FOR IMMEDIATE RELEASE
|
NEWS RELEASE
Contacts:
Gastar Exploration Ltd.
Michael A. Gerlich, Chief Financial Officer
713-739-1800 /
mgerlich@gastar.com
Investor Relations Counsel:
Lisa Elliott / Anne Pearson
DRG&L: 713-529-6600
lelliott@drg-l.com
/
apearson@drg-l.com
|
GASTAR EXPLORATION LTD. REPORTS
SECOND QUARTER 2011 RESULTS
HOUSTON, August 8, 2011
– Gastar Exploration Ltd. (NYSE Amex: GST) (“Gastar”) today reported financial and operating results for the three- and six-month periods ended June 30, 2011.
Net income attributable to Gastar’s common shareholders for the second quarter of 2011 was $126,000, or $0.00 per diluted share. This compares to a net loss of $2.5 million, or $0.05 per share, for the second quarter of 2010. Excluding the impact of an unrealized natural gas hedging gain of $502,000 and other special items, adjusted net loss attributable to common shareholders was $377,000, or $0.01 per share for the second quarter of 2011. Excluding an unrealized natural gas hedging loss of $972,000 and other special items, adjusted net loss for the second quarter of 2010 was $1.5 million, or $0.03 per share. (See the accompanying reconciliation of net income (loss) per common share and earnings per share to these non-GAAP financial measures at the end of this news release.)
Our net cash flow provided by operations for the second quarter of 2011 was $6.1 million compared to net cash flow used in operations of $2.7 million in the same period last year. Net cash flow from operations for the first half of 2011 was $7.7 million, versus $5.1 million for first six months of 2010. Our cash flow from operations before working capital changes and as adjusted for special items for the second quarter was $2.9 million versus $1.9 million in the second quarter of 2010, and $7.4 million for the first six months of 2011 versus $4.3 million for the same period last year. (See the accompanying reconciliation of cash flow before working capital changes and special items to these non-GAAP financial measures at the end of this news release.)
Natural gas and oil revenues increased 26% to $8.5 million in the second quarter of 2011, up from $6.7 million for the same period a year ago. The increase in revenues was the result of an 18% increase in volumes combined with a 7% increase in realized commodity prices. Average daily production was 18.6 million cubic feet of natural gas equivalent (MMcfe) for the second quarter, compared to 15.8 MMcfe per day for the same period in 2010.
During the second quarter of 2011, approximately 79% of our natural gas production was hedged. The realized effect of hedging on natural gas sales was an increase of $1.7 million in revenues and resulted in an increase in total price received from $3.52 per thousand cubic feet (Mcf) to $4.59 per Mcf. We continue to maintain an active hedging program covering a substantial portion of our estimated future natural gas production.
Lease operating expense (LOE) was $1.9 million in the second quarter of 2011, which is unchanged from the second quarter of 2010. LOE per Mcf equivalent (Mcfe) of production decreased to $1.10 from $1.33 in the second quarter of 2010. The decrease in the rate per Mcfe was primarily due to lower ad valorem taxes of $0.09 per Mcfe, lower workover costs of $0.22 per Mcfe and higher production volumes.
Depreciation, depletion and amortization (DD&A) was $3.0 million in the second quarter of 2011, up from $1.7 million in the second quarter of 2010. The increase in DD&A expense was the result of a 52% increase in the DD&A rate per Mcfe and an 18% increase in production. The DD&A rate for the second quarter of 2011 increased primarily due to higher proved costs associated with recent wells drilled to test oil prospects in East Texas and limited initial reserve increases related to these activities. By comparison, the second quarter 2010 DD&A rate was reduced by gathering system sales proceeds credited to proved property costs in the fourth quarter of 2009.
General and administrative (G&A) expense was $2.6 million in the second quarter of 2011, down from $3.9 million for the second quarter of 2010 and includes non-cash stock-based compensation expense of $538,000 and $880,000 for the quarter ended June 30, 2011 and 2010, respectively. The decrease in stock-based compensation expense is primarily due to the forfeiture of previously issued unvested awards as a result of employee resignations, prior-year awards being fully amortized and recently issued shares having a lower fair value. Excluding the non-cash stock based compensation, G&A expense decreased $1.0 million due to lower legal fees as a result of the settlement of the Classic Star litigation in November 2010.
