SARATOGA RESOURCES, INC.

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, DC 20549


FORM 10-Q

(Mark One)


x

QUARTERLY REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934


For the quarterly period ended March 31, 2013


OR


o

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


For the transition period from ___________ to ______________.


Commission File Number 001-35241


SARATOGA RESOURCES, INC.

(Exact name of registrant as specified in its charter)


Texas

 

76-0314489

(State or other jurisdiction of incorporation or organization)

 

(IRS Employer Identification No.)


7500 San Felipe, Suite 675, Houston, Texas 77063

 (Address of principal executive offices)(Zip Code)


(713) 458-1560

(Registrant's telephone number, including area code)


 

 (Former name, former address and former fiscal year, if changed since last report)


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


Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§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 x   No ¨


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


Large accelerated filer  ¨

Accelerated filer  x

Non-accelerated filer  ¨

Smaller reporting company  ¨


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


Indicate by check mark whether the registrant has filed all documents and reports required to be filed by Section 12, 13 or 15(d) of the Securities Exchange Act of 1934 subsequent to the distribution of securities under a plan confirmed by a court.  Yes x   No ¨


As of May 3, 2013, we had 30,911,601 shares of $0.001 par value Common Stock outstanding.


 




SARATOGA RESOURCES, INC.


FORM 10-Q


INDEX


 

 

Page No.

PART I    FINANCIAL INFORMATION

 3

 

 

 

ITEM 1.   Financial Statements (Unaudited)

3

 

 Consolidated Balance Sheets as of March 31, 2013 and December 31, 2012

3

 

 Consolidated Statements of Operations and Comprehensive Income for the three months ended March 31, 2013 and 2012

4

 

 Consolidated Statements of Cash Flows for the three months ended March 31, 2013 and 2012

5

 

 Notes to Consolidated Financial Statements

6

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

11

ITEM 3.  Quantitative and Qualitative Disclosures About Market Risk

19

ITEM 4.  Controls and Procedures

20

 

 

 

PART II  OTHER INFORMATION

21

 

 

 

ITEM 6.  Exhibits

21





2




PART I - FINANCIAL INFORMATION


ITEM 1

Financial Statements


SARATOGA RESOURCES, INC.

CONSOLIDATED BALANCE SHEETS

(Unaudited)

 

 

 

 

 

March 31,

 

December 31,

 

2013

 

2012

ASSETS

 

 

 

 

 

 

 

 

 

 

 

Current assets:

 

 

 

 

 

Cash and cash equivalents

$

21,997,531 

 

$

32,302,313 

Accounts receivable

 

10,166,005 

 

 

12,430,158 

Prepaid expenses and other

 

659,106 

 

 

1,268,971 

Derivative asset

 

157,183 

 

 

Other current asset

 

150,000 

 

 

150,000 

Total current assets

 

33,129,825 

 

 

46,151,442 

 

 

 

 

 

 

Property and equipment:

 

 

 

 

 

Oil and gas properties - proved (successful efforts method)

 

268,047,053 

 

 

260,916,084 

Other

 

802,732 

 

 

795,138 

 

 

268,849,785 

 

 

261,711,222 

Less: Accumulated depreciation, depletion and amortization

 

(86,848,766)

 

 

(81,640,272)

Total property and equipment, net

 

182,001,019 

 

 

180,070,950 

 

 

 

 

 

 

Deferred tax asset, net

 

8,986,822 

 

 

8,499,575 

Other assets, net

 

20,040,370 

 

 

19,929,394 

Total assets

$

244,158,036 

 

$

254,651,361 

 

 

 

 

 

 

LIABILITIES AND STOCKHOLDERS' EQUITY

 

 

 

 

 

 

 

 

 

 

 

Current liabilities:

 

 

 

 

 

Accounts payable

$

3,457,324 

 

$

7,259,244 

Revenue and severance tax payable

 

5,315,337 

 

 

6,129,867 

Accrued liabilities

 

5,735,078 

 

 

10,787,044 

Derivative liabilities – short term

 

 

 

171,086 

Short-term notes payable

 

 

 

373,360 

Asset retirement obligation – current

 

 

 

256,200 

Total current liabilities

 

14,507,739 

 

 

24,976,801 

 

 

 

 

 

 

Long-term liabilities:

 

 

 

 

 

Asset retirement obligation

 

17,400,201 

 

 

16,815,736 

Long-term debt, net of unamortized discount of $1,986,188 and $2,104,106, respectively

 

150,513,812 

 

 

150,395,894 

Total long-term liabilities

 

167,914,013 

 

 

167,211,630 

 

 

 

 

 

 

Commitment and contingencies (see notes)

 

 

 

 

 

 

 

 

 

 

 

Stockholders' equity:

 

 

 

 

 

Common stock, $0.001 par value; 100,000,000 shares authorized 30,911,601 and 30,905,101 shares issued and outstanding at March 31, 2013 and December 31, 2012, respectively

 

30,912 

 

 

30,905 

Additional paid-in capital

 

77,313,431 

 

 

77,140,451 

Accumulated other comprehensive loss

 

(9,326)

 

 

(171,086)

Retained deficit

 

(15,598,733)

 

 

(14,537,340)

 

 

 

 

 

 

Total stockholders' equity

 

61,736,284 

 

 

62,462,930 

 

 

 

 

 

 

Total liabilities and stockholders' equity

$

244,158,036 

 

$

254,651,361 


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



3





SARATOGA RESOURCES, INC.

CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME

(Unaudited)


 

For the Three Months Ended

 

March 31,

 

2013

 

2012

Revenues:

 

 

 

 

 

Oil and gas revenues

$

19,261,901 

 

$

19,343,680 

Oil and gas hedging

 

(648,380)

 

 

Other revenues

 

119,675 

 

 

874,248 

 

 

 

 

 

 

Total revenues

 

18,733,196 

 

 

20,217,928 

 

 

 

 

 

 

Operating Expense:

 

 

 

 

 

Lease operating expense

 

4,558,833 

 

 

4,570,699 

Workover expense

 

261,262 

 

 

1,471,468 

Exploration expense

 

168,284 

 

 

57,396 

Loss on plugging and abandonment

 

 

 

1,612,290 

Dry hole costs

 

 

 

89,874 

Depreciation, depletion and amortization

 

5,208,494 

 

 

4,937,152 

Accretion expense

 

638,097 

 

 

555,504 

General and administrative

 

2,103,534 

 

 

2,746,483 

Severance taxes

 

2,091,054 

 

 

1,680,879 

 

 

 

 

 

 

Total operating expenses

 

15,029,558 

 

 

17,721,745 

 

 

 

 

 

 

Operating income

 

3,703,638 

 

 

2,496,183 

 

 

 

 

 

 

Other income (expense):

 

 

 

 

 

Interest income

 

6,080 

 

 

3,316 

Interest expense

 

(5,222,942)

 

 

(4,411,111)

 

 

 

 

 

 

Total other expense

 

(5,216,862)

 

 

(4,407,795)

 

 

 

 

 

 

Net loss before reorganization expenses and income taxes

 

(1,513,224)

 

 

(1,911,612)

 

