Form 10-Q
Table of Contents

 

 

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

 

FORM 10-Q

 

 

 

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

For the Quarterly Period Ended June 30, 2011

Or

 

¨ 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 0-7406

 

 

PrimeEnergy Corporation

(Exact name of registrant as specified in its charter)

 

 

 

Delaware   84-0637348

(State or other jurisdiction of

incorporation or organization)

 

(I.R.S. employer

Identification No.)

One Landmark Square, Stamford, Connecticut 06901

(Address of principal executive offices)

(203) 358-5700

(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 filings required 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 the definitions of “large accelerated filer”, “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

 

Large accelerated filer   ¨    Accelerated filer   ¨
Non-accelerated filer   ¨  (Do not check if smaller reporting company)    Smaller reporting company   x

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

The number of shares outstanding of each class of the Registrant’s Common Stock as of August 8, 2011 was: Common Stock, $0.10 par value 2,741,055 shares.

 

 

 


Table of Contents

PrimeEnergy Corporation

Index to Form 10-Q

June 30, 2011

 

     Page  

Item 1. Financial Statements

  

Consolidated Balance Sheet – June 30, 2011 and December 31, 2010

     3-4   

Consolidated Statement of Operations – Six and Three Months Ended June 30, 2011 and 2010

     5-6   

Consolidated Statement of Stockholders’ Equity – Six Months Ended June 30, 2011

     7   

Consolidated Statement of Comprehensive Income – Six Months Ended June 30, 2011 and 2010

     8   

Consolidated Statement of Cash Flows – Six Months Ended June 30, 2011 and 2010

     9   

Notes to Consolidated Financial Statements – June 30, 2011

     10-15   

Item 2. Management’s Discussion and Analysis of Financial Conditions and Results of Operation

     16-18   

Item 3. Quantitative and Qualitative Disclosures About Market Risk

     18   

Item 4. Controls and Procedures

     18   

Part II - Other Information

     19   

Item 1. Legal Proceedings

     19   

Item 1A. Risk Factors

     19   

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

     19   

Item 3. Defaults Upon Senior Securities

     19   

Item 4. Reserved

     19   

Item 5. Other Information

     19   

Item 6. Exhibits

     19-21   

Signatures

     22   

 

2


Table of Contents

PART I—FINANCIAL INFORMATION

 

Item 1. FINANCIAL STATEMENTS

PrimeEnergy Corporation

Consolidated Balance Sheet

June 30, 2011 and December 31, 2010

(Unaudited)

 

     June  30,
2011
     December  31,
2010
 

ASSETS:

     

Current assets:

     

Cash and cash equivalents

   $ 14,503,000       $ 32,792,000   

Restricted cash and cash equivalents

     7,267,000         6,131,000   

Accounts receivable, net

     12,983,000         12,748,000   

Due from related parties

     21,000         140,000   

Prepaid expenses

     1,857,000         1,609,000   

Derivative contracts

     1,832,000         3,038,000   

Inventory, at cost

     630,000         700,000   

Deferred income taxes

     595,000         595,000   
  

 

 

    

 

 

 

Total current assets

     39,688,000         57,753,000   
  

 

 

    

 

 

 

Property and equipment, at cost:

     

Oil and gas properties (successful efforts method), net

     139,796,000         143,034,000   

Field service equipment and other, net

     6,615,000         6,794,000   
  

 

 

    

 

 

 

Net property and equipment

     146,411,000         149,828,000   

Other assets

     781,000         579,000   
  

 

 

    

 

 

 

Total assets

   $ 186,880,000       $ 208,160,000   
  

 

 

    

 

 

 

The accompanying Notes are an integral part of these Consolidated Financial Statements

 

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Table of Contents

PrimeEnergy Corporation

Consolidated Balance Sheet

June 30, 2011 and December 31, 2010

(Unaudited)

 

     June  30,
2011
    December  31,
2010
 

LIABILITIES and STOCKHOLDERS’ EQUITY:

    

Current liabilities:

    

Accounts payable

   $ 32,451,000      $ 34,376,000   

Current portion of asset retirement and other long-term obligations

     2,889,000        2,206,000   

Derivative liability short term

     2,796,000        3,048,000   

Accrued liabilities

     5,510,000        7,676,000   

Due to related parties

     194,000        350,000   
  

 

 

   

 

 

 

Total current liabilities

     43,840,000        47,656,000   

Long-term bank debt

     71,850,000        73,100,000   

Indebtedness to related parties

     0        20,000,000   

Asset retirement obligations

     15,893,000        15,285,000   

Derivative liability long term

     5,332,000        2,587,000   

Deferred income taxes

     16,534,000        16,445,000   
  

 

 

   

 

 

 

Total liabilities

     153,449,000        175,073,000   
  

 

 

   

 

 

 

Stockholders’ equity—PrimeEnergy:

    

Common stock, $.10 par value; 2011 and 2010: Authorized: 4,000,000 shares, issued: 3,836,397 shares; outstanding 2011: 2,752,059 shares; outstanding 2010: 2,802,053 shares

     383,000        383,000   

Paid in capital

     6,294,000        5,955,000   

Retained earnings

     47,299,000        46,478,000   
  

 

 

   

 

 

 
     53,976,000        52,816,000   

Treasury stock, at cost; 2011: 1,084,338 shares; 2010 1,034,344 shares

     (30,075,000     (28,896,000
  

 

 

   

 

 

 

Total stockholders’ equity—PrimeEnergy

     23,901,000        23,920,000   

Non-controlling interest

     9,530,000        9,167,000   
  

 

 

   

 

 

 

Total stockholders’ equity

     33,431,000        33,087,000   
  

 

 

   

 

 

 

Total liabilities and stockholders’ equity

   $ 186,880,000      $ 208,160,000   
  

 

 

   

 

 

 

The accompanying Notes are an integral part of these Consolidated Financial Statements

 

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Table of Contents

PrimeEnergy Corporation

Consolidated Statement of Operations

Six Months Ended June 30, 2011 and 2010

(Unaudited)

 

     2011     2010  

Revenue:

    

Oil and gas sales

   $ 43,616,000      $ 43,834,000   

Field service income

     9,774,000        7,843,000   

Administrative overhead fees

     4,338,000        4,148,000   

Unrealized gain (loss) on derivative instruments

     (3,496,000     9,243,000   

Other income

     49,000        193,000   
  

 

 

   

 

 

 

Total revenue

     54,281,000        65,261,000   
  

 

 

   

 

 

 

Costs and expenses:

    

Lease operating expense

     16,809,000        17,537,000   

Field service expense

     8,144,000        6,533,000   

Depreciation, depletion and amortization and accretion on discounted liabilities

     18,031,000        16,929,000   

General and administrative expense

     7,037,000        5,977,000   

Exploration costs

     8,000        5,000   
  

 

 

   

 

 

 

Total costs and expenses

     50,029,000        46,981,000   
  

 

 

   

 

 

 

Gain on sale and exchange of assets

     233,000        350,000   
  

 

 

   

 

 

 

Income from operations

     4,485,000        18,630,000   

Other income and expenses:

    

Less: Interest expense

     2,350,000        3,633,000   

Add: Interest income

     85,000        22,000   
  

 

 

   

 

 