Operations Review and Update
Appalachia
In late July, we announced initial production test results of our first two horizontal Marcellus wells in Marshall County, West Virginia, which came in above our expectations for individual well results. The Wengerd 1H and 7H, with lateral lengths of 4,700 and 5,700 feet, respectively, tested at a combined stabilized rate of approximately 15.5 MMcf per day of 1,285 Btu natural gas and 1,100 barrels of condensate per day. Currently, both wells are being placed on sales.
We have identified approximately 72 additional well locations within the immediate vicinity of the Wengerd wells and plan to spud approximately 21 more wells in Marshall County before the end of 2011. Including the Wengerd 1H and 7H, we expect to have 8 to 10 wells on sales by year-end and another 8 to 11 wells on sales in the first half of 2012 with working interest of between 40-50% in these wells. We will have three rigs working in Marshall County, two drilling horizontal sections and one drilling the vertical sections. We have collected a full array of micro-seismic data during the two Wengerd completions and plan to use that data to improve our results and become more efficient with our completions. Gastar holds approximately 4,700 net (9,400 gross) acres in Marshall County within our Atinum Joint Venture.
We have also recently finished drilling the Hickory Ridge 2H, our first well on our Marcellus East Acquisition acreage in Preston County, West Virginia. This well is outside our Atinum Joint Venture, and we have a 100% working interest. We are planning a multi-stage fracture stimulation in August 2011, with first natural gas sales anticipated in September. No additional wells are currently planned to be drilled on the Marcellus East Acquisition acreage in 2011 pending the completion of a 3-D seismic survey over a portion of the acreage.
In Butler County, Pennsylvania, Gastar and Atinum have been participating in seven wells with Rex Energy as operator, of which three are expected to be on sales by year-end, with the remaining four wells to go online in early 2012.
For the three and six months ended June 30, 2011, net production from the Appalachia area averaged approximately 0.6 MMcfe per day, compared to 0.4 MMcfe per day for the first and second quarters of 2010, respectively.
Capital expenditures net to us for the second quarter of 2011 in Appalachia were $7.0 million.
East Texas
We recently completed the drilling of the Belin #3 deep Bossier well to a total depth of 20,100 feet and has run casing to a depth of 19,120 feet. The well encountered 60 net feet of potential lower Bossier pay in four separate lower Bossier sands. The well is scheduled to be fracture stimulated in the deepest potentially productive zone in September 2011.
In April 2011 we fracture stimulated the initial formation zone in the previously drilled Belin #2 well, with marginal results. In early May 2011, we fracture stimulated the next zone, which based on log interpretation should have been the most productive lower Bossier zone in the well. During this procedure, we experienced equipment failure and the operation had to be stopped before it was completed. We subsequently attempted to re-fracture the zone, but it appears there may have been reservoir damage from the first fracture attempt, and production from the well is minimal. We are planning another re-fracture stimulation of the zone in November 2011. We have a 67% before payout working interest and an approximate 50% before payout net revenue interest in the Belin #2 and #3 wells.
To help maintain current production levels in the field, we are planning to add two recompletion zones in the Wildman #5 well in November 2011. Once completed and pressures are normalized, we plan to commingle all zones in the well. Additionally, we are currently performing workover operations in the Holmes #1 well.
During the second quarter of 2011, we continued to monitor the four wells previously drilled to test the productivity of the Glen Rose and Eagle Ford/Woodbine (Eaglebine) formations on our East Texas acreage. Production rates for these wells have been lower than expected, but we believe that the drilling and completion methods that we have used so far have not been optimal. Due to drilling issues with our Wildman 7H horizontal well, we do not believe that we have adequately tested the horizontal drilling potential of the Eaglebine formation. For the balance of 2011, we are postponing further drilling tests on these formations and will instead continue monitoring the four wells, analyzing a core sample taken from the Eaglebine section of a nearby well and observing offset operator drilling activity in the zones.
In East Texas, second quarter of 2011 net production from the Hilltop area averaged 16.6 MMcfe per day, down from 20.4 MMcfe per day in the first quarter of 2011. The lower volumes were due to natural declines in field production that were not offset by incremental production from newly completed wells during the second quarter.
Capital expenditures in East Texas were $9.9 million for the second quarter.
