RAME Ram Energy Resources, Inc. (MM)

RAM Energy Resources, Inc. (Nasdaq: RAME) today announced second quarter 2011 earnings and financial highlights as well as an update on its testing of several wells in the Southern Surber area of the company’s Osage Mississippian exploration play.

RAM Reports 2Q 2011 Net Income of $8.9 Million vs. $2.7 Million in 2Q2010

For the quarter ended June 30, 2011, RAM reported net income of $8.9 million, or $0.11 per share, compared to $2.7 million, or $0.03 per share, in the year-ago quarter.

Modified EBITDA (a non-GAAP measure) was $11.6 million for the 2Q11, compared with $12.5 million in last year’s quarter. Similarly, free cash flow (a non-GAAP measure) was $7.7 million, or $0.10 per share, for this year’s second quarter compared to $7.2 million, or $0.09 per share, in last year’s second quarter.

Update to Osage Concession Activity

Southern Suber Area

Modifications to the company’s production facilities and salt water disposal well have been completed, and RAM has begun the process of testing previously drilled wells that have been shut in pending completion of these improvements. In addition, the company is adding a natural gas powered electric generator to the central tank battery which will provide electricity to run submersible pumps in the Surber #1-26 and Rickets #3-26 wells and additional pumps, if needed, to increase the capacity of the water disposal facilities. Plans are to permit a second salt water disposal well for fluid disposal from the recently drilled wells and to service future wells in this area. The Surber #1-26 well, which was fracture stimulated in late March, continues to produce at rates well above the type curve, producing about 108 barrels of oil equivalent per day, or BOEPD (composed of 55 barrels of oil and 317 MCF of high BTU natural gas). Initial production testing on the Surber #1-35, Ricketts #2-35 and Surber #2-T, after having been acidized but not fractured , currently aggregates to 17 BOEPD (composed of 8 barrels of oil and 52 MCF of high BTU natural gas). As a result of the excellent response observed to date after fracturing the Surber #1-26 well, the company is evaluating plans to also apply a slick water frac treatment to the Surber #1-35, Ricketts #2-35 and Surber #2-T, with the expectation of achieving increased production volumes. The Rickets #3-26, which was drilled to the Mississippi Chat in late 2010 and fractured stimulated in April of this year, is scheduled for testing in mid-August. The well is currently shut in pending installation of the field electric generator to enhance salt water disposal capacity.

Central Mashunkashey Area

The Farmland #2-16 well, drilled in mid-April and completed in the Bartlesville formation, is producing 5 BOPD while recovering load water from a small fracture stimulation treatment initiated in late July. The Christenson #3-2, which initially tested at 750 MCFPD (125 BOEPD) of natural gas from the Arbuckle formation, is awaiting additional testing uphole in the Mississippi Dense (Lime) formation.

Additional Planned Activity

RAM plans to drill four wells targeting the Mississippi formation in the third quarter of 2011, including the Jones #1-33 and Kendrick #1-27 in the Northern Jones portion of the concession, the Cooper #3-35 (a recent replacement for the previously planned Stuart #1-28 well) in the Southern Surber area, and the Farmland #1-20 well in the Central Mashunkashey area. RAM is tentatively planning to drill its first horizontal Mississippi well in the Southern Surber area in early 2012.

The company’s Phase 2 seismic survey, which covers 31 square miles of the concession to the south and east of the 25 square mile Phase 1 seismic survey, has been completed. Processing and interpretation are underway with initial results expected in mid-September.

Second Quarter Results

Crude oil and natural gas liquids (NGL) production remained consistently high in the second quarter of 2011, accounting for 71% of total company production. Crude oil and NGL production in 2Q11 was 270 thousand barrels, up slightly compared to 269 thousand barrels of oil and NGL produced in the first quarter of 2011. Total production in 2Q11 was 380 thousand BOE, down 31% from 549 thousand BOE in 2Q10. Excluding production in the year ago quarter of 101 thousand BOE attributable to properties sold in December 2010, RAM’s production would have decreased by 15%, as shown in the accompanying table, Components of Production Decline, due primarily to normal production declines and the shutting in of one well in Louisiana in conjunction with a major workover. Given the company’s continuing outlook for lackluster natural gas prices in the intermediate term, capital spending has focused predominantly on the company’s substantial inventory of crude oil projects rather than those expected to be primarily natural gas.