 

 

 

 

 

Reorganization expenses

 

2,319 

 

 

43,205 

 

 

 

 

 

 

Net loss before income taxes

 

(1,515,543)

 

 

(1,954,817)

 

 

 

 

 

 

Income tax benefit

 

(454,150)

 

 

(735,743)

 

 

 

 

 

 

Net income loss

$

(1,061,393)

 

$

(1,219,074)

 

 

 

 

 

 

Other Comprehensive income (loss)

 

 

 

 

 

Unrealized gain on derivative instruments

 

161,760 

 

 

Total comprehensive income (loss)

$

(899,633)

 

$

(1,219,074)

 

 

 

 

 

 

Net loss per share:

 

 

 

 

 

Basic

$

(0.03)

 

$

(0.04)

Diluted

$

(0.03)

 

$

(0.04)

 

 

 

 

 

 

Weighted average number of common shares outstanding:

 

 

 

 

 

Basic

 

30,911,023 

 

 

27,114,972 

Diluted

 

30,911,023 

 

 

27,114,972 



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




4





SARATOGA RESOURCES, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

 

 

For the Three Months Ended

 

March 31,

 

2013

 

2012

Cash flows from operating activities:

 

 

 

 

 

Net loss

$

(1,061,393)

 

$

(1,219,074)

Adjustments to reconcile net loss to net cash provided by operating activities:

 

 

 

 

 

Depreciation, depletion and amortization

 

5,208,494 

 

 

4,937,152 

Accretion expense

 

638,097 

 

 

555,504 

Amortization of debt issuance costs

 

320,870 

 

 

216,469 

Amortization of debt discount

 

117,918 

 

 

85,007 

Dry hole costs

 

 

 

89,874 

Stock-based compensation

 

163,042 

 

 

261,783 

Loss on plugging and abandonment

 

 

 

1,612,290 

Deferred tax benefit

 

(487,247)

 

 

(768,243)

Unrealized gain on hedges

 

(166,509)

 

 

Changes in operating assets and liabilities:

 

 

 

 

 

Accounts receivable

 

2,264,153 

 

 

(850,178)

Prepaids and other

 

609,865 

 

 

322,907 

Accounts payable

 

(4,380,931)

 

 

(556,757)

Revenue and severance tax payable

 

(814,530)

 

 

7,118 

Payments to settle asset retirement obligations

 

(309,832)

 

 

(705,462)

Accrued liabilities

 

(5,126,160)

 

 

(3,105,187)

Net cash (used in) provided by operating activities

 

(3,024,163)

 

 

883,203 

 

 

 

 

 

 

Cash flows from investing activities:

 

 

 

 

 

Additions to oil and gas property

 

(6,477,765)

 

 

(4,029,778)

Additions to other property and equipment

 

(7,594)

 

 

(10,446)

Other assets

 

(431,845)

 

 

(196,368)

Net cash used in investing activities

 

(6,917,204)

 

 

(4,236,592)

 

 

 

 

 

 

Cash flows from financing activities:

 

 

 

 

 

Proceeds from issuance of common stock

 

9,945 

 

 

2,576,950 

Repayment of short-term notes payable

 

(373,360)

 

 

(344,256)

Net cash (used in) provided by financing activities

 

(363,415)

 

 

2,232,694 

 

 

 

 

 

 

Net increase (decrease) in cash and cash equivalents

 

(10,304,782)

 

 

(1,120,695)

Cash and cash equivalents - beginning of period

 

32,302,313 

 

 

15,874,680 

Cash and cash equivalents - end of period

$

21,997,531 

 

$

14,753,985 

 

 

 

 

 

 

Supplemental disclosures of cash flow information:

 

 

 

 

 

Cash paid for income taxes

$

33,097 

 

$

Cash paid for interest

 

9,541,508 

 

 

7,485,332 

 

 

 

 

 

 

Non-cash investing and financing activities:

 

 

 

 

 

Unrealized gain on derivative instruments

$

161,760 

 

$

Accounts payable for oil and gas additions

 

579,019 

 

 

2,565,795 

Accrued liabilities for oil and gas additions

 

74,185 

 

 

355,243 


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



5





SARATOGA RESOURCES, INC.

Notes to Consolidated Financial Statements

March 31, 2013

(Unaudited)


NOTE 1 – ORGANIZATION AND BASIS OF PRESENTATION


Organization


Saratoga Resources, Inc. (“Saratoga” or the “Company”) is an independent oil and natural gas company engaged in the acquisition, development, exploitation and production of natural gas and crude oil properties.


Financial Statements Presented


The accompanying unaudited financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) for interim financial information and with the instructions to Form 10-Q.  They do not include all of the information and footnotes required by accounting principles generally accepted in the United States of America for a complete financial presentation. In the opinion of management, all adjustments, consisting only of normal recurring adjustments, considered necessary for a fair presentation, have been included in the accompanying unaudited financial statements. Operating results for the periods presented are not necessarily indicative of the results that may be expected for the full year.


The Company utilizes the successful efforts method of accounting for oil and gas producing activities.


These financial statements should be read in conjunction with the financial statements and footnotes which are included as part of the Company’s Form 10-K for the year ended December 31, 2012.


Reclassifications of Prior Period Statements


Certain reclassifications of prior period consolidated financial statement balances have been made to conform to current reporting practices.


Concentration of Credit Risk


Financial instruments that potentially subject the Company to a concentration of credit risk include cash, cash equivalents and any marketable securities. The Company had cash deposits of approximately $21.7 million in excess of FDIC insured limits at the period end. The Company has not experienced any losses on its deposits of cash and cash equivalents.


NOTE 2 – DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES


Objective and Strategies for Using Commodity Derivative Instruments


The Company periodically enters into commodity derivative instruments, primarily fixed price swaps, to manage its exposure to oil and gas price volatility. The oil and gas reference prices upon which the price hedging instruments are based reflect various market indices that have a high degree of historical correlation with actual prices received by the Company. The fixed price swap contracts entitle us (floating price payor) to receive settlement from the counterparty (fixed price payor) for each calculation period in amounts, if any, by which the settlement price for the scheduled trading days applicable for each calculation period is less than the fixed strike price. We would pay the counterparty if the settlement price for the scheduled trading days applicable for each calculation period is more than the fixed strike price. The amount payable by us, if the floating price is above the fixed price, is the product of the notional quantity per calculation period and the excess of the floating price over the fixed price with respect to each calculation period. The amount payable by the counterparty, if the floating price is below the fixed price, is the product of the notional quantity per calculation period and the excess of the fixed price over the floating price with respect to each calculation period.


While these instruments mitigate the cash flow risk of future reductions in commodity prices, they may also curtail benefits from future increases in commodity prices.


See Note 3 – “Fair Value Measurements” for a discussion of the methods and assumptions used to estimate the fair values of our commodity derivative instruments.



6





The Company utilizes hedge accounting for our commodity derivative instruments, which are designated as cash flow hedges.