J. Russell Porter, Gastar's President and CEO, stated, “We are highly encouraged by the initial test results of our liquids-rich area of the Marcellus Shale in Marshall County, West Virginia and are excited to have our Marcellus drilling program underway. Based on the early indications, we believe we are operating in a very productive area of the play that could generate excellent returns on investment. Additionally, we believe our active program positions us to achieve significant reserve growth by year end 2011, with escalating oil and gas production volumes later in the year and throughout 2012, as we put these wells on line,” Porter said.
Liquidity and Capital Budget
At June 30, 2011, we had cash and cash equivalents of $5.5 million and a net working capital deficit of approximately $16.9 million, including $11.8 million of advances from non-operators, a portion of which will be applied to our net future costs pursuant to the carried interest provisions of the Atinum Joint Venture. Availability under our Revolving Credit Facility was $42.0 million on June 30, 2011.
During the second quarter of 2011, Gastar Exploration USA, Inc. (“Gastar USA”), the primary operating subsidiary of Gastar, which owns 100% of the common stock of Gastar USA, sold 650,728 shares of its 8.625% Series A Cumulative Preferred Securities with a liquidation preference of $25.00 per share, of which 646,295 shares were sold in an underwritten public offering and 4,433 shares under an at-the-market agreement, for net proceeds of $13.7 million. Under the terms of the at-the-market agreement, Gastar USA may offer and sell from time to time up to 3,400,000 shares of Series A Preferred Stock through a sales agent.
Capital expenditures for the remainder of 2011 are projected to be approximately $37.3 million, consisting of drilling, completion, infrastructure, lease acquisition and seismic costs of $30.5 million in Appalachia and $5.2 million in East Texas and an additional $1.6 million for capitalized interest and other costs. We plan on funding this capital activity through existing cash balances, internally generated cash flow from operating activities, borrowings under the Revolving Credit Facility, a possible joint venture for the development of our Marcellus Acquisition acreage and possible future at-the-market issuances of preferred equity securities by Gastar USA.
Conference Call
Gastar Exploration’s management team will hold a conference call today at 10:00 a.m. Eastern Time (9:00 a.m. Central Time) to discuss these results. To participate in the call, dial 480-629-9771
and ask for the Gastar Exploration conference call. A replay will be available and will be accessible through August 15, 2011. To access the replay, dial 303-590-3030 and enter the pass code 4457364 #.
The call will also be webcast live over the Internet at
www.gastar.com
. To listen to the live call on the Internet, please visit Gastar’s web site at least 10 minutes early to register and download any necessary audio software. An archive will be available shortly after the call. For more information, please contact Donna Washburn at DRG&L at 713-529-6600 or e-mail
dmw@drg-l.com
.
About Gastar Exploration
Gastar Exploration Ltd. is an independent company engaged in the exploration, development and production of natural gas and oil in the United States. Our principal business activities include the identification, acquisition, and subsequent exploration and development of natural gas and oil properties with an emphasis on prospective deep structures identified through seismic and other analytical techniques as well as unconventional natural gas reserves, such as shale resource plays. We are pursuing natural gas exploration in the Marcellus Shale in the Appalachian area of West Virginia and central and southwestern Pennsylvania and in the deep Bossier gas play in the Hilltop area of East Texas. We also conduct limited coal bed methane development activities within the Powder River Basin of Wyoming and Montana. For more information, visit our web site at www.gastar.com.
Safe Harbor Statement and Disclaimer
This news release includes “forward looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. Forward looking statements give our current expectations, opinion, belief or forecasts of future events and performance. A statement identified by the use of forward looking words including “may,” “expects,” “projects,” “anticipates,” “plans,” “believes,” “estimate,” “will,” “should,” and certain of the other foregoing statements may be deemed forward-looking statements. Although Gastar believes that the expectations reflected in such forward-looking statements are reasonable, these statements involve risks and uncertainties that may cause actual future activities and results to be materially different from those suggested or described in this news release. These include risk inherent in natural gas and oil drilling and production activities, including risks of fire, explosion, blowouts, pipe failure, casing collapse, unusual or unexpected formation pressures, environmental hazards, and other operating and production risks, which may temporarily or permanently reduce production or cause initial production or test results to not be indicative of future well performance or delay the timing of sales or completion of drilling operations; delays in receipt of drilling permits; risks with respect to natural gas and oil prices, a material decline in which could cause Gastar to delay or suspend planned drilling operations or reduce production levels; risks relating to the availability of capital to fund drilling operations that can be adversely affected by adverse drilling results, production declines and declines in natural gas and oil prices; risks relating to unexpected adverse developments in the status of properties; risks relating to the absence or delay in receipt of government approvals or fourth party consents; and other risks described in Gastar’s Annual Report on Form 10-K and other filings with the SEC, available at the SEC’s website at www.sec.gov. Our actual sales production rates can vary considerably from tested initial production rates depending upon completion and production techniques and our primary areas of operations are subject to natural steep decline rates. By issuing forward looking statements based on current expectations, opinions, views or beliefs, Gastar has no obligation and, except as required by law, is not undertaking any obligation, to update or revise these statements or provide any other information relating to such statements.