 

Income before provision for income taxes

     2,220,000        15,019,000   

Provision for income taxes

     458,000        4,634,000   
  

 

 

   

 

 

 

Net income

     1,762,000        10,385,000   
  

 

 

   

 

 

 

Less: Net income attributable to non-controlling interest

     941,000        710,000   
  

 

 

   

 

 

 

Net income attributable to PrimeEnergy

   $ 821,000      $ 9,675,000   
  

 

 

   

 

 

 

Basic income per common share

   $ 0.30      $ 3.23   
  

 

 

   

 

 

 

Diluted income per common share

   $ 0.23      $ 2.59   
  

 

 

   

 

 

 

The accompanying Notes are an integral part of these Consolidated Financial Statements

 

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Table of Contents

PrimeEnergy Corporation

Consolidated Statement of Operations

Three Months Ended June 30, 2011 and 2010

(Unaudited)

 

     2011      2010  

Revenue:

     

Oil and gas sales

   $ 22,171,000       $ 21,529,000   

Field service income

     5,169,000         3,808,000   

Administrative overhead fees

     2,121,000         2,100,000   

Unrealized gain on derivative instruments

     6,013,000         5,359,000   

Other income

     36,000         118,000   
  

 

 

    

 

 

 

Total revenue

     35,510,000         32,914,000   
  

 

 

    

 

 

 

Costs and expenses:

     

Lease operating expense

     8,903,000         8,668,000   

Field service expense

     4,239,000         3,265,000   

Depreciation, depletion and amortization and accretion on discounted liabilities

     11,995,000         7,291,000   

General and administrative expense

     4,000,000         2,945,000   

Exploration costs

     7,000         4,000   
  

 

 

    

 

 

 

Total costs and expenses

     29,144,000         22,173,000   
  

 

 

    

 

 

 

Gain on sale and exchange of assets

     11,000         316,000   
  

 

 

    

 

 

 

Income from operations

     6,377,000         11,057,000   

Other income and expenses:

     

Less: Interest expense

     1,139,000         1,640,000   

Add: Interest income

     4,000         11,000   
  

 

 

    

 

 

 

Income before provision for income taxes

     5,242,000         9,428,000   

Provision for income taxes

     1,571,000         2,925,000   
  

 

 

    

 

 

 

Net income

     3,671,000         6,503,000   
  

 

 

    

 

 

 

Less: Net income attributable to non-controlling interest

     468,000         268,000   
  

 

 

    

 

 

 

Net income attributable to PrimeEnergy

   $ 3,203,000       $ 6,235,000   
  

 

 

    

 

 

 

Basic income per common share

   $ 1.16       $ 2.09   
  

 

 

    

 

 

 

Diluted income per common share

   $ 0.92       $ 1.68   
  

 

 

    

 

 

 

The accompanying Notes are an integral part of these Consolidated Financial Statements

 

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PrimeEnergy Corporation

Consolidated Statement of Stockholders’ Equity

Six Months Ended June 30, 2011

(Unaudited)

 

     Common Stock      Additional
Paid in
Capital
     Retained
Earnings
     Treasury Stock     Total
Stockholders’
Equity—PrimeEnergy
    Non-Controlling
Interest
    Total
Stockholders’
Equity
 
     Shares      Amount                 

Balance at December 31, 2010,

     3,836,397       $ 383,000       $ 5,955,000       $ 46,478,000       $ (28,896,000   $ 23,920,000      $ 9,167,000      $ 33,087,000   

Purchase 49,994 shares of common stock

                 (1,179,000     (1,179,000       (1,179,000

Net income

              821,000           821,000        941,000        1,762,000   

Purchase of non-controlling interests

           339,000              339,000        (508,000     (169,000

Distributions to non-controlling interests

                     (70,000     (70,000
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

Balance at June 30, 2011

     3,836,397       $ 383,000       $ 6,294,000       $ 47,299,000       $ (30,075,000   $ 23,901,000      $ 9,530,000      $ 33,431,000   
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

   

 

 

   

 

 

 

The accompanying Notes are an integral part of these Consolidated Financial Statements

 

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Table of Contents

PrimeEnergy Corporation

Consolidated Statement of Comprehensive Income

Six Months Ended June 30, 2011 and 2010

(Unaudited)

 

     2011      2010  

Net income

   $ 1,762,000       $ 10,385,000   

Other comprehensive income, net of taxes:

     

Reclassification adjustment for settled contracts, net of taxes of $0 and $125,000, respectively

     0         222,000   

Changes in fair value of hedge positions, net of taxes of $0 and $5,000, respectively

     0         (8,000
  

 

 

    

 

 

 

Total other comprehensive income

     0         214,000   
  

 

 

    

 

 

 

Comprehensive income

     1,762,000         10,599,000   
  

 

 

    

 

 

 

Less: Comprehensive income attributable to non-controlling interest

     941,000         710,000   
  

 

 

    

 

 

 

Comprehensive income attributable to PrimeEnergy

   $ 821,000       $ 9,889,000   
  

 

 

    

 

 

 

The accompanying Notes are an integral part of these Consolidated Financial Statements

 

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Table of Contents

PrimeEnergy Corporation

Consolidated Statement of Cash Flows

Six Months Ended June 30, 2011 and 2010

(Unaudited)

 

     2011     2010  

Cash flows from operating activities:

    

Net Income

   $ 821,000      $ 9,675,000   

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

    

Non-controlling interest in earnings of partnerships

     941,000        710,000   

Depreciation, depletion, amortization and accretion on discounted liabilities

     18,031,000        16,929,000   

Gain on sale of properties

     (233,000     (350,000

Unrealized (gain) loss on derivative instruments

     3,496,000        (9,243,000

Provision for deferred income taxes

     89,000        4,557,000   

Changes in assets and liabilities:

    

(Increase) decrease in accounts receivable

     (235,000     (488,000

(Increase) decrease in due from related parties

     119,000        (19,000

(Increase) decrease in inventories

     70,000        895,000   

(Increase) decrease in prepaid expenses and other assets

     (246,000     1,747,000   

Increase (decrease) in accounts payable

     (3,061,000     (1,380,000

Increase (decrease) in accrued liabilities

     (187,000     (202,000

Increase (decrease) in due to related parties

     (156,000     (37,000
  

 

 

   

 

 

 

Net cash provided by operating activities

     19,449,000        22,794,000   
  

 

 

   

 

 

 

Cash flows from investing activities:

    

Capital expenditures, including exploration expense

     (15,773,000     (7,861,000

Proceeds from sale of properties and equipment

     233,000        350,000   
  

 

 

   

 

 

 

Net cash used in investing activities

     (15,540,000     (7,511,000
  

 

 

   

 

 

 

Cash flows from financing activities:

    

Purchase of stock for treasury

     (1,179,000     (1,947,000

Purchase of non-controlling interests

     (169,000     (1,000

Increase in long-term bank debt and other long-term obligations

     50,933,000        29,517,000   

Repayment of long-term bank debt and other long-term obligations

     (51,713,000     (42,359,000

Repayment of indebtedness to related parties

     (20,000,000     0   

Distribution to non-controlling interest

     (70,000     (818,000
  

 

 

   

 

 

 

Net cash used in financing activities

     (22,198,000     (15,608,000
  

 

