. The following are those that we consider to be principal factors affecting our business.

Demand for Seismic Data: Demand for our products and services is cyclical due to the nature of the oil and gas industry. In particular, demand for our seismic data services depends upon exploration, production, development and field management spending by E&P companies and, in the case of new data creation, the willingness of these companies to forgo ownership in the seismic data. Capital expenditures by E&P companies depend upon several factors, including actual and forecasted oil and natural gas commodity prices, prospect availability and the companies’ own short-term and long-term strategic plans. These capital expenditures may also be affected by worldwide economic or industry-wide conditions.

Merger and Acquisition/Joint Venture Activity: Merger and acquisition activity continues to occur within our client base. This activity could have a negative impact on seismic companies that operate in markets with a limited number of participating clients. However, we believe that, over time, this activity could have a positive impact on our business, as it should generate resale licensing revenue, result in increased vitality in the trading of mineral interests and result in the creation of new independent customers through the rationalization of staff within those companies affected by this activity.

Exploiting unconventional plays is a capital intensive endeavor and many technically proficient E&P companies remain subject to capital constraints. These companies find themselves needing to sell their positions to, or create partnerships with, large well-capitalized companies in order to develop their recoverable resource base. Generally, contracts with our customers for the license of data do not permit sharing of the data among partners. As a result, these joint venture partners or new owners will often need to purchase a license to our seismic data for their own use.

North America Drilling Activity: The North American land rig count continues to improve in 2017. Since the low of 422 rigs in May 2016, the North American land rig count has increased 168% to 1,133 rigs as of July 21, 2017. The rig count is forecast to continue to rise throughout 2017 with continued strong directional drilling activity.

Availability of Capital for Our Customers: The continued low oil and gas prices have caused a reduction in cash flows for our customers. Many E&P companies rely on revolving credit to finance their day-to-day operations. These credit facilities have borrowing bases that are tied to the net present value of their reserves. Lower oil prices have decreased the value of those reserves and, as a result, the borrowing bases under such facilities have been reduced. Reductions in cash flows resulting from lower commodity prices, along with the reduced availability of credit and increased costs of borrowing, has had, and could continue to have, a material impact on the ability of such companies to obtain funding necessary to purchase our seismic data.

Government Regulation: Our operations and the operations of our third party contractors are subject to a variety of federal, provincial, state, foreign and local laws and regulations, including environmental and health and safety laws. We invest financial and managerial resources to comply with these laws and related permit requirements and require our third party contractors to do the same. Modification of existing laws or regulations and the adoption of new laws or regulations impacting exploration or production activities by oil and gas companies may have a material effect on our business operations.

Key Performance Measures

Management considers, among others, the following performance and financial measures in evaluating and managing our operating performance and financial condition. Some of these measures are not calculated in accordance with United States generally accepted accounting principles, or GAAP. Generally, a non-GAAP measure is a numerical measure of a company’s performance, financial position or cash flows that either excludes or includes amounts that are not normally excluded or included in the most directly comparable measure calculated and presented in accordance with GAAP. These non-GAAP measures are intended to supplement the presentation of our financial results that are prepared in accordance with GAAP and should not be considered substitutes for GAAP financial measures.

Cash Resales: Cash resales represent new contracts for data licenses from our library, including data currently in progress, payable in cash. We believe cash resales are an important measure of our operating performance and are useful in assessing overall industry and client activity. Cash resales are likely to fluctuate quarter to quarter as they do not require the longer planning and lead times necessary for new data creation.

Table of Contents

Cash resales for the three and six months ended June 30, 2017 and 2016 were as follows (in thousands):



	Three Months Ended June 30,				Six Months Ended June 30,
	2017		2016		2017		2016
Cash resales	$	12,904	$	19,135	$	26,925	$	21,833

Cash EBITDA: Cash EBITDA represents cash generated from licensing data from our seismic library net of recurring cash operating expenses. We believe this measure is helpful in determining the level of cash from operations we have available for debt service and funding of capital expenditures (net of the portion funded or underwritten by our customers). Cash EBITDA includes cash resales plus all other cash revenues other than from data acquisitions, less cost of goods sold and cash selling, general and administrative expenses (excluding severance and other non-routine costs).