Counterparty Credit Risk


Commodity derivative instruments expose us to counterparty credit risk.  Our commodity derivative instruments are with two and one counterparties at March 31, 2013 and December 31, 2012, respectively.  We monitor and manage our level of financial exposure with respect to the counterparties we use.  Our commodity derivative contracts are executed under master agreements which allow us, in the event of default, to elect early termination of all contracts with the defaulting counterparty.  If we choose to elect early termination, all asset and liability positions with the defaulting counterparty would be net settled at the time of election.


We monitor the creditworthiness of our commodity derivatives counterparties. However, we are not able to predict sudden changes in counterparties’ creditworthiness. In addition, even if such changes are not sudden, we may be limited in our ability to mitigate an increase in counterparty credit risk.


As of March 31, 2013, the Company had the following hedge contracts outstanding:


 

 

Beginning

 

Ending

 

Fixed

 

Total

Instrument

 

Date

 

Date

 

Price

 

Bbls

Fixed Price Swap

 

April 2013

 

December 2013

 

$

106.82 

 

137,500 

Fixed Price Swap

 

April 2013

 

March 2014

 

$

109.20 

 

159,500 

 

 

 

 

 

 

 

 

 

297,000 


The following table presents the fair value of the Company’s commodity derivative instruments at March 31, 2013 and December 31, 2012:


 

 

March 31,

 

December 31,

Description

 

2013

 

2012

Current Assets:

 

 

 

 

 

 

Commodity derivatives

 

$

157,183 

 

$

 

 

$

157,183 

 

$

Current liabilities:

 

 

 

 

 

 

Commodity derivatives

 

$

 

$

171,086 

 

 

$

 

$

171,086 


NOTE 3 – FAIR VALUE MEASUREMENTS


The Company has various financial instruments that are measured at fair value in the financial statements, including commodity derivatives.  The Company’s financial assets and liabilities are measured using input from three levels of the fair value hierarchy. A financial asset or liability classification within the hierarchy is determined based on the lowest level input that is significant to the fair value measurement.  The three levels are as follows:


Level 1 – Inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the Company has the ability to access at the measurement date.


Level 2 – Inputs include quoted prices for similar assets and liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the assets or liability and inputs that are derived principally from, or corroborated by, observable market data by correlation or other means (market corroborated inputs).


Level 3 – Unobservable inputs that reflect the Company’s judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists.  The Company develops these inputs based on the best information available, using internal and external data.




7




The following table presents the Company’s assets and liabilities recognized in the balance sheet and measured at fair value on a recurring basis as of March 31, 2013 and December 31, 2012:


 

 

Level 1

 

Level 2

 

Level 3

 

Total

March 31, 2013

 

 

 

 

 

 

 

 

 

 

 

 

Assets:

 

 

 

 

 

 

 

 

 

 

 

 

Commodity derivatives

 

$

 

$

157,183 

 

$

 

$

157,183 

 

 

$

 

$

157,183 

 

$

 

$

157,183 

 

 

 

 

 

 

 

 

 

 

 

 

 

December 31, 2012

 

 

 

 

 

 

 

 

 

 

 

 

Liabilities:

 

 

 

 

 

 

 

 

 

 

 

 

Commodity derivatives

 

$

 

$

171,086 

 

 

 

$

171,086 

 

 

$

 

$

171,086 

 

 

 

$

171,086 


The Company uses various commodity derivative instruments, including fixed price swaps.  We consider the fair value of our commodity derivative instruments to be level 2 on the fair value hierarchy.  The fair value of commodity derivatives is determined using adjusted exchange prices, prices provided by brokers or pricing service companies that are all corroborated by market data.


NOTE 4 – OTHER ASSETS


Other assets consist of the following:


 

March 31,

 

December 31,

 

2013

 

2012

Site specific trust accounts - P&A escrow

$

5,485,049 

 

$

5,279,084 

Debt issuance cost, net

 

5,452,066 

 

 

5,728,755 

Restricted cash – P&A bond

 

8,873,497 

 

 

8,873,497 

Other

 

229,758 

 

 

48,058 

 

$

20,040,370 

 

$

19,929,394 


Site Specific Trust Accounts – P&A Escrow


The Company maintains an escrow agreement that has been established for the purpose of assuring maintenance and administration of a performance bond which secures certain plugging and abandonment obligations assumed in the acquisition of oil and gas properties in certain fields.  Changes in the escrow accounts reflect additional contributions and interest earned during 2013.  See Note 8 – “Asset Retirement Obligations”.


Debt Issuance Costs, Net


The Company capitalizes certain debt issuance costs and amortizes those costs as additional interest expense over the lives of the associated debt.  Net debt issuance costs at March 31, 2013 and December 31, 2012 reflect the issuance of the 2016 Notes in December 2012 and July 2011.  See Note 9 – “Debt”.


Restricted Cash – P&A Bond


Restricted Cash – P&A Bond consists of cash collateral held in escrow to assure maintenance and administration of performance bonds which secures certain plugging and abandonment obligations imposed by state law.  The cash collateral is reflected as a long term asset to correspond with the expected timing of the related asset retirement obligation liability.  See Note 8 – “Asset Retirement Obligations”.


NOTE 5 – STOCK-BASED COMPENSATION EXPENSE


The Company periodically grants restricted stock and stock options to employees, directors and consultants.  The Company is required to make estimates of the fair value of the related instruments and recognize expense over the period benefited, usually the vesting period.




8




Compensation Plan


In September 2011, the Company’s board of directors adopted, and in June 2012 the Company’s stockholders approved, the Saratoga Resources, Inc. 2011 Omnibus Equity Plan (the “2011 Plan”).  The 2011 Plan reserves a total of 3,000,000 shares for issuance to eligible employees, officers, directors and other service providers pursuant to grants of options, restricted stock, performance stock and other equity based compensation agreements.


Stock Option Activity


The following table summarizes information about stock option activity and related information for the three months ended March 31, 2013:


 

Number of

Shares

Underlying

Options

 

Weighted

Average

Exercise

Price per

Share

 

Weighted

Average

Grant

Date Fair

Value per

Share

 

Weighted

Average

Remaining

Contractual

Life (in

Years)

 

Aggregate

Intrinsic

Value (1)

Outstanding at December 31, 2012

 

784,000 

 

$

3.66 

 

$

3.65 

 

6.5 

 

$

474,240 

Granted

 

 

 

 

 

 

 

 

Exercised

 

(6,500)

 

 

1.53 

 

 

1.53 

 

 

 

Forfeited

 

 

 

 

 

 

 

 

Outstanding at March 31, 2013

 

777,500 

 

$

3.68 

 

$

3.67 

 

6.3 

 

$

175,275 

Exercisable at March 31, 2013

 

551,666 

 

$

3.23 

 

$

3.22 

 

6.4 

 

$

160,208 


(1)

The intrinsic value of an option is the amount by which the market value of our common stock at the indicated date, or at the time of exercise, exceeds the exercise price of the option. On March 28, 2013, the last reported sales price of our common stock on the NYSE MKT was $2.66 per share.