 

   

 

 

 

Net decrease in cash and cash equivalents

     (18,289,000     (325,000

Cash and cash equivalents at the beginning of the period

     32,792,000        11,779,000   
  

 

 

   

 

 

 

Cash and cash equivalents at the end of the period

   $ 14,503,000      $ 11,454,000   
  

 

 

   

 

 

 

Supplemental disclosures:

    

Income taxes paid

   $ 1,211,000      $ 77,215   

Net income tax refunds received during the year

   $ 41,000      $ 0   

Interest paid

   $ 2,350,000      $ 3,633,000   

Change in accrued expenses relating to property

   $ 1,979,000      $ 1,315,000   

The accompanying Notes are an integral part of these Consolidated Financial Statements

 

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Table of Contents

PrimeEnergy Corporation

Notes to Consolidated Financial Statements

June 30, 2011

(Unaudited)

(1) Interim Financial Statements:

The accompanying consolidated financial statements of PrimeEnergy Corporation (“PEC” or the “Company”) have not been audited by independent public accountants. During the interim periods, the Company follows the same accounting policies as used and described in its Annual Report on Form 10-K for the year ended December 31, 2010. In accordance with applicable Securities and Exchange Commission (“SEC”) rules and regulations, the accompanying interim financial statements do not include all disclosures presented in annual financial statements and the reader should refer to the Company’s Form 10-K for the year ended December 31, 2010 filed with the SEC on April 7, 2011. In the opinion of management, the accompanying interim consolidated financial statements contain all material adjustments, consisting only of normal recurring adjustments, necessary for a fair presentation of the Company’s Consolidated Balance Sheets as of June 30, 2011 and December 31, 2010, the Consolidated Statements of Operations for the three and six months ended June 30, 2011 and 2010, the Consolidated Statement of Stockholders’ Equity for the six months ended June 30, 2011, and the Consolidated Statements of Comprehensive Income and Cash Flows for the six months ended June 30, 2011 and 2010. Certain amounts presented in prior period financial statements have been reclassified for consistency with current period presentation. The results for interim periods are not necessarily indicative of annual results. For purposes of disclosure in the consolidated financial statements, subsequent events have been evaluated through the date the statements were issued.

Recently Issued Accounting Pronouncements

In May 2011, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2011-04 “Amendments to Achieve Common Fair Value Measurement and Disclosure Requirements in US GAAP and IFRSs”. This ASU amends previously issued authoritative guidance and requires new disclosures, clarifies existing disclosures and is effective for interim and annual periods beginning after December 15, 2011. Early application by public entities is not permitted. The amendments change requirements for measuring fair value and disclosing information about those measurements. Additionally, this ASU clarifies the FASB’s intent regarding the application of existing fair value measurement requirements and changes certain principles or requirements for measuring fair value or disclosing information about its measurements. For many of the requirements, the FASB does not intend the amendments to change the application of the existing Fair Value Measurements guidance. The Company does not expect this guidance to have a significant impact on its financial position, results of operations or cash flows.

In June 2011, the FASB issued ASU No. 2011-05, “Presentation of Comprehensive Income”, which amends current comprehensive income guidance. This accounting update eliminates the option to present the components of other comprehensive income as part of the statement of shareholders’ equity. Instead, the Company must report comprehensive income in either a single continuous statement of comprehensive income which contains two sections, net income and other comprehensive income, or in two separate but consecutive statements. The new requirements are effective for public entities for interim and annual periods beginning after December 15, 2011 with early adoption permitted. The adoption of this ASU will not have an impact on the Company’s consolidated financial position, results of operations or cash flows as it only requires a change in the format of the current presentation.

(2) Acquisitions and Dispositions:

Historically the Company has repurchased the interests of the partners and trust unit holders in the eighteen oil and gas limited partnerships (the “Partnerships”) and the two asset and business income trusts (the “Trusts”) managed by the Company as general partner and as managing trustee, respectively. The Company purchased such interests in an amount totaling $169,000 and $1,000 for the six months ended June 30, 2011and 2010, respectively.

(3) Restricted Cash and Cash Equivalents:

Restricted cash and cash equivalents include $7,267,000 and $6,131,000 at June 30, 2011 and December 31, 2010, respectively, of cash primarily pertaining to oil and gas revenue payments. There were corresponding accounts payable recorded at June 30, 2011 and December 31, 2010 for these liabilities. Both the restricted cash and the accounts payable are classified as current on the Consolidated Balance Sheet.

 

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(4) Additional Balance Sheet Information:

Certain balance sheet amounts are comprised of the following:

 

     June 30, 2011      December 31, 2010  

Accounts Receivable:

     

Joint interest billing

   $ 2,575,000       $ 2,538,000   

Trade receivables

     1,658,000         1,688,000   

Oil and gas sales

     9,020,000         8,139,000   

Other

     134,000         724,000   
  

 

 

    

 

 

 
     13,387,000         13,089,000   

Less: Allowance for doubtful accounts

     404,000         341,000   
  

 

 

    

 

 

 

Total

   $ 12,983,000       $ 12,748,000   
  

 

 

    

 

 

 

Accounts Payable:

     

Trade

   $ 4,740,000       $ 3,421,000   

Royalty and other owners

     12,677,000         10,395,000   

Prepaid drilling deposits

     8,148,000         12,871,000   

Other

     6,886,000         7,689,000   
  

 

 

    

 

 

 

Total

   $ 32,451,000       $ 34,376,000   
  

 

 

    

 

 

 

Accrued Liabilities:

     

Compensation and related expenses

   $ 3,153,000       $ 2,010,000   

Property costs

     780,000         3,282,000   

Income tax

     129,000         930,000   

Other

     1,448,000         1,454,000   
  

 

 

    

 

 

 

Total

   $ 5,510,000       $ 7,676,000   
  

 

 

    

 

 

 

(5) Property and Equipment:

Property and equipment at June 30, 2011 and December 31, 2010 consisted of the following:

 

     June  30,
2011
     December 31,
2010
 

Proved oil and gas properties, at cost

   $ 466,899,000       $ 453,145,000   

Unproved oil and gas properties, at cost

     103,000         698,000   

Less: Accumulated depletion and depreciation

     327,206,000         310,809,000   
  

 

 

    

 

 

 
   $ 139,796,000       $ 143,034,000   

Field service equipment and other

   $ 19,540,000       $ 19,499,000   

Less: Accumulated depreciation

     12,925,000         12,705,000   
  

 

 

    

 

 

 
   $ 6,615,000       $ 6,794,000   
  

 

 

    

 

 

 

Total net property and equipment

   $ 146,411,000       $ 149,828,000   
  

 

 

    

 

 

 

(6) Long-Term Bank Debt:

Bank Debt:

Effective June 22, 2011, the Company entered into a Second Amendment to the Second Amended and Restated Credit Agreement (“Second Amendment”). The Second Amendment to this $250 million credit facility increased the Company’s borrowing base to $125 million; removed the floor rate component of LIBO rate loans; modified financial reporting requirements to the agent; increased hedging allowances; and allowed for a one-time advance to be made to the Company’s offshore subsidiary. Subject to facility borrowing base availability amounts, the banks approved a one-time advance of up to $16 million to be made from PEC to its offshore subsidiary specifically to be used to pay in full the offshore subsidiary’s indebtedness to a related party. The banks required this advance to be made within 30 days after the effective date of the Second Amendment and the Company completed the advance to its offshore subsidiary on June 24, 2011. Under the Second Amendment, the maximum percentage of production available to enter into commodity hedge agreements was revised to 90% from 85% of proved developed producing reserves for each of the next succeeding four calendar years for crude oil and natural gas computed separately. In addition, following the Second Amendment the Company’s restriction on payments for dividends, distributions or repurchase of PEC’s stock was increased to $2.5 million in each calendar year. Borrowing base monthly reduction amounts remain at $2 million with the first reduction to now begin on December 15, 2011.