The company’s realized price for oil increased 33% to an average of $100.81 per barrel in 2Q11 compared with last year’s second quarter average realized price of $75.57 per barrel. In addition, the price of NGLs grew 59% in 2Q11, averaging $57.34 per barrel, compared to the average of $36.04 per barrel for last year’s second quarter. Similarly, the company’s realized price for natural gas rose 9% in 2Q11 to an average of $4.26 per Mcf compared to an average of $3.92 per Mcf in the second quarter of 2010. The positive impact from the 49% increase in total average price per BOE in 2Q11 more than offset the impact from asset sales and normal production declines, allowing oil and gas revenue for the second quarter to grow to $28.1 million, compared to $27.2 million in the year ago second quarter. Oil and NGL production accounted for 90% of total oil and natural gas sales in 2Q11, up slightly from the 1Q11 level of 89%.

Derivative activity resulted in a $8.6 million net gain in the 2Q11, comprised of $10.7 million in unrealized mark-to-market gains, partially offset by realized losses from contract settlements and premium costs of $2.1 million (which included a $1.4 million charge associated with unwinding and novation of certain contracts in connection with the Company’s recent refinancing). As a result, total revenues for the quarter rose to $36.8 million. Derivative activity in last year’s second quarter resulted in a $1.7 million net gain, raising total revenue to $29.0 million in 2Q10.

Production expenses were $8.2 million in 2Q11, down $0.5 million from $8.7 million in 2Q10; however, excluding expenses attributable to sold properties, production expenses for 2Q10 would have been level with the year ago quarter. Production taxes were $1.5 million in 2Q11, up slightly compared to production taxes of $1.3 million, excluding asset sales, in the same quarter last year, primarily due to higher hydrocarbon prices during 2Q11. Other expenses include an $0.8 million charge for a legal settlement relating to a disputed ownership interest in an Oklahoma well.

Six Month 2011 Results

Oil and natural gas sales decreased $3.2 million, or 6%, to $53.8 million for the six months ended June 30, 2011, as compared to $57.1 million for the same period in 2010. Excluding production from the sale properties, oil and natural gas sales would have increased $3.1 million for the six months ended June 30, 2011 as compared to the same period in 2010. This increase was driven primarily by higher commodity prices during the 2011 period. Production volumes decreased 31% compared to the same period last year; however production from sold properties and the shutting in of one well in Louisiana for a major workover accounted for approximately 65% of the decline. Net loss for the six months ended June 30, 2011 was $1.0 million, or $0.01 per share, compared to net income of $5.1 million, or $0.07 per share, in the year-ago period. Results for the June 30, 2011 period were negatively impacted by unrealized derivative losses and debt extinguishment costs. Results of the June 30, 2010 period were positively impacted by unrealized derivative gains.

Modified EBITDA (a non-GAAP measure) was $24.6 million for the six months ended June 30, 2011 compared with $28.2 million in last year’s first half. Similarly, free cash flow for the first half of 2011 totaled $15.4 million, or $0.20 a share, compared with $18.5 million, or $0.24 a share, for the six month period ending June 30, 2010.

Long-Term Debt and Liquidity

At June 30, 2011, RAM’s outstanding borrowings under its credit facility totaled $205.0 million, including $75.0 million outstanding under its second lien term loan and $130.0 million drawn on its revolver, which is currently subject to a $150.0 million borrowing base. Total outstanding borrowings under the credit facility at June 30 last year totaled $245.0 million.

Interest expense for 2Q11 was $3.6 million compared to $5.7 million in the year-ago quarter. The decrease is due to lower interest rates under the company’s new credit facility completed in the first quarter of this year and lower average outstanding borrowings during this year’s quarter. The blended interest rate on borrowings was 6.2% in 2Q11 compared to 8.2% in last year’s quarter.

Capital Expenditures and Revised Plans for 2011

Capital expenditures during 2Q11 totaled $7.9 million, including $7.7 million attributable to development and exploration costs and $0.2 million for proved property acquisitions. During 2Q11 RAM participated in the drilling of 10 gross (9.2 net) development wells and 5 gross (5.0 net) exploration wells. Nine gross (8.2 net) development wells were capable of production. One gross (1.0 net) development well was in the process of testing at the end of the quarter. Five gross (5.0 net) exploration wells were either testing or waiting on completion and/or equipment at the end of the second quarter. RAM has revised its non-acquisition capital budget for the 2011 year to $29.0 million, a decrease of $6.0 million from the previously announced level of $35.0 million. Substantially all of the change is attributable to a reduction for development drilling and recompletions, primarily on our South Texas natural gas properties. The total allocated to exploration as well as geological, geophysical and seismic remains the same at $17.0 million. Consistent with prior years, the company expects all non-acquisition capital expenditures to be funded out of cash flow.