Share-Based Compensation Expense


The following table reflects share-based compensation recorded by the Company for the three months ended March 31, 2013 and 2012:


 

Three Months Ended

March 31,

 

2013

 

2012

Share-based compensation expense included in reported net income

$

163,042 

 

$

261,783 

Basic earnings per share effect of share-based compensation expense

$

(0.01)

 

$

(0.01)


As of March 31, 2013, total unrecognized stock-based compensation expense related to non-vested stock options was $0.4 million. The unrecognized expense is expected to be recognized over a weighted average period of 0.5 years.


NOTE 6 – EQUITY


Common Stock Activity


In January 2013, the Company received gross proceeds of $9,945 for 6,500 stock options exercised at $1.53 a share.




9




Warrant Activity


The following table summarizes information about stock warrant activity and related information for the three months ended March 31, 2013:


 

Number of

Shares

Underlying

Warrants

 

Weighted

Average

Exercise

Price per

Share

 

Weighted

Average

Grant

Date Fair

Value per

Share

 

Weighted

Average

Remaining

Contractual

Life (in

Years)

 

Aggregate

Intrinsic

Value (1)

Outstanding at December 31, 2012

 

572,628 

 

$

5.14 

 

$

3.22 

 

0.8 

 

$

132,900 

Granted

 

 

 

 

 

 

 

 

Exercised

 

 

 

 

 

 

 

 

Forfeited

 

 

 

 

 

 

 

 

Outstanding at March 31, 2013

 

572,628 

 

$

5.14 

 

$

3.22 

 

0.6 

 

$

80,500 

Exercisable at March 31, 2013

 

572,628 

 

$

5.14 

 

$

3.22 

 

0.6 

 

$

80,500 


(1)

The intrinsic value of a warrant is the amount by which the market value of our common stock at the indicated date, or at the time of exercise, exceeds the exercise price of the warrant. On March 28, 2013, the last reported sales price of our common stock on the NYSE MKT was $2.66 per share.


NOTE 7 – EARNINGS (LOSS) PER SHARE


A reconciliation of the components of basic and diluted net loss per common share is presented in the tables below:


 

For the Three Months Ended March 31,

 

2013

 

2012

 

Income

(Loss)

 

Weighted

Average

Common

Shares

Outstanding

 

Per Share

 

Income

(Loss)

 

Weighted

Average

Common

Shares

Outstanding

 

Per Share

Basic:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Loss attributable to common stock

$

(1,061,393)

 

30,911,023

 

$

(0.03)

 

$

(1,219,074)

 

27,114,972

 

$

(0.04)

Effect of Dilutive Securities:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Stock options and other

 

 

 

-

 

 

 

 

 

 

 

-

 

 

 

Diluted:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Loss attributable to common

stock, including assumed conversions

$

(1,061,393)

 

30,911,023

 

$

(0.03)

 

$

(1,219,074)

 

27,114,972

 

$

(0.04)


NOTE 8 – ASSET RETIREMENT OBLIGATIONS


The Company accounts for plugging and abandonment costs in accordance with FASB Accounting Standards Codification 410-20, Accounting for Asset Retirement Obligations.


A reconciliation of the beginning and ending aggregate carrying amount of asset retirement obligations are as follows:


Balance at December 31, 2012

$

17,071,936 

Accretion expense

 

638,097 

Additions

 

Revisions

 

Settlements

 

(309,832)

Balance at March 31, 2013

$

17,400,201 


NOTE 9 – DEBT


Long-term debt consists of the following:


 

March 31,

 

December 31,

 

2013

 

2012

12.5% Senior Secured Notes due 2016

$

152,500,000 

 

$

152,500,000 

Less unamortized discount

 

1,986,188 

 

 

2,104,106 

 

$

150,513,812 

 

$

150,395,894 




10




2016 Notes


In July 2011, the Company and the several wholly-owned subsidiaries of the Company (the “Guarantors”) entered into a Purchase Agreement with Imperial Capital, LLC (the “Initial Purchaser”), relating to the issuance and sale of $127.5 million in aggregate principal amount of the Company’s 12.5% Senior Secured Notes due 2016 (the “2016 Notes”).  The 2016 Notes were sold at 98.221% of par. The 2016 Notes were offered and sold in a transaction exempt from the registration requirements of the Securities Act. The 2016 Notes were resold to qualified institutional buyers in reliance on Rule 144A of the Securities Act and to persons outside of the U.S. pursuant to Regulation S.


In December 2012, the Company and the Guarantors entered into another Purchase Agreement with the Initial Purchaser, relating to the issuance and sale of an additional $25 million in aggregate principal amount of the Company’s 2016 Notes.  The 2016 Notes were sold at 98.58% of par.  The 2016 Notes were offered and sold in a transaction exempt from the registration requirements of the Securities Act.  The 2016 Notes were resold to qualified institutional buyers in reliance on Rule 144A of the Securities Act and to persons outside of the U.S. pursuant to Regulation S.


The 2016 Notes were issued pursuant to an indenture, dated July 12, 2011 (the “Base Indenture”), among the Company, the Guarantors named therein and The Bank of New York Mellon Trust Company, N.A., as trustee (the “Trustee”) and as collateral agent (the “Collateral Agent”) and, with respect to the 2016 Notes issued in 2012, a First Supplemental Indenture, dated December 4, 2012 (the “Supplemental Indenture” and, together with the Base Indenture, the “Indenture”). The 2016 Notes are the senior secured obligations of the Company and are fully and unconditionally guaranteed on a senior secured basis by the Guarantors and will rank equally in right of payment with the Company’s and the Guarantors’ existing and future senior indebtedness.


The 2016 Notes mature on July 1, 2016, and interest is payable on the 2016 Notes on January 1 and July 1 of each year, commencing January 1, 2012.


The Indenture includes customary events of default and places restrictions on the Company and certain of its subsidiaries with respect to additional indebtedness, liens, dividends and other payments to shareholders, repurchases or redemptions of the Company’s common stock, redemptions of senior notes, investments, acquisitions, mergers, asset dispositions, transactions with affiliates, hedging transactions and other matters.


The Company has the option to redeem all or a portion of the 2016 Notes at any time on or after January 1, 2014 at the redemption prices specified in the Indenture plus accrued and unpaid interest. The Company may also redeem the 2016 Notes, in whole or in part, at a “make-whole” redemption price specified in the Indenture, plus accrued and unpaid interest, at any time prior to January 1, 2014. Within each twelve-month period commencing on July 12, 2012 and ending January 1, 2014, the Company may also redeem up to 10% of the aggregate principal amount of the 2016 Notes at a price equal to 106.25% of the principal amount thereof, plus accrued and unpaid interest.  In addition, the Company may redeem up to 35% of the 2016 Notes prior to January 1, 2014 under certain circumstances with the net cash proceeds from certain equity offerings and at a price equal to 112.5% of the principal amount thereof, plus accrued and unpaid interest.


NOTE 10 – COMMITMENTS AND CONTINGENCIES


In March 2013, we bid on, and were the apparent high bidder relative to, four leases, with seismic maps included, totaling 19,814 acres in the Central Gulf of Mexico Lease Sale 227.  The acreage is in the shallow Gulf of Mexico shelf in water depths of 13 to 77 feet.  Two of the leases are in the Vermilion area and two of the leases are in the Ship Shoal area.  Final award of the leases is subject to BOEMRE review.  Lease bonuses on the prospects total $880,000 and first year annual rentals total $138,698.  Additionally, assuming final award of the leases, we will pay a prospect fee of $450,000 to a third party consultant.