 

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The Company’s borrowing rates in the credit facility include for a base rate loan at the prime rate (3.25% at June 30, 2011) plus applicable margin utilization rates that range from 1.75% to 2.0%, and for a LIBO rate loan at LIBO published rates plus applicable utilization rates (2.75% to 3.00% at June 30, 2011). As of June 30, 2011, the Company had in place one base rate loan and one LIBO rate loan with effective rates of 5.00% and 3.04%, respectively.

At June 30, 2011, the Company had $71.9 million of borrowings outstanding under its revolving credit facility at a weighted- average interest rate of 5.58% and $53.1 million available for future borrowings. The combined weighted average interest rates paid on outstanding bank borrowings subject to base rate and LIBO interest were 5.67% during the first six months of 2011 as compared to 6.09% during the same period in 2010.

Indebtedness to related parties:

Effective January 3, 2011, the Company’s loan with a private lender that is controlled by a Director of PEC was modified and included a payment from the Company’s offshore subsidiary to the private lender of $4 million which was made on January 18, 2011. Further, on June 27, 2011, this loan along with all accrued interest was paid in full from the Company’s offshore subsidiary and the note was cancelled.

(7) Other Long-Term Obligations and Commitments:

Operating Leases:

The Company has several non-cancelable operating leases, primarily for rental of office space, that have a term of more than one year. The future minimum lease payments for the rest of the fiscal 2011 and thereafter for the operating leases are as follows:

 

     Operating Leases  

2011

   $ 403,000   

2012

     555,000   

2013

     434,000   

2014

     16,000   
  

 

 

 

Total minimum payments

   $ 1,408,000   
  

 

 

 

Rent expense for office space for the six months ended June 30, 2011 and 2010 was $378,000 and $391,000, respectively.

Asset Retirement Obligation:

A reconciliation of the liability for plugging and abandonment costs for the six months ended June 30, 2011 is as follows:

 

Asset retirement obligation – December 31, 2010

   $ 17,147,000   

Liabilities incurred

     140,000   

Liabilities settled

     (213,000

Accretion expense

     681,000   
  

 

 

 

Asset retirement obligation – June 30, 2011

   $ 17,755,000   
  

 

 

 

The Company’s liability is determined using significant assumptions, including current estimates of plugging and abandonment costs, annual inflation of these costs, the productive life of wells and a risk-adjusted interest rate. Changes in any of these assumptions can result in significant revisions to the estimated asset retirement obligation. Revisions to the asset retirement obligation are recorded with an offsetting change to producing properties, resulting in prospective changes to depreciation, depletion and amortization expense and accretion of discount. Because of the subjectivity of assumptions and the relatively long life of most of the Company’s wells, the costs to ultimately retire the wells may vary significantly from previous estimates.

(8) Contingent Liabilities:

The Company, as managing general partner of the affiliated Partnerships, is responsible for all Partnership activities, including the drilling of development wells and the production and sale of oil and gas from productive wells. The Company also provides the administration, accounting and tax preparation work for the Partnerships, and is liable for all debts and liabilities of the affiliated Partnerships, to the extent that the assets of a given limited Partnership are not sufficient to satisfy its obligations. As of June 30, 2011, the affiliated Partnerships have established cash reserves in excess of their debts and liabilities and the Company believes these reserves will be sufficient to satisfy Partnership obligations.

The Company is subject to environmental laws and regulations. Management believes that future expenses, before recoveries from third parties, if any, will not have a material effect on the Company’s financial condition. This opinion is based on expenses incurred to date for remediation and compliance with laws and regulations, which have not been material to the Company’s results of operations.

 

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From time to time, the Company is party to certain legal actions arising in the ordinary course of business. While the outcome of these events cannot be predicted with certainty, management does not expect these matters to have a materially adverse effect on the financial position or results of operations of the Company.

(9) Stock Options and Other Compensation:

In May 1989, non-statutory stock options were granted by the Company to four key executive officers for the purchase of shares of common stock. At June 30, 2011 and 2010, options on 767,500 shares were outstanding and exercisable at prices ranging from $1.00 to $1.25. According to their terms, the options have no expiration date.

(10) Related Party Transactions:

The Company, as managing general partner or managing trustee, makes an annual offer to repurchase the interests of the partners and trust unit holders in certain of the Partnerships or Trusts. The Company purchased such interests in an amount totaling $169,000 and $1,000 for the six months ended June 30, 2011 and 2010, respectively.

Receivables from related parties consist of reimbursable general and administrative costs, lease operating expenses and reimbursement for property development and related costs. These receivables are due from joint venture partners, which may include members of the Company’s Board of Directors.

Payables owed to related parties primarily represent receipts collected by the Company as agent for the joint venture partners, which may include members of the Company’s Board of Directors, for oil and gas sales net of expenses. Also included in due to related parties at December 31, 2010 was the amount of accrued interest, $170,000, owed to a related party, a company controlled by a Director of the Company, with whom the Company’s offshore subsidiary entered into a credit agreement. This agreement was concluded as of June 2011 and all interest owed and the loan balance remaining was paid at that time.

(11) Financial Instruments

Fair Value measurements:

Authoritative guidance on fair value measurements defines fair value, establishes a framework for measuring fair value and stipulates the related disclosure requirements. The Company follows a three-level hierarchy, prioritizing and defining the types of inputs used to measure fair value. The fair values of the Company’s interest rate swaps, natural gas and crude oil price collars and swaps are designated as Level 3. The following fair value hierarchy table presents information about the Company’s assets and liabilities measured at fair value on a recurring basis as of June 30, 2011 and December 31, 2010:

 

     Quoted Prices in
Active Markets
For Identical
Assets (Level 1)
     Significant
Other
Observable
Inputs (Level 2)
     Significant
Unobservable
Inputs (Level 3)
    Balance as of
June 30,
2011
 

June 30, 2011

          

Assets

          

Commodity derivative contracts

                 $ 2,040,000      $ 2,040,000   
        

 

 

   

 

 

 

Total assets

                 $ 2,040,000      $ 2,040,000   
        

 

 

   

 

 

 

Liabilities

          

Commodity derivative contracts

                 $ (8,128,000   $ (8,128,000
        

 

 

   

 

 

 

Total liability

                 $ (8,128,000   $ (8,128,000
        

 

 

   

 

 

 
     Quoted Prices in
Active Markets
For Identical
Assets (Level 1)
     Significant
Other
Observable
Inputs (Level 2)
     Significant
Unobservable
Inputs (Level 3)
    Balance as of
December 31,
2010
 

December 31, 2010

          

Assets

          

Commodity derivative contracts

                   $ 3,042,000      $ 3,042,000   
        

 

 

   

 

 

 

Total assets

                   $ 3,042,000      $ 3,042,000   
        

 

 

   

 

 

 

Liabilities

          

Commodity derivative contracts

                   $ (5,635,000   $ (5,635,000
        

 

 

   

 

 

 

Total liability

                   $ (5,635,000   $ (5,635,000
        

 

 

   

 

 

 

 

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Table of Contents

The following table sets forth a reconciliation of changes in the fair value of financial assets and liabilities classified as level 3 in the fair value hierarchy for the six months ended June 30, 2011.