The following is a quantitative reconciliation of this non-GAAP financial measure to the most directly comparable GAAP financial measure, cash flows from operating activities (in thousands):



	Three Months Ended June 30,						Six Months Ended June 30,
	2017			2016			2017			2016
Cash EBITDA	$	8,409		$	15,030		$	17,259		$	13,259
Add (subtract) other components not included in cash EBITDA:
Cash acquisition underwriting revenue	4,272			4,886			11,146			9,837
Revenue recognition adjustments from contracts payable in cash	4,974			(1,404		)	3,898			2,352
Severance and other non-routine costs	(103		)	(160		)	(103		)	(1,106		)
Interest expense, net	(6,187		)	(6,334		)	(12,397		)	(12,690		)
Amortization of deferred financing costs	317			310			627			628
Decrease in allowance for doubtful accounts	—			(21		)	—			(21		)
Other cash operating income	—			3			—			3
Current income tax expense	(177		)	(9		)	(583		)	(9		)
Changes in operating working capital	(4,785		)	(18,236		)	1,007			(7,499		)
Net cash provided by operating activities	$	6,720		$	(5,935	)	$	20,854		$	4,754

Growth of Our Seismic Data Library: We regularly add to our seismic data library through four different methods: (1) recording new data; (2) buying ownership of existing data for cash; (3) obtaining ownership of existing data sets through non-monetary exchanges; and (4) creating new value-added products from existing data within our library. For the period from January 1, 2017 to August 7, 2017, we completed the addition of approximately 1,450 square miles of seismic data to our library. As of August 7, 2017, we had approximately 250 square miles of seismic data in progress.

Critical Accounting Policies

We operate in one business segment, which consists of seismic data acquisition, seismic data licensing, seismic data processing and seismic reproduction services. There have not been any changes in our critical accounting policies since December 31, 2016.

Table of Contents

Results of Operations

Revenue

The following table summarizes the components of our revenue for the three and six months ended June 30, 2017 and 2016 (in thousands):



	Three Months Ended June 30,					Six Months Ended June 30,
	2017		2016			2017		2016
Acquisition underwriting revenue:
Cash underwriting	$	4,272	$	4,886		$	11,146	$	9,837
Underwriting from non-monetary exchanges	87		23			126		24
Total acquisition underwriting revenue	4,359		4,909			11,272		9,861
Resale licensing revenue:
Cash resales	12,904		19,135			26,925		21,833
Non-monetary exchanges	1,000		—			1,250		222
Revenue recognition adjustments	4,974		(64		)	3,898		3,470
Total resale licensing revenue	18,878		19,071			32,073		25,525
Total seismic revenue	23,237		23,980			43,345		35,386
Solutions and other	463		360			950		904
Total revenue	$	23,700	$	24,340		$	44,295	$	36,290

Total revenue was $23.7 million in the second quarter of 2017 compared to $24.3 million in the second quarter of 2016. Acquisition underwriting revenue was $4.4 million in the second quarter of 2017 compared to $4.9 million in the second quarter of 2016. New data acquisition activity in the second quarter of 2017 was primarily focused in the Louisiana Cotton Valley and Eagle Ford/Woodbine areas. Total resale licensing revenue was $18.9 million in the second quarter of 2017 compared to $19.1 million in the second quarter of 2016. Cash resales were $12.9 million in the second quarter of 2017 compared to $19.1 million in the second quarter of 2016. Although crude oil prices have recovered from the lows experienced in the first quarter of 2016, oil prices showed weakness during the second quarter of 2017. As a result, E&P companies were cautious in their capital spending which, in turn, impacted our cash resale activity in the second quarter of 2017. Non-monetary exchanges fluctuate quarter to quarter depending upon the data available for trade. Revenue recognition adjustments are non-cash adjustments to revenue and reflect the net amount of (i) revenue deferred as a result of all of the revenue recognition criteria not being met and (ii) the subsequent revenue recognition once the criteria are met. The $5.0 million increase in revenue recognition adjustments between the second quarters of 2016 and 2017 primarily resulted from a decrease in deferrals associated with new licensing contracts, partially offset by a decrease in revenue recognized on previously deferred licensing contracts.

Total revenue for the first six months of 2017 was $44.3 million compared to $36.3 million in the first six months of 2016. Acquisition underwriting revenue was $11.3 million for the first six months of 2017 compared to $9.9 million in the first six months of 2016. The increase was primarily due to an increase in new data acquisition activity in Canada following reduced activity in 2016. New data acquisition activity in the first six months of 2017 was focused in the Eagle Ford/Woodbine and Louisiana Cotton Valley areas in the U.S. and in the Montney area in Canada. Total resale licensing revenue was $32.1 million in the first six months of 2017 compared to $25.5 million in the first six months of 2016. Cash resales for the first six months of 2017 were $26.9 million compared to $21.8 million in the first six months of 2016 reflecting some increase in capital spending by our E&P clients as a result of the improved, but still volatile, commodity price environment. Revenue recognition adjustments increased $0.4 million from the first six months of 2016 to the first six months of 2017 primarily due to a decrease in the deferral of new licensing contracts, partially offset by a decrease in revenue recognized on previously deferred direct licensing contracts and a decrease in selections of data from library card contracts.