From time to time the Company may become involved in litigation in the ordinary course of business. At March 31, 2013, the Company’s management was not aware, and as of the date of this report is not aware, of any such litigation that could have a material adverse effect on its results of operations, cash flows or financial condition.


The Company, as an owner or lessee and operator of oil and gas properties, is subject to various federal, state and local laws and regulations relating to discharge of materials into, and protection of, the environment. These laws and regulations may, among other things, impose liability on the lessee under an oil and gas lease for the cost of pollution clean-up resulting from operations and subject the lessee to liability for pollution damages. In some instances, the Company may be directed to suspend or cease operations in the affected area. The Company maintains insurance coverage, which it believes is customary in the industry, although the Company is not fully insured against all environmental risks. The Company is not aware of any environmental claims existing as of March 31, 2013, which have not been provided for, covered by insurance or otherwise have a material impact on its financial position or results of operations. There can be no assurance, however, that current regulatory requirements will not change, or past non-compliance with environmental laws will not be discovered on the Company’s properties.



11





ITEM 2

MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS


Forward-Looking Information


This Form 10-Q quarterly report of Saratoga Resources, Inc. (the “Company”) for the three months ended March 31, 2013, contains certain 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, which are intended to be covered by the safe harbors created thereby.  To the extent that there are statements that are not recitations of historical fact, such statements constitute forward-looking statements that, by definition, involve risks and uncertainties.  In any forward-looking statement, where we express an expectation or belief as to future results or events, such expectation or belief is expressed in good faith and believed to have a reasonable basis, but there can be no assurance that the statement of expectation or belief will be achieved or accomplished.


The actual results or events may differ materially from those anticipated and as reflected in forward-looking statements included herein. Factors that may cause actual results or events to differ from those anticipated in the forward-looking statements included herein include the Risk Factors described in Item 1A of our Form 10-K for the year ended December 31, 2012.


Readers are cautioned not to place undue reliance on the forward-looking statements contained herein, which speak only as of the date hereof. We believe the information contained in this Form 10-Q to be accurate as of the date hereof. Changes may occur after that date, and we will not update that information except as required by law in the normal course of our public disclosure practices.


Additionally, the following discussion regarding our financial condition and results of operations should be read in conjunction with the financial statements and related notes contained in Item 1 of Part 1 of this Form 10-Q, as well as the Risk Factors in Item 1A and the financial statements in Item 8 of Part II of our Form 10-K for the fiscal year ended December 31, 2012.


Overview


We are an independent oil and natural gas company engaged in the acquisition, development, exploitation, exploration and production of crude oil and natural gas properties.  Our principal properties were acquired in July 2008 and are located in the transitional coastline and protected in-bay environment on parish and state leases of south Louisiana.


At March 31, 2013, we operated or had interests in 105 producing wells and our principal properties covered approximately 32,027 gross/net acres, substantially all of which were held by production without near-term lease expirations, across 12 fields in the transitional coastline and protected in-bay environment on parish and state leases in south Louisiana. We own approximately 100% working interest in all our properties, with the only exceptions being a handful of wells where we have either a net profits interest or an overriding royalty interest. Our net revenue interests in our properties range from 62% to 88%, with our average net revenue interest on a net acreage leasehold basis being approximately 75%. We operate over 97% of the wells that comprise our PV-10, enabling us to effectively exercise management control of our operating costs, capital expenditures and the timing and method of development of our properties.


2013 Developments


Drilling and Development Activities


Drilling and development and infrastructure project operations to date in 2013 are summarized as follows:


Development Drilling.  During the three months ended March 31, 2013, we completed the SL 195QQ-209 “Buddy” well in Grand Bay Field and drilled and completed the MP 47 SL 195QQ-25 “Roux Toux” well in Main Pass 47 Field.


Exploratory Drilling.  We did not drill any exploratory wells during the three months ended March 31, 2013.


Recompletion and Workover Program.  During the three months ended March 31, 2013, we invested $0.3 million in 3 recompletions, all of which were successful, and an additional $0.3 million on 2 workovers, 1 of which was still in progress at the end of the quarter.


Infrastructure Program.  During the three months ended March 31, 2013, we invested $0.8 million in infrastructure improvements and additions to support existing production and anticipated increases in production, primarily in Grand Bay Field.




12




Drilling and Development Plans.  We have an extensive inventory of drilling opportunities, including numerous proved behind pipe and proved undeveloped opportunities as well as a number of exploratory opportunities.  Our near term development plans are focused on proved undeveloped opportunities and conversion of PDNP opportunities.


For the three months ended March 31, 2013, we had approximately 105 gross (104 net) wells in production.


Effects of Hurricane Isaac


As of March 31, 2013, we had completed all ongoing projects relating to restoration of production and repairs arising from the effects of Hurricane Isaac.


Compensation


As of March 31, 2013, total compensation cost related to unvested stock option awards not yet recognized in earnings was approximately $0.4 million, which is expected to be recognized over a weighted average period of approximately 0.5 years.


Share Issuances for Cash


During the three months ended March 31, 2013, we sold 6,500 shares of common stock for $9,945 pursuant to the exercise of outstanding stock options.


Hedging Activities


As of March 31, 2013, we had in place fixed price swaps covering an aggregate of 297,000 barrels of oil over the period beginning April 1, 2013 and ending March 31, 2014, at prices ranging from $106.82 to $109.20 per barrel.


Gulf of Mexico Shelf Acreage  


In March 2013, we bid on, and were the apparent high bidder relative to, four leases, with seismic maps included, totaling 19,814 acres in the Central Gulf of Mexico Lease Sale 227.  The acreage is in the shallow Gulf of Mexico shelf in water depths of 13 to 77 feet.  Two of the leases are in the Vermilion area and two of the leases are in the Ship Shoal area.  Final award of the leases is subject to BOEMRE review.  Lease bonuses on the prospects total $880,000 and first year annual rentals total $138,698. Additionally, assuming final award of the leases, we will pay a prospect fee of $450,000 to a third party consultant.


Results of Operations


Oil and Gas Revenue


Oil and gas revenue for the quarter ended March 31, 2013 stayed flat at $19.3 million.


