-----BEGIN PRIVACY-ENHANCED MESSAGE----- Proc-Type: 2001,MIC-CLEAR Originator-Name: webmaster@www.sec.gov Originator-Key-Asymmetric: MFgwCgYEVQgBAQICAf8DSgAwRwJAW2sNKK9AVtBzYZmr6aGjlWyK3XmZv3dTINen TWSM7vrzLADbmYQaionwg5sDW3P6oaM5D3tdezXMm7z1T+B+twIDAQAB MIC-Info: RSA-MD5,RSA, K8rdcXUtFZZKMGL8M8R/6wGhPUuFmzqNs6zVviogXOx3ixYTk7ygKO92SGBAijNK AK9l8at3sxXuDU7OVn0XTQ== 0000950129-99-003577.txt : 19990813 0000950129-99-003577.hdr.sgml : 19990813 ACCESSION NUMBER: 0000950129-99-003577 CONFORMED SUBMISSION TYPE: 10-Q PUBLIC DOCUMENT COUNT: 3 CONFORMED PERIOD OF REPORT: 19990630 FILED AS OF DATE: 19990812 FILER: COMPANY DATA: COMPANY CONFORMED NAME: POGO PRODUCING CO CENTRAL INDEX KEY: 0000230463 STANDARD INDUSTRIAL CLASSIFICATION: CRUDE PETROLEUM & NATURAL GAS [1311] IRS NUMBER: 741659398 STATE OF INCORPORATION: DE FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 10-Q SEC ACT: SEC FILE NUMBER: 001-07792 FILM NUMBER: 99684678 BUSINESS ADDRESS: STREET 1: 5 GREENWAY PLAZA STE 2700 STREET 2: P O BOX 2504 CITY: HOUSTON STATE: TX ZIP: 77046-0504 BUSINESS PHONE: 7132975017 MAIL ADDRESS: STREET 1: 5 GREENWAY PLAZA SUITE 2700 STREET 2: P O BOX 2504 CITY: HOUSTON STATE: TX ZIP: 77046-0504 FORMER COMPANY: FORMER CONFORMED NAME: PENNZOIL OFFSHORE GAS OPERATORS INC /TX/ DATE OF NAME CHANGE: 19600201 10-Q 1 POGO PRODUCING COMPANY - DATED JUNE 30, 1999 1 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, 1999 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 1-7792 POGO PRODUCING COMPANY (Exact Name of Registrant as Specified in Its Charter) DELAWARE 74-1659398 (State or Other Jurisdiction of (I.R.S. Employer Incorporation or Organization) Identification No.) 5 GREENWAY PLAZA, SUITE 2700 HOUSTON, TEXAS 77046-0504 (Address of principal executive offices) (Zip Code) (713) 297-5000 - ------------------------------------------------------------------------------- (Registrant's Telephone Number, Including Area Code) Not Applicable - ------------------------------------------------------------------------------- (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 requirement for the past 90 days: Yes X No ... Registrant's number of common shares outstanding as of June 30, 1999: 40,142,061 2 PART I. FINANCIAL INFORMATION POGO PRODUCING COMPANY AND SUBSIDIARIES Consolidated Statements of Income (Unaudited)
Three Months Ended Six Months Ended June 30, June 30, ------------------------ ------------------------ 1999 1998 1999 1998 --------- --------- --------- --------- (Expressed in thousands, except per share amounts) REVENUES: Oil and gas $ 43,159 $ 53,117 $ 80,894 $ 113,549 Pipeline sales and other 1,263 (442) 2,230 (213) Gains (losses) on sales 406 (12) 37,750 57 --------- --------- --------- --------- Total 44,828 52,663 120,874 113,393 --------- --------- --------- --------- OPERATING COSTS AND EXPENSES: Lease operating 12,817 16,075 28,159 32,584 Pipeline operating and natural gas purchases 1,336 -- 2,198 -- General and administrative 6,881 5,802 13,987 11,287 Exploration 1,374 2,002 3,139 5,834 Dry hole and impairment 791 1,470 1,030 2,778 Depreciation, depletion and amortization 23,394 28,358 47,245 58,818 --------- --------- --------- --------- Total 46,593 53,707 95,758 111,301 --------- --------- --------- --------- OPERATING INCOME (LOSS) (1,765) (1,044) 25,116 2,092 --------- --------- --------- --------- INTEREST: Charges (9,234) (5,209) (19,109) (11,277) Income 238 102 310 250 Capitalized 5,017 2,219 8,767 4,064 MINORITY INTEREST - Dividends and costs associated with preferred securities of a subsidiary trust (799) -- (799) -- FOREIGN CURRENCY TRANSACTION GAIN (LOSS) 460 (804) 409 193 --------- --------- --------- --------- INCOME (LOSS) BEFORE INCOME TAXES (6,083) (4,736) 14,694 (4,678) INCOME TAX BENEFIT (EXPENSE) 3,077 2,068 (3,387) 2,194 --------- --------- --------- --------- NET INCOME (LOSS) $ (3,006) $ (2,668) $ 11,307 $ (2,484) --------- --------- --------- --------- EARNINGS (LOSS) PER COMMON SHARE Basic $ (0.07) $ (0.07) $ 0.28 $ (0.07) ========= ========= ========= ========= Diluted $ (0.07) $ (0.07) $ 0.28 $ (0.07) ========= ========= ========= ========= DIVIDENDS PER COMMON SHARE $ 0.03 $ 0.03 $ 0.06 $ 0.06 ========= ========= ========= ========= WEIGHTED AVERAGE NUMBER OF COMMON SHARES AND POTENTIAL COMMON SHARES OUTSTANDING: Basic 40,141 37,560 40,138 36,353 Diluted 40,141 37,560 40,315 36,353
See accompanying notes to consolidated financial statements. - 1 - 3 POGO PRODUCING COMPANY AND SUBSIDIARIES Consolidated Balance Sheets