At June 30, 2017, we had a deferred revenue balance of $12.9 million, compared to the December 31, 2016 balance of $15.9 million. The deferred revenue balance was related to (i) deferred revenue on data acquisition projects, (ii) data licensing contracts on which selection of specific data had not yet occurred, (iii) contracts in which the data products are not yet available and (iv) data licensing contracts on which the revenue recognition criteria has not yet been met. The deferred revenue will be recognized as work progresses on the data acquisition contracts, when selection of specific data is made by the customer, upon expiration of the data selection period specified in the data licensing contracts, as the data products become available or as all of the revenue recognition criteria are met.

Table of Contents

Depreciation and Amortization

The table below sets forth the components of depreciation and amortization and presents seismic data amortization as a percentage of total seismic revenue for the three and six months ended June 30, 2017 and 2016 (dollars in thousands):



	Three Months Ended June 30,								Six Months Ended June 30,
	2017				2016				2017				2016
Amortization of seismic data:
Income forecast	$	9,645	41.5	%	$	12,010	50.1	%	$	20,481	47.3	%	$	16,059	45.4	%
Straight-line	12,201		52.5	%	11,564		48.2	%	22,971		53.0	%	21,399		60.5	%
Total amortization of seismic data	21,846		94.0	%	23,574		98.3	%	43,452		100.3	%	37,458		105.9	%
Depreciation of property and equipment	123				186				260				369
Amortization of acquired intangibles	—				1,045				520				2,079
Total	$	21,969			$	24,805			$	44,232			$	39,906

Total seismic data library amortization amounted to $21.8 million in the second quarter of 2017 compared to $23.6 million in the second quarter of 2016 and $43.5 million for the first half of 2017 compared to $37.5 million for the first half of 2016. The amount of seismic data library amortization fluctuates based on the level and location of specific seismic surveys licensed (including licensing resulting from new data acquisition) and selected by our customers during the period as well as the amount of straight-line amortization required under our accounting policy. Income forecast amortization as a percentage of total seismic revenue fluctuated from 2016 to 2017 primarily due to the mix of data being licensed. In all periods, we had resale revenue recognized from data whose costs were fully amortized. In the three and six months ended June 30, 2017, the percentage of resale revenue recognized from data whose costs were fully amortized was 50% and 44%, respectively, as compared to 36% and 49% in the three and six months ended June 30, 2016. Straight-line amortization represents the expense required under our accounting policy to ensure the book value of our data is fully amortized within four years of when the data becomes available for licensing. The amount of straight-line amortization varies between periods due to the distribution of revenue among the various seismic surveys.

Selling, General and Administrative Expenses

Selling, general and administrative (“SG&A”) expenses were $5.0 million in the second quarter of 2017 compared to $4.7 million in the second quarter of 2016 and $10.7 million in the first six months of 2017 compared to $10.6 million in the first six months of 2016. SG&A expenses are made up of the following cash and non-cash expenses (in thousands):



	Three Months Ended June 30,				Six Months Ended June 30,
	2017		2016		2017		2016
Cash SG&A expenses	$	4,997	$	4,614	$	10,645	$	10,551
Non-cash compensation expense	8		54		6		76
Total	$	5,005	$	4,668	$	10,651	$	10,627

The increase in cash SG&A expenses of $0.4 million from the second quarter of 2016 to the second quarter of 2017 was primarily due to an increase in variable compensation related to our annual incentive compensation plan resulting from overall improving Cash EBITDA in 2017. In the second quarter of 2016, no expense was recorded for the annual incentive compensation plan due to the uncertainty of achieving the goals set for 2016 as a result of the industry environment.

The change in cash SG&A expenses from the first six months of 2016 to the first six months of 2017 was minimal; however, the overall change was a combination of an increase in routine overhead costs of approximately $1.1 million offset by a decrease in non-routine costs of $1.0 million. The increase in routine overhead costs was mainly the result of an increase in annual incentive compensation. The decrease in non-routine costs was primarily due to termination benefits related to layoffs of personnel that were included in the 2016 period.