Pending the outcome of the proposed asset sale of a 90% interest in the Electra Burkburnett fields, RAM’s previously disclosed guidance of 1.7 million to 1.8 million BOE of production for 2011 and modified EBITDA of $52.0 to $55.0 million for 2011 is no longer valid.

RAM to Webcast Second Quarter 2011 Conference Call

The company’s teleconference call to review second quarter results will be broadcast live on a listen-only basis over the internet on Tuesday, August 9, 2011 at 11:00 a.m. Eastern Daylight Time. Interested parties may access the webcast by visiting the RAM Energy Resources, Inc. website at www.ramenergy.com. From the home page, select the Investor Relations tab and then Events and Presentations tab. The teleconference may be accessed by dialing (877) 645-6210 (domestic) or (970) 315-0430 (international) and providing the ID number “87189296” to the operator. The webcast will be available for replay on the company’s website following the call’s completion. An audio replay will be available until August 16, 2011 by dialing (855) 859-2056 and referencing the ID number “87189296”.

Forward-Looking Statements

This release includes certain statements that may be deemed to be “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995. All statements in this release, other than statements of historical facts, that address planned drilling, or other expected activities, well tests, anticipated production, the impact of oil and gas derivatives, borrowing availability, and events or developments that the company expects or believes are forward-looking statements. Although the company believes the expectations expressed in such forward-looking statements are based on reasonable assumptions, such statements are not guarantees of future performance and actual results or developments may differ materially from those in the forward-looking statements. Factors that could cause actual results to differ materially from those in forward-looking statements include oil and gas prices, exploitation and exploration successes, actions taken and to be taken by the government as a result of political and economic conditions, continued availability of capital and financing, and general economic, market or business conditions as well as other risk factors described from time to time in the company’s filings with the SEC. The company assumes no obligation to update publicly such forward-looking statements, whether as a result of new information, future events or otherwise.

About RAM Energy

RAM Energy Resources, Inc. is an independent energy company engaged in the acquisition, exploitation, exploration, and development of oil and natural gas properties and the marketing of crude oil and natural gas. Company headquarters are in Tulsa, Oklahoma, and its common shares are traded on the Nasdaq under the symbol RAM. For additional information, visit the company website at www.ramenergy.com.

            RAM Energy Resources, Inc. Condensed Consolidated Balance Sheets (in thousands, except share and per share amounts)   June 30, December 31, 2011 2010 (unaudited) ASSETS CURRENT ASSETS: Cash and cash equivalents $ 454 $ 37 Accounts receivable: Oil and natural gas sales, net of allowance of $50 ($50 at December 31, 2010) 9,657 9,797 Joint interest operations, net of allowance of $479 ($479 at December 31, 2010) 724 631 Other, net of allowance of $34 ($48 at December 31, 2010) 152 155 Derivative assets - 1,340 Prepaid expenses 1,030 1,657 Deferred tax asset 7,422 3,526 Inventory 3,812 3,382 Other current assets   384     4   Total current assets 23,635 20,529 PROPERTIES AND EQUIPMENT, AT COST: Proved oil and natural gas properties and equipment, using full cost accounting 702,668 689,472 Other property and equipment   10,438     10,072   713,106 699,544 Less accumulated depreciation, amortization and impairment   (499,994 )   (489,634 )