June 30, December 31, 1999 1998 ----------- ----------- (Unaudited) (Expressed in thousands except share amounts) ASSETS CURRENT ASSETS: Cash and cash investments $ 43,069 $ 7,959 Accounts receivable 25,806 24,054 Other receivables 25,520 38,977 Inventory - Product 1,656 969 Inventories - Tubulars 13,242 10,594 Other 2,378 2,814 ----------- ----------- Total current assets 111,671 85,367 ----------- ----------- PROPERTY AND EQUIPMENT: Oil and gas, on the basis of successful efforts accounting Proved properties being amortized 1,401,119 1,485,125 Unevaluated properties and properties under development, not being amortized 268,883 215,244 Pipelines, at cost 6,750 6,205 Other, at cost 12,411 11,710 ----------- ----------- 1,689,163 1,718,284 ----------- ----------- Accumulated depreciation, depletion and amortization Oil and gas (957,702) (985,897) Pipelines (1,415) (1,213) Other (6,557) (5,649) ----------- ----------- (965,674) (992,759) ----------- ----------- Property and equipment, net 723,489 725,525 ----------- ----------- OTHER ASSETS: Foreign taxes receivable 32,743 23,482 Debt issue expenses 13,143 7,727 Other 20,065 20,295 ----------- ----------- 65,951 51,504 ----------- ----------- $ 901,111 $ 862,396 =========== ===========
See accompanying notes to consolidated financial statements. - 2 - 4 POGO PRODUCING COMPANY AND SUBSIDIARIES Consolidated Balance Sheets
June 30, December 31, 1999 1998 ---------- ----------- (Unaudited) (Expressed in thousands except share amounts) LIABILITIES AND SHAREHOLDERS' EQUITY CURRENT LIABILITIES: Accounts payable - operating activities $ 15,613 $ 12,197 Accounts payable - investing activities 31,819 90,102 Accrued interest payable 8,623 3,226 Accrued dividends associated with preferred securities of a subsidiary trust 785 -- Accrued payroll and related benefits 2,165 1,952 Other 164 2 --------- --------- Total current liabilities 59,169 107,479 LONG-TERM DEBT 365,000 434,947 DEFERRED FEDERAL INCOME TAX 59,988 53,869 DEFERRED CREDITS 13,145 16,441 --------- --------- Total liabilities 497,302 612,736 --------- --------- MINORITY INTEREST: Company-obligated mandatorily redeemable convertible preferred securities of a subsidiary trust, net of unamortized issue expenses 145,044 -- --------- --------- SHAREHOLDERS' EQUITY: Preferred stock, $1 par; 2,000,000 shares authorized -- -- Common stock, $1 par; 100,000,000 shares authorized, 40,157,636 and 40,136,254 shares issued, respectively 40,157 40,136 Additional capital 290,713 290,655 Retained earnings (deficit) (70,700) (79,600) Treasury stock (15,575 shares) and other, at cost (1,405) (1,531) --------- --------- Total shareholders' equity 258,765 249,660 --------- --------- $ 901,111 $ 862,396 ========= =========
See accompanying notes to consolidated financial statements. - 3 - 5 POGO PRODUCING COMPANY AND SUBSIDIARIES Condensed Consolidated Statements of Cash Flows (Unaudited)
Six Months Ended June 30, ------------------------ 1999 1998 --------- --------- (Expressed in thousands) CASH FLOWS FROM OPERATING ACTIVITIES: Cash received from customers $ 80,740 $ 125,842 Operating, exploration, and general and administrative expenses paid (47,254) (50,313) Interest paid (12,645) (12,544) Federal income taxes received 6,446 -- Federal income taxes paid (8,000) -- Value added taxes paid (3,956) (3,376) Other 1,000 213 --------- --------- Net cash provided by operating activities 16,331 59,822 --------- --------- CASH FLOWS FROM INVESTING ACTIVITIES: Capital expenditures (129,179) (105,669) Purchase of proved reserves -- (2,961) Proceeds from the sale of properties 81,983 513 --------- --------- Net cash used in investing activities (47,196) (108,117) --------- --------- CASH FLOWS FROM FINANCING ACTIVITIES: Proceeds from issuance of new financing 300,000 -- Borrowings under senior debt agreements 250,053 196,954 Payments under senior debt agreements (470,000) (157,000) Payments of cash dividends on common stock (2,407) (2,200) Payment of financing issue expenses (11,425) -- Proceeds from exercise of stock options and other 59 880 --------- --------- Net cash provided by financing activities 66,280 38,634 --------- --------- EFFECT OF EXCHANGE RATE CHANGES ON CASH (305) 388 --------- --------- NET INCREASE (DECREASE) IN CASH AND CASH INVESTMENTS 35,110 (9,273) CASH AND CASH INVESTMENTS AT THE BEGINNING OF THE YEAR 7,959 19,646 --------- --------- CASH AND CASH INVESTMENTS AT THE END OF THE PERIOD $ 43,069 $ 10,373 ========= ========= RECONCILIATION OF NET INCOME (LOSS) TO NET CASH PROVIDED BY OPERATING ACTIVITIES: Net income (loss) $ 11,307 $ (2,484) Adjustments to reconcile net income (loss) to net cash provided by operating activities - Foreign currency transaction gains (409) (193) Gains from the sales of properties (37,750) (57) Depreciation, depletion and amortization 47,245 58,818 Dry hole and impairment 1,030 2,778 Interest capitalized (8,767) (4,064) Deferred federal income taxes 6,139 (746) Change in operating assets and liabilities (2,464) 5,770 --------- --------- NET CASH PROVIDED BY OPERATING ACTIVITIES $ 16,331 $ 59,822 ========= =========