The following table discloses the oil and gas sales revenues, net oil and natural gas production volumes and average sales prices for the three months ended March 31, 2013 and 2012:



 

Three Months Ended

March 31,

 

 

2013

 

 

2012

Revenues

 

 

 

 

 

 

 

Oil

 

$

17,388,900

 

 

$

17,130,340

Gas

 

 

1,873,001

 

 

 

2,213,340

Total oil and gas revenues

 

$

19,261,901

 

 

$

19,343,680

 

 

 

 

 

 

 

 

Production

 

 

 

 

 

 

 

Oil (Bbls)

 

 

156,770

 

 

 

150,744

Gas (Mcf)

 

 

443,346

 

 

 

620,717

Total production (Boe)

 

 

230,661

 

 

 

254,197

 

 

 

 

 

 

 

 

Average sales price

 

 

 

 

 

 

 

Oil (per Bbl)

 

$

110.92

 

 

$

113.64

Gas (per Mcf)

 

 

4.22

 

 

 

3.57

Total average sales price (per Boe)

 

$

83.51

 

 

$

76.10




13




The decrease in production during the quarter was primarily due a curtailment of production due to third party handling issues and a temporary lack of available gas lift gas in Main Pass 25 Field, where production was down 21.5 MBOE compared to the 2012 quarter.  In addition, the QQ24 well in Grand Bay Field was shut-in for five weeks during the drilling of the QQ25 well resulting in a decrease in production of 4.5 MBOE compared to the 2012 quarter.  Also contributing to the production decrease were shut ins due to work associated with infrastructure improvements.  Residual curtailments caused by the lingering effects of Hurricane Isaac also effected production during the 2013 quarter.  The decreases in production were partially offset by new wells that came on production over the last 3 quarters of 2012 and the first quarter of 2013.  At quarter end, all curtailments related to gas lift and third party handling issues in Main Pass 25 field, as well as the residual curtailments associated with Hurricane Isaac had been resolved.


The increase in realized hydrocarbon prices reflects a general strengthening of natural gas prices, partially offset by slight moderation in crude oil prices. We continued to realize a premium to WTI pricing on both our crude oil and natural gas production.


Other Revenues


Other revenues consist principally of (i) a net profits interest attributable to operating the Breton Sound 31 field, for which we receive a percentage of profits, (ii) production handling fees from our Vermilion 16 field, and (iii) during the 2012 period, settlements of lawsuits against the former owners of The Harvest Group LLC and Harvest Oil & Gas, LLC.


Other revenue for the quarter ended March 31, 2013 decreased to $119,675 from $874,248 in the 2012 quarter.  The decrease in other revenue was principally as a result of the one-time nature of lawsuit settlements, totaling $604,591, in the 2012 quarter.


Operating Expenses


Operating expenses decreased by 15.2% to $15.0 million for the quarter ended March 31, 2013 from $17.7 million in the 2012 quarter.  The following table sets forth the components of operating expenses for the 2013 and 2012 quarters:


 

Three Months Ended

 

Three Months Ended

 

March 31, 2013

 

March 31, 2012

 

Total

 

Per Boe

 

Total

 

Per Boe

Lease operating expense

$

4,558,833

 

$

19.76

 

$

4,570,699

 

$

17.98

Workover expense

 

261,262

 

 

1.13

 

 

1,471,468

 

 

5.79

Exploration expense

 

168,284

 

 

0.73

 

 

57,396

 

 

0.23

Loss on plugging and abandonment

 

-

 

 

-

 

 

1,612,290

 

 

6.34

Dry hole costs

 

-

 

 

-

 

 

89,874

 

 

0.35

Depreciation, depletion and amortization

 

5,208,494

 

 

22.58

 

 

4,937,152

 

 

19.42

Accretion expense

 

638,097

 

 

2.77

 

 

555,504

 

 

2.18

General and administrative

 

2,103,534

 

 

9.12

 

 

2,746,483

 

 

10.80

Severance taxes

 

2,091,054

 

 

9.07

 

 

1,680,879

 

 

6.61

 

$

15,029,558

 

$

65.16

 

$

17,721,745

 

$

69.72


The changes in operating expenses were primarily attributable to the factors discussed below.


Lease Operating Expense


Lease operating expenses for the quarter ended March 31, 2013 were essentially flat at $4.6 million as compared to the 2012 quarter, but on a per BOE basis increased 9.9% to $19.76 per BOE from $17.98 per BOE, in the 2012 quarter.


Operating costs in our fields have historically been relatively high due to water handling, the need for gas lift to maintain oil production and due to the need for marine transportation in the shallow water, bay environment.  The increase in lease operating expenses on a per BOE basis for the three month period was primarily attributable to the 9.3% decrease in production volumes and the fixed nature of certain lease operating expenses.


Workover Expense


Workover expense for the quarter ended March 31, 2013 decreased to $261,262 from $1,471,468 in the 2012 quarter.  The change in workover expense was attributable to a decrease in the number of workovers completed during 2013 quarter.




14




Exploration Expense


Exploration expense for the quarter ended March 31, 2013 increased to $168,284 from $57,396 in the 2012 quarter.  Exploration expenses principally relate to delay rentals and field studies related to Grand Bay Field.


Loss on plugging and abandonment


Loss on plugging and abandonment for the three months ended March 31, 2012 totaled $1,612,290 due to costs of plugging and abandoning wells in Little Bay, South Atchafalaya Bay and Crooked Bayou fields that exceeded those estimated in our calculation of asset retirement obligation liabilities.  Four of the wells plugged were the deepest and highest pressure wells in our entire inventory of wells to be plugged.  These wells were orphaned wells on expired leases which we inherited from the previous owners and which have never produced since we have owned the assets.  In addition, several of the wells had unanticipated severe casing damage.  Accordingly, the actual costs incurred in plugging and abandoning these wells was substantially higher than we estimated and would expect to incur in future plugging operations.


Depreciation, Depletion and Amortization (DD&A)


Depreciation, depletion and amortization for the quarter ended March 31, 2013 increased 5.5% to $5,208,494 from $4,937,152 in the 2012 quarter and increased to $22.58 per BOE from $19.42 per BOE in the 2012 quarter.


We utilize the successful efforts method of accounting for oil and gas producing activities.  Under this method, DD&A is computed on the units-of-production method separately on each individual property and includes the accrual of future plugging and abandonment costs.


The increase in DD&A expense and DD&A expense per BOE, during the 2013 quarter was attributable to additional capital expenditures incurred in our development program.


Accretion expense


Accretion expense relating to our asset retirement obligations increased to $638,097 from $555,504 for the quarter ended March 31, 2013 as compared to the 2012 quarter.


The increase in accretion expense was attributable to changes in the anticipated plugging dates and discount rates used in calculating the asset retirement obligation for certain fields.


General and Administrative


General and administrative (“G&A”) expense for the quarter ended March 31, 2013 decreased 23.4% to $2,103,534 from $2,746,483 in the 2012 quarter, and was 15.6% lower on a per BOE basis. The decrease in G&A expense for the quarter was primarily attributable to decreases in head count (reducing salary, wages and benefits approximately $280,000) and stock based compensation (down $98,741).


Severance Taxes


Severance taxes for the quarter ended March 31, 2013 increased to $2,091,054 from $1,680,879 in the 2012 quarter.  The increase was primarily attributable to a reduced number of inactive wells eligible for certain Louisiana severance tax exemptions.


Other Income (Expense), Net


Net other income (expense) increased to $5.2 million in expense for the quarter ended March 31, 2013 from $4.4 million for the 2012 quarter.


The following table sets forth the components of net other income (expenses) for the 2013 and 2012 quarters:


 

Three Months Ended

March 31,

 

2013

 

2012

Interest income

 

6,080 

 

 

3,316 

Interest expense

 

(5,222,942)

 

 

(4,411,111)

 

$

(5,216,862)

 

$

(4,407,795)




15




Interest expense reflects interest incurred on debt under our senior secured notes and our prior term credit agreement and revolving credit agreement. The increase in interest expense was attributable to our placement of an additional $25.0 million in principal amount of senior secured notes in December 2012.