Total properties and equipment

213,112 209,910 OTHER ASSETS: Deferred tax asset 29,058 31,001 Deferred loan costs, net of accumulated amortization of $381 ($5,012 at December 31, 2010) 6,622 2,609 Other   978     952   Total assets $ 273,405   $ 265,001   LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT) CURRENT LIABILITIES: Accounts payable: Trade $ 13,807 $ 17,149 Oil and natural gas proceeds due others 9,455 9,414 Other 155 452 Accrued liabilities: Compensation 1,794 1,948 Interest 502 2,448 Income taxes 334 699 Other 640 10 Derivative liabilities 1,576 - Asset retirement obligations 352 639 Long-term debt due within one year   146     127   Total current liabilities 28,761 32,886 DERIVATIVE LIABILITIES 3,079 203 LONG-TERM DEBT 205,289 196,965 ASSET RETIREMENT OBLIGATIONS 31,504 30,770 OTHER LONG-TERM LIABILITIES 10 10 COMMITMENTS AND CONTINGENCIES   STOCKHOLDERS' EQUITY (DEFICIT): Common stock, $0.0001 par value, 100,000,000 shares authorized, 83,386,299 and 82,597,829 shares issued, 79,120,829 and 78,386,983 shares outstanding at June 30, 2011 and December 31, 2010, respectively 8 8 Additional paid-in capital 227,720 226,042 Treasury stock - 4,265,470 shares (4,210,846 shares at December 31,2010) at cost (7,084 ) (6,976 ) Accumulated deficit   (215,882 )   (214,907 ) Stockholders' equity   4,762     4,167   Total liabilities and stockholders' equity $ 273,405   $ 265,001       RAM Energy Resources, Inc. Condensed Consolidated Statements of Operations (in thousands, except share and per share amounts) (unaudited)                             Three months ended June 30, Six months ended June 30, 2011 2010 2011 2010 REVENUES AND OTHER OPERATING INCOME: Oil and natural gas sales Oil $ 22,783 $ 19,120 $ 43,195 $ 38,608 Natural gas 2,812 4,818 5,704 11,247 NGLs   2,523     3,280     4,938     7,211   Total oil and natural gas sales 28,118 27,218 53,837 57,066 Realized losses on derivatives (2,098 ) (707 ) (1,262 ) (1,605 ) Unrealized gains (losses) on derivatives 10,728 2,419 (4,225 ) 4,354 Other   34     38     85     74   Total revenues and other operating income 36,782 28,968 48,435 59,889   OPERATING EXPENSES: Oil and natural gas production taxes 1,478 1,453 2,889 3,047 Oil and natural gas production expenses 8,174 8,662 16,549 16,582 Depreciation and amortization 5,196 6,891 10,469 13,605 Accretion expense 412 454 814 836 Share-based compensation 686 785 1,355 1,471 General and administrative, overhead and other expenses, net of operator's overhead fees   3,935     3,992     7,813     7,762   Total operating expenses   19,881     22,237     39,889     43,303   Operating income 16,901 6,731 8,546 16,586   OTHER INCOME (EXPENSE): Interest expense (3,563 ) (5,714 ) (10,113 ) (11,349 ) Interest income 3 2 3 4 Loss on interest rate derivatives (362 ) - (495 ) - Other income (expense)   (801 )   570     (753 )   561   INCOME (LOSS) BEFORE INCOME TAXES 12,178 1,589 (2,812 ) 5,802 INCOME TAX PROVISION (BENEFIT)   3,242     (1,140 )   (1,837 )   655   Net income (loss) $ 8,936   $ 2,729   $ (975 ) $ 5,147     BASIC INCOME (LOSS) PER SHARE $ 0.11   $ 0.03   $ (0.01 ) $ 0.07   BASIC WEIGHTED AVERAGE SHARES OUTSTANDING   78,834,159     78,446,305     78,598,387     78,222,925     DILUTED INCOME (LOSS) PER SHARE $ 0.11   $ 0.03   $ (0.01 ) $ 0.07   DILUTED WEIGHTED AVERAGE SHARES OUTSTANDING   78,834,159     78,446,305     78,598,387     78,222,925       