See accompanying notes to consolidated financial statements. - 4 - 6 POGO PRODUCING COMPANY AND SUBSIDIARIES Consolidated Statements of Shareholders' Equity (Unaudited)
Six Months Ended June 30, ------------------------------------------------------------------ 1999 1998 ------------------------------ ------------------------------ Shares Amount Shares Amount ------------ ------------ ------------ ------------ (Expressed in thousands, except share amounts) COMMON STOCK: $1.00 par-100,000,000 shares authorized Balance at beginning of year 40,136,254 $ 40,136 33,552,702 $ 33,553 Conversion of 2004 Notes -- -- 3,879,726 3,880 Adjustment for fractional shares and other 13,132 13 -- -- Stock options exercised 8,250 8 143,517 143 ------------ ------------ ------------ ------------ Issued at end of period 40,157,636 40,157 37,575,945 37,576 ------------ ------------ ------------ ------------ ADDITIONAL CAPITAL: Balance at beginning of year 290,655 144,848 Conversion of 2004 Notes -- 80,712 Adjustment for fractional shares and other (13) -- Stock options exercised 71 1,782 ------------ ------------ Balance at end of period 290,713 227,342 ------------ ------------ RETAINED EARNINGS (DEFICIT): Balance at beginning of year (79,600) (31,971) Net income (loss) 11,307 (2,484) Dividends ($0.06 per common share) (2,407) (2,200) ------------ ------------ Balance at end of period (70,700) (36,655) ------------ ------------ TREASURY STOCK AND OTHER: Balance at beginning of year (15,575) (1,531) (15,575) (324) Activity during the period -- 126 -- -- ------------ ------------ ------------ ------------ Balance at end of period (15,575) (1,405) (15,575) (324) ------------ ------------ ------------ ------------ COMMON STOCK OUTSTANDING, AT THE END OF THE PERIOD 40,142,061 37,560,370 ============ ============ TOTAL SHAREHOLDERS' EQUITY $ 258,765 $ 227,939 ============ ============
See accompanying notes to consolidated financial statements. - 5 - 7 POGO PRODUCING COMPANY AND SUBSIDIARIES Notes to Consolidated Financial Statements (Unaudited) (1) GENERAL INFORMATION - The consolidated financial statements included herein have been prepared by Pogo Producing Company (the "Company") without audit and include all adjustments (of a normal and recurring nature) which are, in the opinion of management, necessary for the fair presentation of interim results which are not necessarily indicative of results for the entire year. Certain prior year amounts have been reclassified to conform with current year presentation. The financial statements should be read in conjunction with the consolidated financial statements, and notes thereto included in the Company's annual report on Form 10-K for the year ended December 31, 1998. (2) LONG-TERM DEBT - Long-term debt and the amount due within one year at June 30, 1999 and December 31, 1998, consist of the following:
June 30, December 31, 1999 1998 -------- -------- (Expressed in thousands) Senior debt - Bank revolving credit agreement LIBO Rate based loans, borrowings at an average interest rate of 7.4% $ -- $205,000 Uncommitted credit lines with banks, borrowings at an average interest rate of 6.1% -- 4,000 Banker's acceptance loans, borrowings at an average interest rate of 5.9% -- 10,947 -------- -------- Total senior debt -- 219,947 -------- -------- Subordinated debt - 8 3/4% Senior subordinated notes due 2007 ("2007 Notes") 100,000 100,000 10 3/8% Senior subordinated notes due 2009 ("2009 Notes") 150,000 -- 5 1/2% Convertible subordinated notes due 2006 ("2006 Notes") 115,000 115,000 -------- -------- Total subordinated debt 365,000 215,000 -------- -------- Long-term debt, none due within one year $365,000 $434,947 ======== ========