- Financial Tables Follow -
GASTAR EXPLORATION LTD. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
GASTAR EXPLORATION LTD. AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
|
June 30,
|
December 31,
|
|||||||
|
2011
|
2010
|
|||||||
|
(Unaudited)
|
||||||||
|
(in thousands)
|
||||||||
|
ASSETS
|
||||||||
|
CURRENT ASSETS:
|
||||||||
|
Cash and cash equivalents
|
$ | 5,495 | $ | 7,439 | ||||
|
Accounts receivable, net of allowance for doubtful accounts of $561 and $571, respectively
|
6,333 | 4,034 | ||||||
|
Commodity derivative contracts
|
9,708 | 10,229 | ||||||
|
Prepaid expenses
|
611 | 1,191 | ||||||
|
Total current assets
|
22,147 | 22,893 | ||||||
|
PROPERTY, PLANT AND EQUIPM ENT:
|
||||||||
|
Natural gas and oil properties, full cost method of accounting:
|
||||||||
|
Unproved properties, excluded from amortization
|
157,879 | 162,230 | ||||||
|
Proved properties
|
391,030 | 345,042 | ||||||
|
Total natural gas and oil properties
|
548,909 | 507,272 | ||||||
|
Furniture and equipment
|
1,449 | 1,175 | ||||||
|
Total property, plant and equipment
|
550,358 | 508,447 | ||||||
|
Accumulated depreciation, depletion and amortization
|
(300,435 | ) | (293,332 | ) | ||||
|
Total property, plant and equipment, net
|
249,923 | 215,115 | ||||||
|
OTHER ASSETS:
|
||||||||
|
Restricted cash
|
50 | 50 | ||||||
|
Commodity derivative contracts
|
5,650 | 8,482 | ||||||
|
Deferred charges, net
|
393 | 508 | ||||||
|
Advances to operators and other assets
|
728 | 304 | ||||||
|
Total other assets
|
6,821 | 9,344 | ||||||
|
TOTAL ASSETS
|
$ | 278,891 | $ | 247,352 | ||||
|
LIABILITIES AND SHAREHOLDERS' EQUITY
|
||||||||
|
CURRENT LIABILITIES:
|
||||||||
|
Accounts payable
|
$ | 8,697 | $ | 8,294 | ||||
|
Revenue payable
|
4,567 | 4,331 | ||||||
|
Accrued interest
|
129 | 138 | ||||||
|
Accrued drilling and operating costs
|
4,724 | 1,490 | ||||||
|
Advances from non-operators
|
11,784 | 783 | ||||||
|
Commodity derivative contracts
|
817 | 1,991 | ||||||
|
Commodity derivative premium payable
|
4,144 | 3,451 | ||||||
|
Accrued litigation settlement liability
|
2,192 | 3,164 | ||||||
|
Other accrued liabilities
|
2,011 | 2,024 | ||||||
|
Total current liabilities
|
39,065 | 25,666 | ||||||
|
LONG-TERM LIABILITIES:
|
||||||||
|
Long-term debt
|
8,000 | - | ||||||
|
Commodity derivative contracts
|
1,255 | 1,521 | ||||||
|
Commodity derivative premium payable
|
2,590 | 4,725 | ||||||
|
Accrued litigation settlement liability
|
- | 800 | ||||||
|
Asset retirement obligation
|
7,682 | 7,249 | ||||||
|
Total long-term liabilities
|
19,527 | 14,295 | ||||||
|
Commitments and contingencies (Note 12)
|
||||||||
|
SHAREHOLDERS' EQUITY:
|
||||||||
|
Common stock, no par value; unlimited shares authorized; 64,778,274 and 64,179,115 shares issued and outstanding at June 30, 2011 and December 31, 2010, respectively
|
316,346 | 316,346 | ||||||
|
Additional paid-in capital
|
24,205 | 23,200 | ||||||
|
Accumulated deficit
|
(133,964 | ) | (132,155 | ) | ||||