RAM Energy Resources, Inc. Condensed Consolidated Statements of Cash Flows (in thousands) (unaudited)       Six months ended June 30, 2011         2010 OPERATING ACTIVITIES: Net income (loss) $ (975 ) $ 5,147 Adjustments to reconcile net income (loss) to net cash provided by operating activities- Depreciation and amortization 10,469 13,605 Amortization of deferred loan costs 2,990 1,044 Non-cash interest 362 1,543 Accretion expense 814 836 Unrealized (gain) loss on commodity derivatives, net of premium amortization 5,474 (2,997 ) Unrealized loss on interest rate derivatives 418 - Deferred income tax provision (benefit) (1,953 ) 268 Share-based compensation 1,355 1,471 Gain on disposal of other property and equipment (22 ) (41 ) Other income - (550 ) Changes in operating assets and liabilities- Accounts receivable 49 3,237 Prepaid expenses, inventory and other assets (208 ) 657 Derivative premiums (111 ) (2,866 ) Accounts payable and proceeds due others (3,553 ) 1,028 Accrued liabilities and other (1,459 ) (1,004 ) Income taxes payable (365 ) (177 ) Asset retirement obligations   (242 )   -   Total adjustments   14,018     16,054   Net cash provided by operating activities   13,043     21,201   INVESTING ACTIVITIES: Payments for oil and natural gas properties and equipment (13,500 ) (18,666 ) Proceeds from sales of oil and natural gas properties 462 478 Payments for other property and equipment (469 ) (358 ) Proceeds from sales of other property and equipment   11     4   Net cash used in investing activities   (13,496 )   (18,542 ) FINANCING ACTIVITIES: Payments on long-term debt (223,185 ) (24,576 ) Proceeds from borrowings on long-term debt 231,166 22,132 Payments for deferred loan costs (7,003 ) - Stock repurchased   (108 )   (326 ) Net cash provided by (used in) financing activities   870     (2,770 ) INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS 417 (111 ) CASH AND CASH EQUIVALENTS, beginning of period   37     129   CASH AND CASH EQUIVALENTS, end of period $ 454   $ 18   SUPPLEMENTAL CASH FLOW INFORMATION: Cash paid for income taxes $ 481   $ 565   Cash paid for interest $ 8,706   $ 9,107   DISCLOSURE OF NON CASH INVESTING AND FINANCING ACTIVITIES: Asset retirement obligations $ (129 ) $ 118       RAM ENERGY RESOURCES, INC. PRODUCTION BY AREA (unaudited)                                 Texas Oklahoma Louisiana Other Total Three Months Ended June 30, 2011 Aggregate Net Production Oil (MBbls) 128 74 16 8 226 NGLs (MBbls) 38 2 - 4 44 Natural Gas (MMcf) 412 107 105 36 660   MBoe 234 94 33 19 380   Three Months Ended June 30, 2010 Aggregate Net Production Oil (MBbls) 142 82 22 7 253 NGLs (MBbls) 85 2 - 4 91 Natural Gas (MMcf) 774 224 192 40 1,230   MBoe 356 121 54 18 549   Change in MBoe (122) (27) (21) 1 (169) Percentage Change in MBoe -34.3% -22.3% -38.9% 5.6% -30.8%       Texas Oklahoma Louisiana Other Total Six Months Ended June 30, 2011 Aggregate Net Production Oil (MBbls) 253 148 32 15 448 NGLs (MBbls) 79 5 - 7 91 Natural Gas (MMcf) 856 187 258 69 1,370   MBoe 474 184 75 34 767   Six Months Ended June 30, 2010 Aggregate Net Production Oil (MBbls) 291 163 39 17 510 NGLs (MBbls) 177 5 - 7 189 Natural Gas (MMcf) 1,638 436 347 78 2,499   MBoe 741 240 97 37 1,115   Change in MBoe (267) (56) (22) (3) (348) Percentage Change in MBoe -36.0% -23.3% -22.7% -8.1% -31.2%     RAM Energy Resources, Inc. Components of Production Decline