Refer to Note 3 of Notes to Consolidated Financial Statements included in the Company's annual report on Form 10-K for the year ended December 31, 1998, for a further discussion of the Company's uncommitted credit lines, the banker's acceptance loans, the 2007 Notes, the 2006 Notes, and the bank revolving credit agreement. On July 16, 1999, the Company and its lenders entered into an amendment to its amended and restated credit agreement which, in addition to other minor matters, extended the maturity date of the lenders' revolving loan commitments to July 1, 2001, and if applicable, their term loan commitments to July 2, 2003. On January 15, 1999, the Company issued $150,000,000 of 10 3/8% Senior Subordinated Notes, due 2009 (the "2009 Notes"). The proceeds from the issuance of the 2009 Notes were used to repay amounts outstanding under the Company's credit agreement. The 2009 Notes bear interest at a rate of 10 3/8%, and are payable semiannually in arrears on February 15 and August 15 of each year, commencing August 15, 1999. The 2009 Notes are general unsecured senior subordinated obligations of the Company, are subordinated in right of payment to the Company's senior indebtedness, which currently includes the Company's obligations under the credit agreement, its unsecured credit lines, and bankers acceptances, are equal in right of payment to the 2007 Notes, but are senior in right of payment to its subordinated indebtedness, which currently includes the 2006 Notes. The Company, at its option, may redeem the 2009 Notes in whole or in part, at any time on or after February 15, 2004, at a redemption price of 105.188% of their principal value and decreasing percentages thereafter. No sinking fund payments are required on the 2009 Notes. The 2009 Notes are redeemable at the option of any holder, upon the occurrence of a change in control (as defined in the indenture governing the 2009 Notes), at 101% of their principal amount. The indenture governing the 2009 Notes also imposes certain covenants on the Company that are similar to the covenants contained in the indenture governing the 2007 Notes, including covenants limiting: incurrence of indebtedness including senior indebtedness; restricted payments; the issuance and sales of restricted subsidiary capital stock; transactions with affiliates; liens; disposition of proceeds of asset sales; non-guarantor restricted subsidiaries; dividends and other payment restrictions affecting restricted subsidiaries; and mergers, consolidations and the sale of assets. As of June 30, 1999, $5,688,000 was available to the Company for common stock dividends under the covenant that restricts certain types of payments and distributions by the Company. - 6 - 8 POGO PRODUCING COMPANY AND SUBSIDIARIES Notes to Consolidated Financial Statements (Unaudited) (3) Minority Interest - Pogo Trust I, a business trust in which the Company owns all of the issued common securities (the "Trust"), issued $150,000,000 (3,000,000 securities having a liquidation preference of $50 each) of 6 1/2% Cumulative Quarterly Income Convertible Securities, Series A (the "Trust Preferred Securities") on June 2, 1999. The proceeds of the issuance of the Trust Preferred Securities were used to purchase $150,000,000 of the Company's 6 1/2% Junior Subordinated Convertible Debentures, due 2029 (the "Debentures"). The financial terms of the Debentures are generally the same as those of the Trust Preferred Securities. The Trust Preferred Securities accrue and pay distributions quarterly in arrears at a rate of 6 1/2% per annum on the stated liquidation amount of $50 per Trust Preferred Security on March 1, June 1, September 1, and December 1 of each year to security holders of record on the business day immediately preceding the distribution payment date. The Company has guaranteed, on a subordinated basis, distributions and other payments due on the Trust Preferred Securities to the extent that there are funds available in the Trust. The Company may cause the Trust to defer the payment of distributions for successive periods up to 20 consecutive periods unless an event of default on the Debentures has occurred and is continuing. During such periods, accrued distributions on the Trust Preferred Securities will compound quarterly and the Company will generally not be permitted to declare or pay distributions on its common stock or debt securities that rank equal or junior to the Debentures. The Trust Preferred Securities are convertible at the option of the holder at any time into common stock of the Company at the rate of 2.1053 shares of Company common stock per Trust Preferred Security. This conversion rate will be subject to adjustment to prevent dilution and is currently equivalent to a conversion price of $23.75 per share of Company common stock. The Trust Preferred Securities are mandatorily redeemable upon maturity of the Debentures on June 1, 2029, or to the extent of any earlier redemption of any Debenture by the Company and are callable by the Trust at any time after June 1, 2002. In addition, if the tax laws change so that the Trust becomes subject to federal income taxes or if interest payments made by the Company to the Trust or the Debentures are no longer deductible for federal income tax purposes, the Trust may liquidate and distribute Debentures