Reorganization Expenses


Reorganization expenses reflect payments to professionals and other fees incurred in connection with our prior Chapter 11 case. Reorganization expenses decreased to $2,319 during the quarter ended March 31, 2013 from $43,205 in the 2012 quarter.  The decrease in reorganization expenses was attributable to our exit from bankruptcy in May 2010.


Income Tax Benefit


For the quarter ended March 31, 2013 we recorded an income tax benefit of $454,150 compared to $735,743 in the 2012 quarter.


Our effective tax rates were different than our federal statutory tax rate due to Louisiana state income taxes associated with income from various locations in which we have operations.  Estimates of future taxable income can be significantly affected by changes in oil and natural gas prices, the timing, amount, and location of future production and future operating expenses and capital costs.


Financial Condition


Liquidity and Capital Resources


Our principal requirements for capital are to fund our day-to-day operations and exploration, development and acquisition activities and to satisfy our contractual obligations, primarily for the payment of interest and repayment of debt.


Since 2009, we have operated without access to a revolving credit facility and have funded operations out of operating cash flow and cash on hand, which funds have been supplemented by our receipt of funds from our April and July 2011 and May 2012 equity capital raises and our December 2012 issuance of senior secured notes described herein.  At March 31, 2013, and continuing as of this writing, we had not yet established a revolving credit facility and continue to evaluate multiple potential options regarding the establishment of such a facility.


We developed, and beginning in 2011 commenced, a layered, multi-faceted development and maintenance program designed to achieve short-, mid- and long-term objectives. Short-term objectives are focused on restoration of shut-in and curtailed production through investments in infrastructure and deferred maintenance and recompletions, workovers and thru-tubing plugbacks each designed to increase or restore production volumes from wells producing below capacity and an inventory of proved developed nonproducing opportunities. Mid-term, following or in conjunction with execution of short-term opportunities, our focus is on the development of an inventory of proved undeveloped opportunities within our inventory of proved undeveloped wells targeting normally pressured oil and gas.  Long-term, following or in conjunction with the execution of our short- and mid-term opportunities, our focus is on continuing development of our reserves and exploratory drilling of deep shelf opportunities.  During 2011, we achieved our principal short-term objectives through substantial investments in infrastructure upgrades.  During 2012 and continuing in the first quarter of 2013, while continuing to advance short-term objectives associated with continual investment in our infrastructure, recompletions and workovers, we focused on our mid-term objectives as reflected in continued investment in our developmental drilling program.


As noted, we have supplemented our cash and liquidity position through a series of equity capital raises during 2011 and 2012, consisting of (1) the receipt of $7.4 million from the sale of common stock and warrants in April 2011, (2) the receipt of $27.3 million from the sale of common stock in July 2011, and (3) the receipt of $18.4 million from the sale of common stock in May 2012. We have utilized the proceeds from the offerings of such stock and warrants to support accelerated investments in our development and maintenance program.


Further, during July 2011, we received $120.9 million of net proceeds from the sale of our 2016 Notes and, during December 2012, we received $23.4 million of net proceeds from the sale of additional 2016 Notes.  Funds received from the July 2011 common stock offering and offering of 2016 Notes were used to repay indebtedness under our prior credit facilities.




16




We believe that our cash flows from operations and cash on hand, including funds received from our equity and note offerings, are sufficient to support our liquidity needs for the next twelve months, including funding all of our current short-term objectives, including investments in planned infrastructure and deferred maintenance, recompletions, workovers and through-tubing plugbacks.  We believe that our cash flows from operations and cash on hand will also be sufficient to pursue our current mid-term objectives relating to development of proved undeveloped opportunities.  Our development of proved undeveloped opportunities is scalable.  Depending upon the results of our short-term development initiatives, ongoing development efforts relating to our proved undeveloped opportunities and any further capital commitments, we may accelerate our planned development of proved undeveloped opportunities or otherwise adjust the nature or rate of our development program.  Pursuit of our long-term plans for exploratory drilling of deep shelf prospects is expected to require funding in excess of our current resources and projected operating cash flow and to be dependent upon results attained by other operators that are currently pioneering ultra-deep drilling in the trend within which our ultra-deep prospects are located.  At March 31, 2013, we were continuing to monitor developments within the ultra-deep trend and to be engaged in discussions with various potential partners relative to the potential exploration of our ultra-deep prospects.  We presently lack the financial resources to carry our proportionate share of the anticipated exploration and development costs associated with such joint venture and will be required to secure additional financing to support our share of such costs and maintain our interest in such ultra-deep prospects.  To that end, we expect to seek partners to enter into arrangements that will provide the necessary funding to pay some, or all, of our share of the joint venture costs with the effect of reducing our interest in the joint venture. We presently have no commitments to provide funding to cover our share of such costs.


Unexpected declines in commodity prices or production levels, or failures in achieving production increases through short- and mid-term development plans, could result in our inability to support our operations and drilling and development plans.


Further, as noted above, in order to further supplement our liquidity and increase our operating flexibility, we intend to enter into a new revolving credit facility.  To that end, we continue to pursue efforts to secure a definitive agreement to provide a revolving credit facility but, as of this writing, have not yet established such a facility and there can be no assurance that we will be successful in establishing a revolving credit facility on terms that we consider to be favorable or at all.


Cash, Cash Flows and Working Capital


We had a cash balance of $22.0 million and working capital of $18.6 million at March 31, 2013 as compared to a cash balance of $32.3 million and working capital of $21.2 million at December 31, 2012. The decrease in cash on hand was primarily attributable to the interest payment on our 2016 notes made in January and investments in our development program. The decrease in our working capital was primarily attributable to utilization of cash to fund our development program.


Operations used cash flow of $3.0 million for the three months ended March 31, 2013 as compared to providing $0.9 million for the three months ended March 31, 2012. The change in operating cash flows during 2013 was principally attributable changes in our operating assets and liabilities, in particular reductions in accrued liabilities reflecting payment of accrued interest on our 2016 Notes in January 2013.


Investing activities used cash totaling $6.9 million during the three months ended March 31, 2013 as compared to cash used in investing of $4.2 million during the three months ended March 31, 2012.  We incurred $7.1 million and $7.0 million for oil and gas development activities for the three months ended March 31, 2013 and 2012, respectively.  The increase in cash used in investing activities during 2013 was attributable primarily to the fact that a large percentage of development costs were included in accounts payable and accrued liabilities at the end of the 2012 quarter.


Financing activities used cash flows of $0.4 million during the three months ended March 31, 2013 as compared to cash provided by financing activities of $2.2 million during the three months ended March 31, 2012. Cash flows used by financing activities during the 2013 period related to repayment of our short term debt.


Debt and Non-Current Liabilities


At March 31, 2013, we had $150.5 million of indebtedness outstanding (reflecting a $2.0 million debt discount) compared to $150.4 million of indebtedness outstanding at December 31, 2012 (reflecting a $2.1 million debt discount), consisting of $152.5 million under our 2016 Notes.