(unaudited)

              Three months ended Six months ended June 30 June 30 (MBOE) (MBOE)   Total production, 2010 549 1,115   Declines due to:   RAM Texas and Oklahoma gas properties sold in 2010 (101) (205)   Natural production declines in South Texas gas production (24) (71)  

Louisiana well shut-in

(12) (17)   Other (32) (55)   Total declines (169) (348)     Total production, 2011 380 767                    

2010 Pro Forma Selected Results Excluding Sold Properties (a)

(unaudited)

 

Three months ended

June 30, 2010

  Sold Pro

Actual

Assets

Forma

Oil and natural gas sales (in thousands): Oil $ 19,120 $ 346 $ 18,774 Natural gas 4,818 1,244 3,574 NGLs 3,280 1,291   1,989  

Total oil and natural gas sales

$ 27,218 $ 2,881 $ 24,337   Production expenses (in thousands): Oil and natural gas production taxes $ 1,453 $ 125 $ 1,328 Oil and natural gas production expenses $ 8,662 $ 454 $ 8,208   Production volumes: Texas (Mboe) 356 86 270 Oklahoma (Mboe) 121 15 106 Other (Mboe) 72 — 72   Total production (Mboe) 549 101 448       Six months ended

June 30, 2010

  Sold Pro Actual Assets Forma Oil and natural gas sales (in thousands): Oil $ 38,608 $ 677 $ 37,931 Natural gas 11,247 2,874 8,373 NGLs 7,211 2,773 4,438   Total oil and natural gas sales $ 57,066 $ 6,324 $ 50,742   Production expenses (in thousands): Oil and natural gas production taxes $ 3,047 $ 253 $ 2,794 Oil and natural gas production expenses $ 16,582 $ 945 $ 15,637   Production volumes: Texas (Mboe) 741 171 570 Oklahoma (Mboe) 240 34 206 Other (Mboe) 134 — 134   Total production (Mboe) 1,115 205 910 (a)   In December 2010 RAM sold assets in Texas and Oklahoma for net proceeds of $48 million. The table above provides actual and pro forma results for the three and six months ending June 30, 2010 to assist our description of results of operations.   RAM Energy Resources, Inc. Production and Prices Summary               Three Months Ended Six Months Ended June 30, 2011 June 30, 2011   Production volumes: Oil (MBbls) 226 448 NGL (MBbls) 44 91 Natural gas (MMcf) 660 1,370 Total (Mboe) 380 767   Average sale prices received: Oil (per Bbl) $ 100.81 $ 96.42 NGL (per Bbl) $ 57.34 $ 54.26 Natural gas (per Mcf) $ 4.26 $ 4.16

Total per Boe

$ 73.99 $ 70.19   Cash effect of derivative contracts: Oil (per Bbl) $ (8.65 ) $ (6.63 ) NGL (per Bbl) $ - $ - Natural gas (per Mcf) $ (0.22 ) $ 1.25

Total per Boe

$ (5.52 ) $ (1.65 )   Average prices computed after cash effect of settlement of derivative contracts: Oil (per Bbl) $ 92.16 $ 89.79 NGL (per Bbl) $ 57.34 $ 54.26 Natural gas (per Mcf) $ 4.04 $ 5.41

Total per Boe

$ 68.47 $ 68.54   Expenses (per Boe): Oil and natural gas production taxes $ 3.89 $ 3.77 Oil and natural gas production expenses $ 21.51 $ 21.58 General and administrative $ 10.36 $ 10.19 Cash interest $ 8.82 $ 11.35 Cash taxes $ 1.33 $ 0.63

Total Cash Expenses per Boe

$ 45.91 $ 47.52  

RAM Energy Resources, Inc.Modified EBITDA and Free Cash Flow(non-GAAP measures)(unaudited)

Non-GAAP Financial Measures

Modified EBITDA, a non-GAAP measure, is determined by adding the following to net income (loss): interest expense, income taxes, depreciation, amortization, accretion, share-based compensation, impairment charges, unrealized gains or losses on derivatives. Free cash flow is also a non-GAAP measure representing Modified EBITDA after adjustments for the cash portion of interest and income taxes. These non-GAAP measures are presented because management believes it is a useful adjunct to cash provided by operating activities under accounting principles generally accepted in the United States (GAAP). These non-GAAP measures are widely accepted as financial indicators of an oil and gas company’s ability to generate cash used to internally fund exploration and development activities and fund debt service costs. These non-GAAP measures are not a measure of financial performance under GAAP and should not be considered as an alternative to cash provided (used) by operating, investing, or financing activities as an indicator of cash flows, or as a measure of liquidity.

                        $000s, except per share amounts   Three Months Ended Six Months Ended 6/30/2011       6/30/2010 6/30/2011       6/30/2010   Modified EBITDA: Net income (loss) $ 8,936 $ 2,729 $ (975 ) $ 5,147 Plus: Interest expense $ 3,291 $ 4,414 $ 6,675 $ 8,762 Plus: PIK interest $ - $ 778 $ 448 $ 1,543 Plus: Amortization of deferred loan costs $ 272 $ 522 $ 2,990 $ 1,044 Plus: Depreciation, amortization and accretion $ 5,608 $ 7,345 $ 11,283 $ 14,441 Plus: Share-based compensation $ 686 $ 785 $ 1,355 $ 1,471 Plus: Income tax provision (benefit) $ 3,242 $ (1,140 ) $ (1,837 ) $ 655 Plus: MTM legal settlement $ - $ (550 ) $ - $ (550 ) Less: Unrealized (gain) loss on derivatives $ (10,432 )       $ (2,419 ) $ 4,643         $ (4,354 )   Modified EBITDA $ 11,603 $ 12,464 $ 24,582 $ 28,159   Less:   Cash paid for interest $ 3,351 $ 4,760 $ 8,706 $ 9,107 Cash paid for income tax $ 504 $ 501 $ 481 $ 565                       Free cash flow $ 7,748         $ 7,203   $ 15,395         $ 18,487     Weighted average shares outstanding - basic 78,834 78,446 78,598 78,223 Weighted average shares outstanding - diluted 78,834 78,446 78,598 78,223   Free cash flow per share - basic $ 0.10 $ 0.09 $ 0.20 $ 0.24 Free cash flow per share - diluted $ 0.10 $ 0.09 $ 0.20 $ 0.24