to holders of the Trust Preferred Securities and, in certain circumstances, the Company may shorten the stated maturity of the Debentures to as early as June 2, 2014. The amounts recorded for the second quarter and first six months of 1999 under Minority Interests - Dividends and Costs Associated with Preferred Securities of a Subsidiary Trust principally reflect cumulative unpaid dividends and, to a lesser extent, the amortization of issuance expenses related to the offering and sale of the Trust Preferred Securities. - 7 - 9 POGO PRODUCING COMPANY AND SUBSIDIARIES Notes to Consolidated Financial Statements (Unaudited) (4) GEOGRAPHIC SEGMENT REPORTING - The Company's long-lived assets, revenues and operating income (loss) by segment and geographic area are as follows:
COMPANY OIL AND GAS PIPELINES OTHER --------- ----------- --------- --------- (Expressed in thousands) LONG-LIVED ASSETS: As of June 30, 1999: United States $ 482,378 $ 473,271 $ 5,335 $ 3,772 Kingdom of Thailand 236,258 234,223 -- 2,035 Canada 4,853 4,806 -- 47 --------- --------- --------- --------- Total $ 723,489 $ 712,300 $ 5,335 $ 5,854 ========= ========= ========= ========= As of December 31, 1998: United States $ 502,787 $ 493,633 $ 4,992 $ 4,162 Kingdom of Thailand 209,552 207,756 -- 1,796 Canada 13,186 13,083 -- 103 --------- --------- --------- --------- Total $ 725,525 $ 714,472 $ 4,992 $ 6,061 ========= ========= ========= ========= REVENUES: For the three months ended June 30, 1999 United States $ 38,969 $ 37,218 $ 1,482 $ 269 Kingdom of Thailand 4,959 5,042 -- (83) Canada 900 899 -- 1 --------- --------- --------- --------- Total $ 44,828 $ 43,159 $ 1,482 $ 187 ========= ========= ========= ========= For the three months ended June 30, 1998 United States $ 42,408 $ 42,884 $ -- $ (476) Kingdom of Thailand 10,255 10,233 -- 22 --------- --------- --------- --------- Total $ 52,663 $ 53,117 $ -- $ (454) ========= ========= ========= ========= For the Six months ended June 30, 1999 United States $ 108,856 $ 68,789 $ 2,472 $ 37,595 Kingdom of Thailand 10,114 10,187 -- (73) Canada 1,904 1,918 -- (14) --------- --------- --------- --------- Total $ 120,874 $ 80,894 $ 2,472 $ 37,508 ========= ========= ========= ========= For the Six months ended June 30, 1998 United States $ 93,331 $ 93,508 $ -- $ (177) Kingdom of Thailand 20,062 20,041 -- 21 --------- --------- --------- --------- Total $ 113,393 $ 113,549 $ -- $ (156) ========= ========= ========= ========= OPERATING INCOME (LOSS): For the three months ended June 30, 1999 United States $ 1,259 $ 1,157 $ (167) $ 269 Kingdom of Thailand (2,234) (2,151) -- (83) Canada (790) (791) -- 1 --------- --------- --------- --------- Total $ (1,765) $ (1,785) $ (167) $ 187 ========= ========= ========= ========= For the three months ended June 30, 1998 United States $ 805 $ 1,280 $ -- $ (475) Kingdom of Thailand (1,849) (1,870) -- 21 --------- --------- --------- --------- Total $ (1,044) $ (590) $ -- $ (454) ========= ========= ========= ========= For the six months ended June 30, 1999 United States $ 33,125 $ (4,397) $ (73) $ 37,595 Kingdom of Thailand (6,391) (6,318) -- (73) Canada (1,618) (1,604) -- (14) --------- --------- --------- --------- Total $ 25,116 $ (12,319) $ (73) $ 37,508 ========= ========= ========= ========= For the six months ended June 30, 1998 United States $ 4,836 $ 5,013 $ -- $ (177) Kingdom of Thailand (2,744) (2,765) -- 21 --------- --------- --------- --------- Total $ 2,092 $ 2,248 $ -- $ (156) ========= ========= ========= =========
-8- 10 POGO PRODUCING COMPANY AND SUBSIDIARIES Notes to Consolidated Financial Statements (Unaudited) (5) COMPREHENSIVE INCOME - During 1998, the Company adopted the Financial Accounting Standards Board's (FASB's) Statement of Financial Accounting Standards No. 130, Reporting Comprehensive Income ("SFAS 130"). Currently there are no significant amounts to be included in the computation of comprehensive income of the Company, as defined, that are required to be disclosed under the provisions of SFAS 130. The Company did report foreign currency translation gains of $12,000 and $126,000, respective for the three and six months ended June 30, 1999, which is reflected in shareholders' equity and represents less than 1% of the Company's reported pretax results for the three and six months ended June 30, 1999. As such, total comprehensive income (loss) and reported net income (loss) are materially the same for the three and six months periods ended June 30, 1999 and 1998. (6) IMPACT OF SFAS 133 - In June 1998, the FASB issued Statement of Financial Accounting Standards No. 133, Accounting for Derivative Instruments and Hedging