The principal terms of our debt and non-current liabilities at March 31, 2013 were as follows:


2016 Notes.  In July 2011, we issued $127.5 million of our 2016 Notes and retired all obligations owing under our prior credit facilities and all outstanding letter of credit obligations.   In December 2012, we issued an additional $25.0 million of our 2016 Notes.




17




The 2016 Notes are our senior secured obligations and are fully and unconditionally guaranteed on a senior secured basis by the Guarantors and will rank equally in right of payment with our and the Guarantors’ existing and future senior indebtedness. The 2016 Notes mature on July 1, 2016, and interest is payable on the 2016 Notes on January 1 and July 1 of each year, commencing January 1, 2012.


We have the option to redeem all or a portion of the 2016 Notes at any time on or after January 1, 2014 at the redemption prices specified in the Indenture pursuant to which the 2016 Notes were issued plus accrued and unpaid interest. We may also redeem the 2016 Notes, in whole or in part, at a “make-whole” redemption price specified in the Indenture, plus accrued and unpaid interest, at any time prior to January 1, 2014. Within each twelve-month period commencing on July 12, 2012 and ending January 1, 2014, we may also redeem up to 10% of the aggregate principal amount of the 2016 Notes at a price equal to 106.25% of the principal amount thereof, plus accrued and unpaid interest.  In addition, we may redeem up to 35% of the 2016 Notes prior to January 1, 2014 under certain circumstances with the net cash proceeds from certain equity offerings and at a price equal to 112.5% of the principal amount thereof, plus accrued and unpaid interest.


Capital Expenditures and Commitments


Our capital spending for the three months ended March 31, 2013 was $7.1 million relating primarily to development of our oil and gas properties, including completion of 3 recompletions and investments in multiple infrastructure projects.


As of April 1, 2013, we anticipate that our capital budget for the remaining three quarters of 2013 will be approximately$37.1 million, excluding potential acquisitions and capital requirements associated with any joint ventures to develop our deep prospects.  If we are ultimately awarded, and consummate, the Gulf of Mexico leases on which we were the apparent high bidder, we will be required to pay lease bonuses and other costs of approximately $1.3 million at the time the leases are finalized.  As noted, we have the operational flexibility to react quickly with our capital expenditures to changes in our cash flows from operations.  Actual levels of capital expenditures in any year may vary significantly due to many factors, including the extent to which properties are acquired, drilling results, oil and gas prices, industry conditions and the prices and availability of goods and services.


Off-Balance Sheet Arrangements


We had no off-balance sheet arrangements or guarantees of third party obligations at March 31, 2013.


Inflation


We believe that inflation has not had a significant impact on our operations since inception.


ITEM 3

QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK


Commodity Price Risk


Our major market-risk exposure is the commodity pricing applicable to our oil and natural gas production.  Realized commodity prices received for such production are primarily driven by the prevailing worldwide price for crude oil and spot prices applicable to natural gas.  Prices have fluctuated significantly during the last five years and such volatility is expected to continue, and the range of such price movement is not predictable with any degree of certainty. During the quarter ended September 30, 2012, we resumed our hedging program under which, in the normal course of business we periodically enter into commodity derivative transactions, including fixed price and ratio swaps to mitigate exposure to commodity price movements, but not for trading or speculative purposes.


As of March 31, 2013, we had the following hedge contracts outstanding:


 

 

Beginning

 

Ending

 

Fixed

 

Total

Instrument

 

Date

 

Date

 

Price

 

Bbls

Fixed Price Swap

 

April 2013

 

December 2013

 

$

106.82 

 

137,500 

Fixed Price Swap

 

April 2013

 

March 2014

 

$

109.20 

 

159,500 

 

 

 

 

 

 

 

 

 

297,000 




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We are exposed to market risk on derivative instruments to the extent of changes in market prices of crude oil.  However, the market risk exposure on these derivative contracts is generally offset by the gain or loss recognized upon the ultimate sale of the commodity.  Unrealized gains and losses, at fair value, are included on our consolidated balance sheets as current or non-current assets or liabilities based on the anticipated timing of cash settlements under the related contracts.  The change in the fair value of our commodity derivative contracts that are effective are recorded to Accumulated Other Comprehensive Loss in Stockholders’ Equity in the Consolidated Balance Sheets.  The ineffective portion of the change in fair market value of derivatives is recorded currently in earnings as a component of Oil and Gas Hedging in the Consolidated Statements of Operations and Comprehensive Income.  We estimate the fair values of swap contracts based on the present value of the difference in exchange-quoted forward price curves and contractual settlement prices multiplied by notional quantities.  For the three months ended March 31, 2013, we recorded an unrealized gain on commodity derivatives of $166,509 in current earnings and an unrealized gain on commodity derivatives of $161,760 in accumulated other comprehensive income (loss).


At March 31, 2013, we had two counterparties to our fixed price swap contracts. We are exposed to credit losses in the event of nonperformance by any counterparty on our commodity derivatives positions. However, we do not anticipate nonperformance by any counterparty over the term of the commodity derivatives positions.


Interest Rate Risk


All of our debt has a fixed interest rate and we are not presently exposed to interest rate risk.  In the event that we establish a new revolving credit facility we expect that such facility will provide for interest at a floating rate and that borrowing under such facility will expose us to risk of changing interest rates.


ITEM 4

CONTROLS AND PROCEDURES


Evaluation of Disclosure Controls and Procedures


Under the supervision and the participation of our management, including our principal executive officer and principal financial officer, we conducted an evaluation as of March 31, 2013 of the effectiveness of the design and operation of our disclosure controls and procedures, as such term is defined under Rule 13a-15(e) promulgated under the Securities Exchange Act of 1934, as amended. Based on this evaluation, our principal executive officer and our principal financial officer concluded that our disclosure controls and procedures were not effective as of March 31, 2013.


Changes in Internal Control over Financial Reporting


No change in our internal control over financial reporting (as defined in Rule 13a-15(f) under the Securities Exchange Act of 1934) occurred during the quarter ended March 31, 2013 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.





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PART II


ITEM 6

EXHIBITS


Exhibit No.

 

Description

 

 

 

31.1

 

Certification of CEO pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

 

 

 

31.2

 

Certification of CFO pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

 

 

 

32.1

 

Certification of CEO Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

 

 

 

32.2

 

Certification of CFO Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

 

 

 

101.INS

 

XBRL Instance Document

101.SCH

 

XBRL Schema Document

101.CAL

 

XBRL Calculation Linkbase Document

101.DEF

 

XBRL Definition Linkbase Document

101.LAB

 

XBRL Labels Linkbase Document

101.PRE

 

XBRL Presentation Linkbase Document




SIGNATURES


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


 

SARATOGA RESOURCES, INC.

Date:  May 10, 2013 

 

 

 

By:

/s/ Thomas Cooke

 

 

Thomas Cooke

 

 

Chief Executive Officer

 

 

 

 

By:

/s/ Michael Aldridge

 

 

Michael Aldridge

 

 

Executive Vice President and Chief

Financial Officer





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