|
Total shareholders' equity
|
206,587 | 207,391 | ||||||
|
Non-controlling interest:
|
||||||||
|
Preferred stock of subsidiary, aggregate liquidation preference $16,268 and $0 at June 30, 2011 and
December 31, 2010, respectively
|
13,712 | - | ||||||
|
Total equity
|
220,299 | 207,391 | ||||||
|
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY
|
$ | 278,891 | $ | 247,352 | ||||
GASTAR EXPLORATION LTD. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
|
For the Six Months Ended
|
||||||||
|
June 30,
|
||||||||
|
2011
|
2010
|
|||||||
|
(in thousands)
|
||||||||
|
CASH FLOWS FROM OPERATING ACTIVITIES:
|
||||||||
|
Net income (loss)
|
$ | (1,778 | ) | $ | 6,895 | |||
|
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
|
||||||||
|
Depreciation, depletion and amortization
|
7,103 | 3,395 | ||||||
|
Stock-based compensation
|
1,243 | 1,639 | ||||||
|
Unrealized natural gas hedge (gain) loss
|
1,397 | (8,406 | ) | |||||
|
Realized loss (gain) on derivative contracts
|
(871 | ) | 1,763 | |||||
|
Amortization of deferred financing costs and debt discount
|
128 | 157 | ||||||
|
Accretion of asset retirement obligation
|
254 | 191 | ||||||
|
Unrealized warrant derivative gain
|
- | (203 | ) | |||||
|
Dividend on preferred stock attributable to non-controlling interest
|
(31 | ) | - | |||||
|
Changes in operating assets and liabilities:
|
||||||||
|
Accounts receivable
|
(625 | ) | 1,615 | |||||
|
Commodity derivative contracts
|
(54 | ) | 1,252 | |||||
|
Prepaid expenses
|
388 | 232 | ||||||
|
Accrued taxes payable
|
- | (1,245 | ) | |||||
|
Accounts payable and accrued liabilities
|
555 | (2,151 | ) | |||||
|
Net cash provided by operating activities
|
7,709 | 5,134 | ||||||
|
CASH FLOWS FROM INVESTING ACTIVITIES:
|
||||||||
|
Development and purchase of natural gas and oil properties
|
(39,074 | ) | (24,591 | ) | ||||
|
Advances to operators
|
(3,155 | ) | - | |||||
|
Proceeds from sale of natural gas and oil properties
|
- | 19,199 | ||||||
|
Proceeds from non-operators
|
11,001 | (686 | ) | |||||
|
Purchase of furniture and equipment
|
(274 | ) | (142 | ) | ||||
|
Purchase of term deposit
|
- | (4,855 | ) | |||||
|
Net cash used in investing activities
|
(31,502 | ) | (11,075 | ) | ||||
|
CASH FLOWS FROM FINANCING ACTIVITIES:
|
||||||||
|
Proceeds from revolving credit facility
|
20,000 | 8,000 | ||||||
|
Repayment of revolving credit facility
|
(12,000 | ) | - | |||||
|
Repayment of short-term loan
|
- | (17,000 | ) | |||||
|
Proceeds from issuance of preferred stock, net of issuance costs
|
14,000 | - | ||||||
|
Deferred financing charges
|
(13 | ) | - | |||||
|
Other
|
(138 | ) | (103 | ) | ||||
|
Net cash provided by (used in) financing activities
|
21,849 | (9,103 | ) | |||||
|
NET DECREASE IN CASH AND CASH EQUIVALENTS
|
(1,944 | ) | (15,044 | ) | ||||
|
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD
|
7,439 | 21,866 | ||||||
|
CASH AND CASH EQUIVALENTS, END OF PERIOD
|
$ | 5,495 | $ | 6,822 | ||||
GASTAR EXPLORATION LTD.