Activities: ("SFAS 133"). SFAS 133 establishes accounting and reporting standards requiring that every derivative instrument (including certain derivative instruments embedded in other contracts) be recorded on the balance sheet as either an asset or liability measured at its fair market value and that changes in the derivative's fair market value be recognized currently in earnings unless specific hedge accounting criteria are met. SFAS 133 is effective for the Company in 2001 but early adoption is allowed. The Company has not yet quantified the impact of adopting SFAS 133 or determined the timing or method of adoption. However, SFAS 133 could increase volatility in earnings and other comprehensive income should the Company enter into transactions covered by the pronouncement. (7) EARNINGS PER SHARE - Earnings per common share (basic earnings per share) are based on the weighted average number of shares of common stock outstanding during the periods. Earnings per share and potential common share (diluted earnings per share) consider the effect of dilutive securities as set out below, in thousands, except per share amounts:
Three Months Ended Six Months Ended June 30, 1999 June 30, 1999 ----------------------------------- ----------------------------------- Income Shares Per Share Income Shares Per Share -------- -------- --------- -------- -------- --------- BASIC EARNINGS PER SHARE - $ (3,006) 40,141 $ (0.07) $ 11,307 40,121 $ 0.28 ========= ========= Effect of dilutive securities: Options to purchase common shares -- -- -- 17 -------- -------- -------- -------- DILUTED EARNINGS PER SHARE $ (3,006) 40,141 $ (0.07) $ 11,307 40,138 $ 0.28 ======== ======== ========= ======== ======== ========= Antidilutive securities - Options to purchase common shares -- 2,521 $ 19.35 -- 2,195 $ 21.14 2006 Notes 1,028 2,726 $ 0.38 2,056 2,726 $ 0.75 Trust Preferred Securities (a) 488 1,943 $ 0.25 490 977 $ 0.50
Three Months Ended Six Months Ended June 30, 1998 June 30, 1998 ----------------------------------- ----------------------------------- Income Shares Per Share Income Shares Per Share -------- -------- --------- -------- -------- --------- BASIC EARNINGS PER SHARE - $ (2,668) 37,560 $ (0.07) $ (2,484) 36,353 $ (0.07) ========= ========= Effect of dilutive securities: Options to purchase common shares -- -- -- -- -------- -------- -------- -------- DILUTED EARNINGS PER SHARE $ (2,668) 37,560 $ (0.07) $ (2,484) 36,353 $ (0.07) ======== ======== ========= ======== ======== ========= Antidilutive securities - Options to purchase common shares -- 1,870 $ 26.55 -- 1,870 $ 26.55 2004 Notes (b) -- -- -- 476 1,200 $ 0.40 2006 Notes 1,028 2,726 $ 0.38 2,056 2,726 $ 0.75
(a) The Trust Preferred Securities were issued on June 2, 1999. (b) The 2004 Notes were converted to common stock or called in the first quarter of 1998. -9- 11 POGO PRODUCING COMPANY AND SUBSIDIARIES Management's Discussion and Analysis of Financial Condition and Results of Operations This discussion should be read in conjunction with Management's Discussion and Analysis of Financial Condition and Results of Operations included in the Company's annual report on Form 10-K for the year ended December 31, 1998. Certain statements contained herein are "Forward Looking Statements" and are thus prospective. As further discussed in the Company's annual report on Form 10-K for the year ended December 31, 1998, such forward-looking statements are subject to risks, uncertainties and other factors that could cause actual results to differ materially from future results expressed or implied by such forward-looking statements. RESULTS OF OPERATIONS Net income The Company reported a net loss for the second quarter of 1999 of $3,006,000 or $0.07 per share (on both a basic and a diluted basis), compared to a net loss for the second quarter of 1998 of $2,668,000 or $0.07 per share (on both a basic and a diluted basis). For the first six months of 1999, the Company reported net income of $11,307,000 or $0.28 per share (on both a basic and a diluted basis) compared to a net loss for the first six months of 1998 of $2,484,000 or $0.07 per share (on both a basic and a diluted basis). The increase in net income during the first six months of 1999, compared to the first six months of 1998, was primarily related to a net gain recognized by the Company from the sale of certain properties, including the previously announced sale of the Lopeno Field in South Texas, most of which occurred in the first quarter of 1999. These property sales were part of an effort by the Company to sell its non-strategic and/or underperforming properties to generate cash and maximize its focus