 

Net liabilities – December 31, 2010

   $ (2,593,000

Total realized and unrealized gains or losses:

  

Included in earnings (a)

     (3,360,000

Purchases, sales, issuances and settlements,

     (135,000
  

 

 

 

Net liabilities – June 30, 2011

   $ (6,088,000
  

 

 

 

 

(a) Derivative instruments are reported in oil and gas sales as realized gain/loss and on a separately reported line item captioned unrealized gain/loss on derivative instruments.

Derivative Instrument:

The Company is exposed to commodity price and interest rate risk, and management considers periodically the Company’s exposure to cash flow variability resulting from the commodity price changes and interest rate fluctuations. Futures, swaps and options are used to manage the Company’s exposure to commodity price risk inherent in the Company’s oil and gas production operations. The Company does not apply hedge accounting to any of its commodity based derivatives. Both realized and unrealized gains and losses associated with derivative instruments are recognized in earnings.

Effect of derivative instruments on the consolidated balance sheet:

 

          Fair Value  
    

Balance Sheet Location

   June 30, 2011     December 31, 2010  

Asset Derivatives:

       

Derivatives not designated as hedging instruments:

       

Natural gas commodity contracts

   Current derivative contracts    $ 1,832,000      $ 3,038,000   

Natural gas commodity contracts

   Other assets      208,000        0   

Crude oil commodity contracts

   Other assets      0        4,000   
     

 

 

   

 

 

 

Total

      $ 2,040,000      $ 3,042,000   
     

 

 

   

 

 

 

Liability Derivatives:

       

Derivatives not designated as hedging instruments:

       

Crude oil commodity contracts

   Derivative liability short term    $ (2,796,000   $ (3,048,000

Crude oil commodity contracts

   Derivative liability long term      (5,332,000     (2,587,000
     

 

 

   

 

 

 

Total

      $ (8,128,000   $ (5,635,000
     

 

 

   

 

 

 

Total derivative instruments

      $ (6,088,000   $ (2,593,000
     

 

 

   

 

 

 

Effect of derivative instruments on the consolidated statement of operations for the six-month periods ended June 30, 2011 and 2010:

 

    

Location of gain/loss reclassified
from OCI into income

   Amount of gain/loss
reclassified from accumulated
OCI into income
 
        2011     2010  

Derivatives designated as cash-flow hedges

       

Interest rate swap derivatives

   Interest expense    $ 0      $ (347,000
     

 

 

   

 

 

 
      $ 0      $ (347,000
     

 

 

   

 

 

 
    

Location of gain/loss recognized
in income

   Amount of gain/loss
recognized in income
 
        2011     2010  

Derivatives not designated as cash-flow hedge instruments

       

Natural gas commodity contracts

   Unrealized gain(loss) on derivative instruments    $ (998,000   $ 1,570,000  

Crude oil commodity contracts

   Unrealized gain(loss) on derivative instruments      (2,498,000     7,673,000  

Natural gas commodity contracts

   Oil and gas sales      1,972,000        1,646,000  

Crude oil commodity contracts

   Oil and gas sales      (1,836,000     (96,000 )
     

 

 

   

 

 

 
      $ (3,360,000   $ 10,793,000  
     

 

 

   

 

 

 

 

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(12) Earnings Per Share:

Basic earnings per share are computed by dividing earnings available to common stockholders by the weighted average number of common shares outstanding during the period. Diluted earnings per share reflect per share amounts that would have resulted if dilutive potential common stock had been converted to common stock in gain periods. The following reconciles amounts reported in the financial statements:

 

     Six Months Ended June 30, 2011      Six Months Ended June 30, 2010  
     Net
Income
     Weighted
Average
Number of
Shares
Outstanding
     Per Share
Amount
     Net Income      Weighted
Average
Number of
Shares
Outstanding
     Per Share
Amount
 

Basic

   $ 821,000         2,767,124       $ 0.30       $ 9,675,000         2,996,491       $ 3.23   

Effect of dilutive securities:

                 

Options

        734,671               735,395      
  

 

 

    

 

 

       

 

 

    

 

 

    

Diluted

   $ 821,000         3,501,795       $ 0.23       $ 9,675,000         3,731,886       $ 2.59   
  

 

 

    

 

 

       

 

 

    

 

 

    
     Three Months Ended June 30, 2011      Three Months Ended June 30, 2010  
     Net
Income
     Weighted
Average
Number of
Shares
Outstanding
     Per Share
Amount
     Net Income      Weighted
Average
Number of
Shares
Outstanding
     Per Share
Amount
 

Basic

   $ 3,203,000         2,755,035       $ 1.16       $ 6,235,000         2,964,696       $ 2.09   

Effect of dilutive securities:

                 

Options

        736,739               729,694      
  

 

 

    

 

 

       

 

 

    

 

 

    

Diluted

   $ 3,203,000         3,491,774       $ 0.92       $ 6,235,000         3,694,390       $ 1.68   
  

 

 

    

 

 

       

 

 

    

 

 

    

 

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

This discussion should be read in conjunction with the consolidated financial statements of the Company and notes thereto.

OVERVIEW

The Company presently owns producing and non-producing properties located primarily in Texas, Oklahoma, West Virginia, the Gulf of Mexico, New Mexico, Colorado and Louisiana, and owns a substantial amount of well servicing equipment. All of the Company’s oil and gas properties and interests are located in the United States. Assets in our principal focus areas include mature properties with long-lived reserves and significant development opportunities as well as newer properties with development and exploration potential. We believe our balanced portfolio of assets and our ongoing hedging program position us well for both the current commodity price environment and future potential upside as we develop our attractive resource opportunities. Our primary sources of liquidity are cash generated from our operations and our credit facility.

The Company attempts to assume the position of operator in all acquisitions of producing properties. The Company will continue to evaluate prospects for leasehold acquisitions and for exploration and development operations in areas in which it owns interests and is actively pursuing the acquisition of producing properties. In order to diversify and broaden its asset base, the Company will consider acquiring the assets or stock in other entities and companies in the oil and gas business. The main objective of the Company in making any such acquisitions will be to acquire income producing assets so as to increase the Company’s net worth and increase the Company’s oil and gas reserve base.

Our cash flows depend on many factors, including the price of oil and gas, the success of our acquisition and drilling activities and the operational performance of our producing properties. We use derivative instruments to manage our commodity price risk. This practice may prevent us from receiving the full advantage of increases in oil and gas prices above the maximum fixed amount specified in the derivative agreements and subjects us to the credit risk of the counterparties to such agreements. Since all of our derivative contracts are accounted for under mark-to-market accounting, we expect continued volatility in gains and losses on mark-to-market derivative contracts in our consolidated income statement as changes occur in the NYMEX price indices.