Income Taxes

Income tax expense (benefit) was $0.2 million in the second quarter of 2017 compared to $(2.2) million in the second quarter of 2016. The income tax expense in the second quarter of 2017 primarily related to our Canadian operations. The U.S. federal tax benefit of $3.4 million resulting from our second quarter 2017 U.S. operations was offset by a valuation allowance because it was more likely than not that the deferred tax asset would not be realized. The income tax benefit in the second quarter of 2016 was comprised of (i) a $2.1 million benefit on uncertain tax positions resulting from settlement of our outstanding appeal

Table of Contents

with Canada Revenue Agency in the second quarter of 2016 and remeasurement of our remaining uncertain tax positions due to the settlement and (ii) a benefit of $0.2 million related to our Canadian operations. The federal tax benefit of $4.0 million resulting from our second quarter 2016 U.S. operations was offset by a valuation allowance because it was more likely than not that the deferred tax asset would not be realized.

Income tax benefit was $2,000 for the six months ended June 30, 2017 and $3.7 million for the six months ended June 30, 2016. During the first six months of 2017, the federal tax benefit of $7.9 million resulting from our U.S. operations was offset by a valuation allowance because it was more likely than not that the deferred tax asset would not be realized. The benefit for the first six months of 2016 was comprised of (i) a $1.7 million benefit related to our Canadian operations and (ii) a $2.0 million benefit which primarily related to uncertain tax position settlements and remeasurements recorded in the second quarter of 2016. The federal tax benefit of $7.1 million resulting from our U.S. operations was offset by a valuation allowance because it was more likely than not that the deferred tax asset would not be realized.

Net Loss

Net loss was $9.6 million in the second quarter of 2017 compared to $9.2 million in the second quarter of 2016. The increase in the loss between quarters was primarily due to an increase in income tax expense along with slightly lower total revenues and a small increase in SG&A expenses, partially offset by a decrease in amortization expense associated with our seismic data library. Net loss was $23.0 million in the first six months of 2017 compared to $23.1 million in the first six months of 2016. The slight decrease in loss between the six month periods was primarily due to higher revenues, partially offset by higher amortization of our seismic data library and a reduction in income tax benefit.

Liquidity and Capital Resources

As of June 30, 2017, we had $60.8 million in consolidated cash, cash equivalents and short-term investments, including $1.4 million of restricted cash. Our Canadian subsidiary regularly holds cash which is used to reinvest in its operations. If we decide at a later date to repatriate those funds to the U.S., we may be required to pay taxes on certain of those funds based on applicable U.S. tax rates net of foreign taxes. Cash held by our Canadian subsidiary fluctuates throughout the year and at June 30, 2017, was $17.2 million.

Our primary sources of liquidity are cash on hand and cash generated from operations.

9½% Senior Unsecured Notes: On March 20, 2013, we issued in a private placement $250.0 million aggregate principal amount of our 9½% Senior Notes. Interest is payable in cash, semi-annually on April 15 and October 15 of each year. The notes mature on April 15, 2019. To the best of our knowledge, we were in compliance with all covenants contained in the indenture governing our 9½% Senior Notes at June 30, 2017.

We may from time to time, as part of various financing and investment strategies, purchase our outstanding indebtedness. These purchases, if any, could have a material positive or negative impact on our liquidity available to repay outstanding debt obligations or on our consolidated results of operations.

Cash Flows from Operating Activities: Cash flows provided by operating activities were $20.9 million and $4.8 million for the six months ended June 30, 2017 and 2016, respectively. Operating cash flows for 2017 increased from 2016 primarily due to higher collections of cash resales in 2017 due to increased activity beginning in the fourth quarter of 2016, partially offset by payments of 2016 annual incentive compensation made in 2017 and slightly lower collections of acquisition underwriting revenue as a result of invoice timing.

Cash Flows from Investing Activities: Cash flows used in investing activities were $16.4 million and $13.0 million for the six months ended June 30, 2017 and 2016, respectively. Cash expenditures for seismic data were $16.1 million and $12.9 million for the six months ended June 30, 2017 and 2016, respectively. The increase in cash invested in seismic data for 2017 compared to 2016 was primarily due to an increase in new data acquisition activity in Canada following reduced activity in 2016.

Cash Flows from Financing Activities: Cash flows used in financing activities were $0.1 million for each of the six months ended June 30, 2017 and 2016.