on properties with greater exploration potential. If the gain of $37,750,000 related to the sale of such properties is excluded, the Company would have reported a net loss for the first six months of $13,231,000 or $0.33 per share (on both a basic and a diluted basis). Earnings per common share are based on the weighted average number of common shares outstanding for the respective periods. The increase in the weighted average number of common shares outstanding for the second quarter of 1999, compared to the second quarter of 1998, resulted primarily from the issuance as of August 17, 1998 of approximately 2,500,000 shares of common stock to former holders of Arch capital stock and convertible debt securities in connection with the Company's acquisition of Arch Petroleum Inc. ("Arch") and, to a lesser extent, the issuance of common stock upon the exercise of stock options pursuant to the Company's incentive plans. The increase in the weighted average number of common shares outstanding for the first six months of 1999, compared to the first six months of 1998, also reflects the issuance of approximately 3,900,000 shares of the Company's common stock upon the conversion of the Company's 5 1/2% Convertible Subordinated Notes due 2004 (the "2004 Notes") prior to their being redeemed on March 16, 1998. The earnings per share computation on a diluted basis in the periods presented also reflects additional shares of common stock issuable upon the assumed exercise of options to purchase common shares under the Company's incentive plans, less treasury shares that are assumed to have been purchased by the Company from the option proceeds. Total Revenues The Company's total revenues for the second quarter of 1999 were $44,828,000, a decrease of approximately 15% from total revenues of $52,663,000 for the second quarter of 1998. The decrease in the Company's total revenues for the second quarter of 1999, compared to the second quarter of 1998, resulted primarily from a substantial decrease in oil and gas revenues that was only partially offset by pipeline sales related to the Saginaw pipeline, which was acquired as part of the Arch acquisition. The Company's total revenues for the first six months of 1999 were $120,874,000, an increase of approximately 7% compared to total revenues of $113,393,000 for the first six months of 1998. The increase in the Company's total revenues for the first six months of 1999, compared to the first six months of 1998, resulted primarily from the gains related to the previously discussed sale of oil and gas properties and, to a lesser extent, pipeline sales revenues resulting from the acquisition of the Saginaw pipeline. -10- 12 POGO PRODUCING COMPANY AND SUBSIDIARIES Management's Discussion and Analysis of Financial Condition and Results of Operations Oil and Gas Revenues The Company's oil and gas revenues for the second quarter of 1999 were $43,159,000, a decrease of approximately 19% from oil and gas revenues of $53,117,000 for the second quarter of 1998. The Company's oil and gas revenues for the first six months of 1999 were $80,894,000, a decrease of approximately 29% from oil and gas revenues of $113,549,000 for the first six months of 1998. The following table reflects an analysis of variances in the Company's oil and gas revenues (expressed in thousands) between 1999 and 1998:
Increase (decrease) in oil and gas revenues 2ND QTR 1999 1ST HALF 1999 resulting from variances in: COMPARED TO COMPARED TO 2ND QTR 1998 1ST HALF 1998 ------------ ------------- NATURAL GAS -- Price ............................................ $ (798) $ (7,033) Production ....................................... (8,460) (17,070) -------- -------- (9,258) (24,103) -------- -------- CRUDE OIL AND CONDENSATE -- Price ............................................ 4,276 442 Production ....................................... (4,771) (5,777) -------- -------- (495) (5,335) -------- -------- NATURAL GAS LIQUIDS ("NGL") ......................... (205) (3,217) -------- -------- Increase (decrease) in oil and gas revenues ...... $ (9,958) $(32,655) ======== ========
The decrease in the Company's oil and gas revenues for the second quarter and first six months of 1999, compared to the second quarter and first six months of 1998, is primarily related to declines in the Company's natural gas and oil, condensate and NGL ("liquid hydrocarbons") production volumes and, to a lesser extent, a decrease in the price that it received for its natural gas production volumes, which was only partially offset by increases in the average price that the Company received for its crude oil and condensate production volumes.