RECENT ACTIVITIES

During the first six months of 2011, the Company continued its drilling program in our West Texas district, drilling a total of 15 gross (10.4 net) wells, all of which were successful completions. The Company intends to drill approximately 30 wells this year, primarily in West Texas.

In June 2011 the Company successfully completed the amendment of its $250,000,000 credit facility with an increase in the current borrowing base from $100,000,000 to $125,000,000 and closed our previously existing subordinated credit facility with a related party private lender.

LIQUIDITY AND CAPITAL RESOURCES

Cash flow provided by operations for the six month period ended June 30, 2011 was $19,449,000. Excluding the effects of significant unforeseen expenses or other income, our cash flow from operations fluctuates primarily because of variations in oil and gas production and prices or changes in working capital accounts. Our oil and gas production will vary based on actual well performance but may be curtailed due to factors beyond our control. Hurricanes in the Gulf of Mexico may shut down our production for the duration of the storm’s presence in the Gulf or damage production facilities so that we cannot produce from a particular property for an extended amount of time. In addition, downstream activities on major pipelines in the Gulf of Mexico can also cause us to shut-in production for various lengths of time.

Our realized oil and gas prices vary due to world political events, supply and demand of products, product storage levels, and weather patterns. We sell the vast majority of our production at spot market prices. Accordingly, product price volatility will affect our cash flow from operations. To mitigate price volatility we sometimes lock in prices for some portion of our production through the use of financial instruments.

The Company’s activities include development and exploratory drilling. The Company’s strategy is to develop a balanced portfolio of drilling prospects that includes lower risk wells with a high probability of success and higher risk wells with greater economic potential. The Company plans on drilling in excess of 30 wells (20 net), mainly in the Permian Basin in West Texas.

The Company has in place both a stock repurchase program and a limited partnership interest repurchase program under which the Company expects to continue spending during 2011. For the six month period ended June 30, 2011, the Company spent $1,348,000 under these programs.

The Company currently maintains a credit facility totaling $250 million, with a current borrowing base of $125 million. The bank reviews the borrowing base semi-annually and, at their discretion, may decrease or propose an increase to the borrowing base relative to a redetermined estimate of proved oil and gas reserves. Our oil and gas properties are pledged as collateral for the line of credit and we are subject to certain financial covenants defined in the agreement. We are currently in compliance with these financial covenants.

 

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If we do not comply with these covenants on a continuing basis, the lenders have the right to refuse to advance additional funds under the facility and/or declare all principal and interest immediately due and payable.

It is the goal of the Company to increase its oil and gas reserves and production through the acquisition and development of oil and gas properties. The Company also continues to explore and consider opportunities to further expand its oilfield servicing revenues through additional investment in field service equipment. However, the majority of the Company’s capital spending is discretionary, and the ultimate level of expenditures will be dependent on the Company’s assessment of the oil and gas business environment, the number and quality of oil and gas prospects available, the market for oilfield services, and oil and gas business opportunities in general.

RESULTS OF OPERATIONS

Revenues and net income during the six and three month periods ended June 30, 2011, as compared to the same periods in 2010 reflect the increased oil and gas sales, presented below, offset by depreciation and depletion of oil and gas properties. The table summarizes production volumes and average sales prices realized (including realized gains and losses from derivatives).

 

     Six Months Ended June 30,     Three Months Ended June 30,  
     2011      2010      Increase /
(Decrease)
    2011      2010      Increase /
(Decrease)
 

Barrels of Oil Produced

     303,000         328,000         (25,000     147,000         168,000         (21,000

Average Price Received (rounded, including the impact of derivatives)

   $ 87.28       $ 72.90       $ 14.38      $ 88.73       $ 70.83       $ 17.89   
  

 

 

    

 

 

    

 

 

   

 

 

    

 

 

    

 

 

 

Oil Revenue

   $ 26,447,000       $ 23,910,000       $ 2,537,000      $ 13,043,000       $ 11,900,000       $ 1,143,000   
  

 

 

    

 

 

    

 

 

   

 

 

    

 

 

    

 

 

 

Mcf of Gas Produced

     2,409,000         3,071,000         (662,000     1,243,000         1,533,000         (290,000

Average Price Received (rounded, including the impact of derivatives)

   $ 7.13       $ 6.49       $ 0.64      $ 7.34       $ 6.28       $ 1.06   
  

 

 

    

 

 

    

 

 

   

 

 

    

 

 

    

 

 

 

Gas Revenue

   $ 17,169,000       $ 19,924,000       $ (2,755,000   $ 9,128,000       $ 9,629,000       $ (501,000
  

 

 

    

 

 

    

 

 

   

 

 

    

 

 

    

 

 

 

Total Oil & Gas Revenue

   $ 43,616,000       $ 43,834,000       $ (218,000   $ 22,171,000       $ 21,529,000       $ 642,000   
  

 

 

    

 

 

    

 

 

   

 

 

    

 

 

    

 

 

 

Oil and gas prices received excluding the impact of derivatives were:

 

     Six Months Ended June 30,      Three Months Ended June 30,  
     2011      2010      Increase /
(Decrease)
     2011      2010      Increase /
(Decrease)
 

Oil Price

   $ 93.34       $ 73.19       $ 20.15       $ 96.72       $ 71.36       $ 25.36   

Gas Price

   $ 6.31       $ 5.95       $ 0.36       $ 6.60       $ 5.51       $ 1.09   

The decrease in oil production reflects the natural decline of existing properties offset by production from properties added during 2010 and 2011. The decrease in gas production is primarily due to the natural decline of the offshore properties.

Lease operating expense for the six months of 2011 decreased by $728,000 or 4.15 % compared to 2010 reflecting a decrease in expensed workovers across all districts.

General and administrative expenses increased $1,060,000 in the first six months of 2011 or 17.73% as compared to 2010 primarily due to increased personnel costs including engineering consultants, and employee related taxes and insurance.

Field service income for the six months of 2011 increased $1,931,000 or 24.62% compared to 2010. Field service expense for the six months of 2011 increased $1,611,000 or 24.66% compared to 2010. The changes in field service income are a direct result of changes in utilization of equipment and rates charged to customers. Workover rig services represent the bulk of our operation, and those rates all increased in our most active districts. Utilization of our workover rigs increased in all districts. Water hauling and disposal services also increased in our South Texas district. The most significant costs included in field service expense are salaries and employee-related expenses. These costs increased relative to our increased utilization and rates.

Depreciation, depletion, amortization and accretion on discounted liabilities expense increased to $18,031,000 in 2011 from $16,929,000 in 2010 or 6.51%. This increase is primarily related to the additional properties and equipment added during 2010 and 2011 combined with decreased offshore reserves.