Anticipated Liquidity: Our ability to cover our operating and capital expenses, make required debt service payments on our 9½% Senior Notes, incur additional indebtedness and comply with our various debt covenants will depend primarily on our ability to generate sufficient operating cash flows. Over the next 12 months, we expect to obtain the funds necessary to pay our operating, capital and other expenses, as well as interest on our 9½% Senior Notes and principal and interest on our other indebtedness, from our operating cash flows and cash and cash equivalents on hand. Our ability to satisfy our payment obligations depends substantially on our future operating and financial performance, which necessarily will be affected by, and subject to, industry, market, economic and other factors. To the extent our operating cash flows and cash on hand are not

Table of Contents

sufficient to cover our anticipated expenditures, we could seek to obtain additional financing. However, there can be no assurance that we would be able to obtain any such financing on satisfactory terms or at all. If necessary, we could choose to further reduce our spending on capital projects and operating expenses to ensure we operate within the cash flow generated from our operations. We will not be able to predict or control many of these factors, such as economic conditions in the markets where we operate and competitive pressures.

Deferred Taxes

As of June 30, 2017, we had a net deferred tax liability of $1.7 million attributable to our Canadian operations. In the United States, we had a federal deferred tax asset of $102.1 million, which was fully offset by a valuation allowance. The recognition of the U.S. federal deferred tax asset will not occur until such time that it is more likely than not that some portion or all of the federal deferred tax asset will be realized. As of June 30, 2017, it was more likely than not that all of the U.S. federal deferred tax asset will not be realized. Additionally, in the U.S., we had a state deferred tax asset of $1.3 million of which $1.2 million was offset by a valuation allowance. The remaining state deferred tax asset was recognized as it is more likely than not that the state deferred tax asset will be realized. In addition, we had a deferred tax asset of $0.2 million related to our operations in Mexico that was recognized as of June 30, 2017 as it is more likely than not that the Mexico deferred tax asset will be realized.

Off-Balance Sheet Transactions

Other than operating leases, we do not maintain any off-balance sheet transactions, arrangements, obligations or other relationships with unconsolidated entities or others that are reasonably likely to have a material current or future effect on our financial condition, changes in financial condition, revenue or expense, results of operations, liquidity, capital expenditures or capital resources.

Capital Expenditures

During the six months ended June 30, 2017, capital expenditures for seismic data and property and equipment amounted to $18.9 million on a gross basis and $6.5 million on a net cash basis. Our capital expenditures for the first six months of 2017 are comprised of the following (in thousands):



	Six Months Ended June 30, 2017
New data acquisition	$	11,959
Cash purchases and data processing	5,413
Non-monetary exchanges	1,250
Property and equipment	250
Total capital expenditures	18,872
Less: Non-monetary exchanges	(1,250		)
Changes in working capital	(1,271		)
Cash investment per statement of cash flows	$	16,351

Net cash capital expenditures represent total capital expenditures less cash underwriting revenue from our clients and non-cash additions to the seismic data library. We believe this measure is important as it reflects the amount of capital expenditures funded from our operating cash flow. The following table shows how our net cash capital expenditures (a non-GAAP financial measure) are derived from total capital expenditures, the most directly comparable GAAP financial measure (in thousands):



	Six Months Ended June 30, 2017
Total capital expenditures	$	18,872
Less: Non-monetary exchanges	(1,250		)
Cash underwriting revenue	(11,146		)
Net cash capital expenditures	$	6,476

As of August 7, 2017, we had capital expenditure commitments related to data acquisition projects of approximately $10.2 million, of which we have obtained approximately $8.0 million of cash underwriting. We expect more than 50% of our $2.2 million committed net cash capital expenditures to be incurred in 2017 with the remainder being incurred in 2018. See discussion of our sources of liquidity under “Liquidity and Capital Resources” beginning on page 33 of this Quarterly Report.

Table of Contents


Item 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

We are exposed to market risk, including adverse changes in foreign currency exchange rates. Historically, we have not entered into financial instruments to mitigate these risks. We do not enter into derivative or other financial instruments for speculative or trading purposes.

Hypothetical changes in foreign currency exchange rates chosen for the estimated sensitivity analysis are considered to be reasonable near-term changes generally based on consideration of past fluctuations in foreign currency exchange rates. However, since it is not possible to accurately predict future changes in foreign currency exchange rates, these hypothetical changes may not necessarily be an indicator of probable future fluctuations.

The following information about our market-sensitive financial instruments constitutes a “forward-looking statement.”