AND SUBSIDIARIES
PRODUCTION AND PRICES
|
For the Three Months Ended
|
For the Six Months Ended
|
|||||||||||||||
|
June 30,
|
June 30,
|
|||||||||||||||
|
2011
|
2010
|
2011
|
2010
|
|||||||||||||
|
Production:
|
||||||||||||||||
|
Natural gas (MMcf)
|
1,634 | 1,428 | 3,600 | 3,181 | ||||||||||||
|
Oil (MBbl)
|
11 | 2 | 21 | 4 | ||||||||||||
|
Total production (MMcfe)
|
1,697 | 1,440 | 3,728 | 3,204 | ||||||||||||
|
Total (MMcfed)
|
18.6 | 15.8 | 20.6 | 17.7 | ||||||||||||
|
Average sales price per unit:
|
||||||||||||||||
|
Natural gas per Mcf, excluding impact of realized hedging activities
|
$ | 3.52 | $ | 3.50 | $ | 3.43 | $ | 3.97 | ||||||||
|
Natural gas per Mcf, including impact of realized hedging activities
|
4.59 | 4.62 | 4.60 | 4.16 | ||||||||||||
|
Oil per Bbl
|
96.66 | 72.67 | 92.30 | 72.36 | ||||||||||||
NON-GAAP FINANCIAL INFORMATION AND RECONCILIATION
We use both GAAP and certain non-GAAP financial measures to assess performance. Generally, a non-GAAP financial 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. Our management believes that these non-GAAP measures provide useful supplemental information to investors in order that they may evaluate our financial performance using the same measures as management. These non-GAAP financial measures should not be considered as a substitute for, or superior to, measures of financial performance prepared in accordance with GAAP. In evaluating these measures, investors should consider that the methodology applied in calculating such measures may differ among companies and analysts. A reconciliation is provided below outlining the differences between these non-GAAP measures and the directly related GAAP measures.
Reconciliation of Net Income (Loss) to Net Income (Loss) Excluding Special Items:
Reconciliation of Cash Flow from Operations Before Working Capital Changes and Special Items:
|
For the Three Months Ended
|
For the Six Months Ended
|
|||||||||||||||
|
June 30,
|
June 30,
|
|||||||||||||||
|
2011
|
2010
|
2011
|
2010
|
|||||||||||||
|
CASH FLOWS FROM OPERATING ACTIVITIES:
|
||||||||||||||||
|
Net income (loss)
|
$ | 157 | $ | (2,498 | ) | $ | (1,778 | ) | $ | 6,895 | ||||||
|
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
|
||||||||||||||||
|
Depreciation, dep letion and amortization
|
2,991 | 1,664 | 7,103 | 3,395 | ||||||||||||
|
Stock-based compensation
|
538 | 880 | 1,243 | 1,639 | ||||||||||||
|
Unrealized natural gas hedge (gain) loss
|
(502 | ) | 972 | 1,397 | (8,406 | ) | ||||||||||
|
Realized loss (gain) on derivative contracts
|
(429 | ) | 724 | (871 | ) | 1,763 | ||||||||||
|
Amortization of deferred financing costs and debt discount
|
65 | 61 | 128 | 157 | ||||||||||||
|
Accretion of asset retirement obligation
|
129 | 96 | 254 | 191 | ||||||||||||
|
Unrealized warrant derivative gain
|
- | (55 | ) | - | (203 | ) | ||||||||||
|
Dividend on preferred stock attributable to non-controlling interest
|
(31 | ) | - | (31 | ) | - | ||||||||||
|
Cash flow from operations before working capital changes (1)
|
2,918 | 1,844 | 7,445 | 5,431 | ||||||||||||
|
Foreign transaction gain
|
(1 | ) | (16 | ) | (3 | ) | (335 | ) | ||||||||
|
Provision for income tax expense (benefit)
|
- | 57 | - | (792 | ) | |||||||||||
|
Adjusted cash flow from operations for special items
|
$ | 2,917 | $ | 1,885 | $ | 7,442 | $ | 4,304 | ||||||||
_____________________
(1)
Cash flow from operations before working capital changes represents cash flows from operating activities before changes in operating assets and liabilities. We have reported cash flow from operations before working capital because we believe it is a measure commonly reported and widely used by investors as an indicator of a company’s operating performance. Cash flow from operations before working capital changes is not a calculation based on U.S. GAAP and should not be considered an alternative to net income (loss) in measuring our performance or used as an exclusive measure of cash flow because it does not consider the impact of working capital growth, which are disclosed in our statements of cash flows. Investors should carefully consider the specific items included in our computation of cash flow from operations before working capital changes. While we have disclosed our cash flow from operations before working capital to permit a more complete comparative analysis of our operating performance relative to other companies, investors should be cautioned that cash flow from operations before working capital changes as reported by us may not be comparable in all instances to cash flow from operations before working capital changes as reported by other companies.
# # #
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