This report may contain statements relating to the future results of the Company that are considered “forward-looking statements” as defined in the Private Securities Litigation Reform Act of 1995 (the “PSLRA”). In addition, certain statements may be contained in the Company’s future filings with the SEC, in press releases, and in oral and written statements made by or with the approval of the Company that are not statements of historical fact and constitute forward-looking statements within the meaning of the PSLRA. Such

 

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Table of Contents

forward-looking statements, in addition to historical information, which involve risk and uncertainties, are based on the beliefs, assumptions and expectations of management of the Company. Words such as “expects”, ‘believes”, “should”, “plans”, “anticipates”, “will”, “potential”, “could”, “intend”, “may”, “outlook”, “predict”, “project”, “would”, “estimates”, “assumes”, “likely”‘ “and variations of such similar expressions are intended to identify such forward-looking statements. These statements are not guarantees of future performance and involve risks and uncertainties and are based on a number of assumptions that could ultimately prove inaccurate and, therefore, there can be no assurance that they will prove to be accurate. Actual results and outcomes may vary materially from what is expressed or forecast in such statements due to various risks and uncertainties. These risks and uncertainties include, among other things, the possibility of drilling cost overruns and technical difficulties, volatility of oil and gas prices, competition, risks inherent in the Company’s oil and gas operations, the inexact nature of interpretation of seismic and other geological and geophysical data, imprecision of reserve estimates, and the Company’s ability to replace and expand oil and gas reserves. Accordingly, stockholders and potential investors are cautioned that certain events or circumstances could cause actual results to differ materially from those projected. The forward looking statements are made as of the date of this report and the Company assumes no obligation to update the forward-looking statement or to update the reasons why actual results could differ from those projected in the forward-looking statements.

 

Item 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

The Company is a smaller reporting company and no response is required pursuant to this Item.

 

Item 4. CONTROLS AND PROCEDURES

As of the end of the current reported period covered by this report, the Company carried out an evaluation, under the supervision and with the participation of the Company’s management, including the Company’s Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of the Company’s disclosure controls and procedures pursuant to Rules 13a-15 and 15d-15 of the Securities Exchange Act of 1934 (the “Exchange Act”). Based upon that evaluation, the Chief Executive Officer and Chief Financial Officer concluded that the Company’s disclosure controls and procedures are effective with respect to the recording, processing, summarizing and reporting, within the time periods specified in the Commission’s rules and forms, of information required to be disclosed by the Company in the reports that it files or submits under the Exchange Act.

There were no changes in the Company’s internal control over financial reporting that occurred during the first six months of 2011 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

 

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Table of Contents

PART II—OTHER INFORMATION

 

Item 1. LEGAL PROCEEDINGS

Not applicable.

 

Item 1A. RISK FACTORS

The Company is a smaller reporting company and no response is required pursuant to this Item.

 

Item 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

There were no sales of equity securities by the Company during the period covered by this report.

During the six months ended June 30, 2011, the Company purchased the following shares of common stock as treasury shares.

 

2011 Month

   Number of Shares      Average Price
Paid per share
     Maximum
Number of Shares
that May Yet Be
Purchased Under
The Program at
Month - End (1)
 

January

     17,225       $ 19.44         238,372   

February

     12,110       $ 24.08         226,262   

March

     12,492       $ 26.61         213,770   

April

     5,227       $ 27.63         208,543   

May

     1,788       $ 27.17         206,755   

June

     1,152       $ 23.55         205,603   
  

 

 

    

 

 

    

Total/Average

     49,994       $ 23.58      
  

 

 

    

 

 

    

 

(1) In December 1993, we announced that our Board of Directors authorized a stock repurchase program whereby we may purchase outstanding shares of our common stock from time-to-time, in open market transactions or negotiated sales. The Board of Directors of the Company approved an additional 300,000 shares of the Company’s stock to be included in the stock repurchase program effective May 20, 2010. A total of 3,000,000 shares have been authorized, to date, under this program. Through June 30, 2011 we repurchased a total of 2,794,397 shares under this program for $38,732,325 at an average price of $13.86 per share. Additional purchases may occur as market conditions warrant. We expect future purchases will be funded with internally generated cash flow or from working capital.

 

Item 3. DEFAULTS UPON SENIOR SECURITIES

None

 

Item 4. RESERVED

 

Item 5. OTHER INFORMATION

None

 

Item 6. EXHIBITS

The following exhibits are filed as a part of this report:

 

Exhibit No.

     
    3.1    Restated Certificate of Incorporation of PrimeEnergy Corporation (effective July 1, 2009) (Incorporated by reference to Exhibit 3.1 to PrimeEnergy Corporation Form 10-Q for the quarter ended June 30, 2009)
    3.2    Bylaws of PrimeEnergy Corporation (Incorporated by reference to Exhibit 3.2 to PrimeEnergy Corporation Form 10-Q for the quarter ended June 30, 2010)
  10.3.1    Adoption Agreement #003 dated 4/23/2002, MassMutual Life Insurance Company Flexinvest Prototype Non-Standardized 401(k) Profit-Sharing Plan; EGTRRA Amendment to the PrimeEnergy employees 401(k) Savings Plan; MassMutual Retirement Services Flexinvest Defined Contribution Prototype Plan; Protected Benefit Addendum; Addendum to the Administrative Services Agreement Loan Agreement; Addendum to Administrative Services Agreement GUST Restatement Provisions; General Trust Agreement (Incorporated by reference to Exhibit 10.3.1 to PrimeEnergy Corporation Form 10-K for the year ended December 31, 2002)

 