Foreign Currency Exchange Rate Risk

Our Canadian subsidiary conducts business in the Canadian dollar and is therefore subject to foreign currency exchange rate risk on cash flows related to sales, expenses, financing and investing transactions in currencies other than the U.S. dollar. Currently, we do not have any open forward exchange contracts.

Additionally, certain intercompany balances between our U.S. and Canadian subsidiaries are denominated in U.S. dollars. Since this is not the functional currency of our Canadian subsidiary, the changes in these balances are translated in our Consolidated Statements of Operations. As a result, we are exposed to foreign exchange risk as it relates to these intercompany balances. A sensitivity analysis on the intercompany balance as of June 30, 2017 indicates that if the U.S. dollar strengthened or weakened 4% (determined using an average of the last three years’ historical exchange rates) against the Canadian dollar, the effect upon our Consolidated Statements of Operations would be immaterial.

We have not had any significant changes in our market risk exposures during the quarter ended June 30, 2017.


Item 4.	CONTROLS AND PROCEDURES

a) Evaluation of Disclosure Controls and Procedures

As of the end of the period covered by this report, our management carried out an evaluation, under the supervision and with the participation of our Chief Executive Officer and President and our Chief Financial Officer, 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), pursuant to Exchange Act Rule 13a-15. Our disclosure controls and procedures are designed to provide reasonable assurance that the information required to be disclosed by us in reports that we file or submit under the Exchange Act is accumulated and communicated to our management, including our principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosures and is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC. Based upon that evaluation, our Chief Executive Officer and President along with our Chief Financial Officer concluded that the Company’s disclosure controls and procedures as of June 30, 2017 were effective at the reasonable assurance level.

b) Changes in Internal Control Over Financial Reporting

There have been no changes in our internal control over financial reporting during the quarter ended June 30, 2017 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II—OTHER INFORMATION


Item 1.	LEGAL PROCEEDINGS

See Part I, Item 1, Note G to Condensed Consolidated Interim Financial Statements, which is incorporated herein by reference.


Item 1A.	RISK FACTORS

For a discussion of our potential risks and uncertainties, see the information under the heading “Item 1A. Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2016, as amended, initially filed with the SEC on February 16, 2017, and the other information set forth elsewhere in this Quarterly Report on Form 10-Q. There have been no material changes to the risk factors disclosed in our Annual Report on Form 10-K for the year ended December 31, 2016. You should be

Table of Contents

aware that these risk factors and other information may not describe every risk we face. Additional risks and uncertainties not currently known to us or that we currently deem immaterial also may materially adversely affect our business, financial condition and/or results of operations.


Item 6.	EXHIBITS

Those exhibits required to be filed by Item 601 of Regulation S-K are listed in the Exhibit Index immediately preceding the exhibits filed herewith and such listing is incorporated herein by reference.

SIGNATURES

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.




	SEITEL, INC.

Date: August 10, 2017		/s/ Robert D. Monson
		Robert D. Monson
		Chief Executive Officer and President
		(Duly Authorized Officer and Principal Executive Officer)




Date: August 10, 2017		/s/ Marcia H. Kendrick
		Marcia H. Kendrick
		Chief Financial Officer
		(Duly Authorized Officer and Principal Financial Officer)

Table of Contents

EXHIBIT

INDEX




Exhibit		Title

3.1		Certificate of Incorporation of the Company (incorporated by reference from Exhibit 3.1 to the Registration Statement on Form S-4, No. 333-144844, as filed with the SEC on July 25, 2007).
3.2		Bylaws of Seitel, Inc. (incorporated by reference from Exhibit 3.2 to the Registration Statement on Form S-4, No. 333-144844, as filed with the SEC on July 25, 2007).
31.1	*	Rule 13a-14(a) / 15d-14(a) Certification of Chief Executive Officer.
31.2	*	Rule 13a-14(a) / 15d-14(a) Certification of Chief Financial Officer.
32.1	**	Section 1350 Certification of Chief Executive Officer.
32.2	**	Section 1350 Certification of Chief Financial Officer.
101.INS	*	XBRL Instance Document.
101.SCH	*	XBRL Taxonomy Extension Schema Document.
101.CAL	*	XBRL Taxonomy Extension Calculation Linkbase Document.
101.DEF	*	XBRL Taxonomy Extension Definition Linkbase Document.
101.LAB	*	XBRL Taxonomy Extension Label Linkbase Document.
101.PRE	*	XBRL Taxonomy Extension Presentation Linkbase Document.



*	Filed herewith.



**	Furnished, not filed.