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Table of Contents
  10.3.2    First Amendment to the PrimeEnergy Corporation Employees 401(k) Savings Plan (Incorporated by reference to Exhibit 10.3.2 to PrimeEnergy Corporation Form 10-K for the year ended December 31, 2006)
  10.4    Amended and Restated Agreement of Limited Partnership, FWOE Partners L.P., dated as of August 22, 2005 (Incorporated by reference to Exhibit 10.3 to PrimeEnergy Corporation Form 8-K for events of August 22, 2005)
  10.4.1    Contribution Agreement between F-W Oil Exploration L.L.C. and FWOE Partners L.P. dated as of August 22, 2005 (Incorporated by reference to exhibit 10.4 to PrimeEnergy Corporation Form 8-K for events of August 22, 2005)
  10.18    Composite copy of Non-Statutory Option Agreements (Incorporated by reference to Exhibit 10.18 to PrimeEnergy Corporation Form 10-K for the year ended December 31, 2004)
  10.22.5.9    Second Amended and Restated Credit Agreement dated July 30, 2010, by and among PrimeEnergy Corporation, the Guarantors Party Hereto (PrimeEnergy Management Corporation, Prime Operating Company, Eastern Oil Well Service Company, Southwest Oilfield Construction Company, and EOWS Midland Company), Compass Bank (successor in interest to Guaranty Bank, FSB) As Administrative Agent and Letter of Credit Issuer, BBVA Compass, As Sole Lead Arranger and Sole Bookrunner and The Lenders Signatory Hereto (BNP Paribas, JPMorgan Chase Bank, N.A. and Amegy Bank National Association) (Incorporated by reference to Exhibit 10.22.5.9 to PrimeEnergy Corporation Form 10-Q for the quarter ended June 30, 2010)
  10.22.5.9.1    First Amendment To Second Amended and Restated Credit Agreement Among PrimeEnergy Corporation, The Guarantors Party Hereto (PrimeEnergy Management Corporation, Prime Operating Company, Eastern Oil Well Service Company, Southwest Oilfield Construction Company, E O W S Midland Company), Compass Bank (successor in interest to Guaranty Bank, FSB), As Administrative Agent, Letter of Credit Issuer and Collateral Agent and The Lenders Signatory Hereto (Compass Bank, BNP Paribas, JPMorgan Chase Bank, N.A., Amegy Bank National Association) effective September 30, 2010 (Incorporated by reference to Exhibit 10.22.5.9.1 to PrimeEnergy Corporation Form 10Q for the quarter ended September 30, 2010).
  10.22.5.9.2    Second Amendment To Second Amended and Restated Credit Agreement Among PrimeEnergy Corporation, The Guarantors Party Hereto (PrimeEnergy Management Corporation, Prime Operating Company, Eastern Oil Well Service Company, Southwest Oilfield Construction Company, E O W S Midland Company), Compass Bank (successor in interest to Guaranty Bank, FSB), As Administrative Agent, Letter of Credit Issuer and Collateral Agent and The Lenders Signatory Hereto (Compass Bank, BNP Paribas, JPMorgan Chase Bank, N.A., Amegy Bank National Association) effective June 22, 2011 (filed herewith).
  10.22.5.10    Security Agreement (Pledge) effective July 30, 2010 by PrimeEnergy Corporation, in favor of Compass Bank) (Incorporated by reference to Exhibit 10.22.5.10 to PrimeEnergy Corporation Form 10-Q for the quarter ended June 30, 2010)
  10.22.5.11    Guaranty effective July 30, 2010, by PrimeEnergy Management Corporation, Prime Operating Company, Eastern Oil Well Service Company, Southwest Oilfield Construction Company, and EOWS Midland Company, in favor of Compass Bank (Incorporated by reference to Exhibit 10.22.5.11 to PrimeEnergy Corporation Form 10-Q for the quarter ended June 30, 2010)
  10.23.9    Ratification of and Amendment to Mortgage, Deed of Trust, Security Agreement, Financing Statement and Assignment of Production, dated effective February 24, 2010, by and between PrimeEnergy Corporation and PrimeEnergy Management Corporation and Compass Bank (successor in interest to Guaranty Bank, FSB) (Incorporated by reference to Exhibit 10.23.9 to PrimeEnergy Corporation Form 10-K for the year ended December 31, 2009)
  10.25    Credit Agreement dated as of June 1, 2006 (but effective for all purposes as of August 22, 2005), between Prime Offshore L.L.C. as Borrower and PrimeEnergy Corporation as Lender (Incorporated by reference to Exhibit 10.25 to PrimeEnergy Corporation Form 10-K for the year ended December 31, 2006)
  10.27.3    Subordinated Promissory Note dated effective March 31, 2008 in the face principal amount of up to $50,000,000 executed by Prime Offshore L.L.C. and payable to Artic Management Corporation. (Incorporated by reference to Exhibit 10.27.3 to PrimeEnergy Corporation Form 10-Q for the quarter ended June 30, 2008)
  10.27.3.2    Amended and Restated Loan Modification dated July 21, 2010, effective June 30, 2009, by and among Artic Management Corporation, Prime Offshore L.L.C. and PrimeEnergy Corporation. (Incorporated by reference to Exhibit 10.27.3.2 to PrimeEnergy Corporation Form 10-Q for the quarter ended June 30, 2010)
  10.27.3.3    Loan Modification dated January 10, 2011, effective January 3, 2010, by and among Artic Management Corporation, Prime Offshore L.L.C. and PrimeEnergy Corporation. (Incorporated by reference to Exhibit 10.27.3.3 to PrimeEnergy Corporation Form 10-K for the year ended December 31, 2010)

 

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  10.27.4    Mortgage, Deed of Trust, Security Agreement, Financing Statement and Assignment of Production Dated effective as of March 31, 2008 from Prime Offshore L.L.C. to Mathias Eckenstein TTEE for Artic Management Corporation (first lien). (Incorporated by reference to Exhibit 10.27.4 to PrimeEnergy Corporation Form 10-Q for the quarter ended June 30, 2008)
  10.27.5    Mortgage, Deed of Trust, Security Agreement, Financing Statement and Assignment of Production Dated effective as of March 31, 2008 from Prime Offshore L.L.C. to Mathias Eckenstein TTEE for Artic Management Corporation (second lien). (Incorporated by reference to Exhibit 10.27.5 to PrimeEnergy Corporation Form 10-Q for the quarter ended June 30, 2008)
  10.27.6    Pledge Agreement dated as effective March 31, 2008 between Prime Offshore L.L.C. and Artic Management Corporation (General Partner Interest in FWOE Partners L.P.) (Incorporated by reference to Exhibit 10.27.6 to PrimeEnergy Corporation Form 10-Q for the quarter ended June 30, 2008)
  10.27.7    Pledge Agreement made effective June 30, 2009, by and between Prime Offshore L.L.C. and Guaranty Bank, FSB, as Agent. (Incorporated by reference to Exhibit 10.27.7 to PrimeEnergy Corporation Form 10-Q for the quarter ended June 30, 2009)
  10.27.8    Subordination of Liens and Security Interests effective June 30, 2009, by Artic Management Corporation for the benefit of Guaranty Bank, FSB, as Agent. (Incorporated by reference to Exhibit 10.27.8 to PrimeEnergy Corporation Form 10-Q for the quarter ended June 30, 2009)
  10.28    Completion and Liquidity Maintenance Agreement effective as of June 29, 2006, between PrimeEnergy Corporation, Guaranty Bank, FSB, and Prime Offshore, L.L.C. (Incorporated by reference to Exhibit 10.28 to PrimeEnergy Corporation Form 10-K for the year ended December 31, 2006)
  10.29    Put Right Agreement effective as of June 29, 2006, by and among PrimeEnergy Corporation and Prime Offshore L.L.C. (Incorporated by reference to Exhibit 10.29 to PrimeEnergy Corporation Form 10-K for the year ended December 31, 2006)
  31.1    Certification of Chief Executive Officer pursuant to Rule 13(a)-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended (filed herewith).
  31.2    Certification of Chief Financial Officer pursuant to Rule 13(a)-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended (filed herewith).
  32.1    Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (filed herewith).
  32.2    Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (filed herewith).
  101.INS*    XBRL (eXtensible Business Reporting Language) Instance Document
  101.SCH*    XBRL Taxonomy Extension Schema Document
  101.CAL*    XBRL Taxonomy Extension Calculation Linkbase Document
  101.DEF*    XBRL Taxonomy Extension Definition Linkbase Document
  101.LAB*    XBRL Taxonomy Extension Label Linkbase Document
  101.PRE*    XBRL Taxonomy Extension Presentation Linkbase Document

 

* XBRL information (the Interactive Date File) is deemed not filed for purposes of Sections 11 and 12 of the Securities Act of 1933 and Section 18 of the Securities Exchange Act of 1934.

 

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SIGNATURES

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

 

   PrimeEnergy Corporation
   (Registrant)
August 15, 2011   

  /s/ Charles E. Drimal, Jr.

(Date)      Charles E. Drimal, Jr.
     President
     Principal Executive Officer
August 15, 2011   

  /s/ Beverly A. Cummings

(Date)      Beverly A. Cummings
     Executive Vice President
     Principal Financial Officer

 

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