Comparison of Increases (Decreases) in: 2ND QUARTER 1ST SIX MONTHS NATURAL GAS -- ------------------- % ------------------ % 1999 1998 CHANGE 1999 1998 CHANGE ------- ------- ------- ------- ------- ------- Average prices North America (a)........................................ $ 2.18 $ 2.18 -- $ 1.96 $ 2.18 (10%) Kingdom of Thailand(b)................................... $ 1.34 $ 1.73 (23%) $ 1.43 $ 1.73 (17%) Company-wide average price.......................... $ 2.02 $ 2.07 (2%) $ 1.86 $ 2.08 (11%) Average daily production volumes (MMcf per day) North America (a)........................................ 96.5 126.4 (24%) 101.7 135.9 (25%) Kingdom of Thailand...................................... 23.0 39.1 (41%) 24.2 40.7 (41%) ------- ------- ------- ------- Company-wide average daily production............... 119.5 165.5 (28%) 125.9 176.6 (29%) ======= ======= ======= =======
- ---------------------------- (a) North American average prices and production reflect production from the United States and Canada for the second quarter and first six months of 1999, but only production from the United States for the second quarter and first six months of 1998. The Company acquired its interests in Canada as part of the Arch acquisition which closed during the third quarter of 1998. "MMcf" and "Bbls" stand for million cubic feet and barrels, respectively. (b) The Company is paid for its natural gas production in the Kingdom of Thailand in Thai Baht. The average prices are presented in dollars based on the revenue recorded in the Company's financial records. The average price that the Company received for its natural gas production in the Kingdom of Thailand during the second quarter and first six months of 1999 reflects the impact of the penalty provisions of the Company's gas sales agreement with the Petroleum Authority of Thailand due to the Company's failure to meet its minimum contractual delivery obligations. -11- 13 POGO PRODUCING COMPANY AND SUBSIDIARIES Management's Discussion and Analysis of Financial Condition and Results of Operations
Comparison of Increases (Decreases) in: 2ND QUARTER 1ST SIX MONTHS CRUDE OIL AND CONDENSATE -- ------------------- % ------------------ % 1999 1998 CHANGE 1999 1998 CHANGE ------- ------- ------- ------- ------- ------- Average prices North America(a)....................................... $ 15.99 $ 12.84 25% $ 13.71 $ 13.77 -- Kingdom of Thailand.................................... $ 18.45 $ 16.05 15% $ 16.38 $ 14.00 17% Company-wide average price............................ $ 16.24 $ 13.38 21% $ 13.96 $ 13.81 1% Average daily production volumes (Bbls per day) North America(a)....................................... 11,893 13,665 (13%) 12,662 13,413 (6%) Kingdom of Thailand ................................... 1,331 2,786 (52%) 1,329 2,864 (54%) ------- ------- ------- ------- Company-wide average daily production................. 13,224 16,451 (20%) 13,991 16,277 (14%) ======= ======= ======= ======= TOTAL LIQUID HYDROCARBONS -- Company-wide average daily production (Bbls per day) 14,824 18,369 (19%) 15,875 19,375 (18%) ======= =======
- -------------------------- (a) North American average prices and production reflect production from the United States and Canada for the second quarter and first six months of 1999, but only production from the United States for the second quarter and first six months of 1998. The Company acquired its interests in Canada as part of the Arch acquisition which closed during the third quarter of 1998. "MMcf" and "Bbls" stand for million cubic feet and barrels, respectively. Natural Gas Thailand Prices. The price that the Company receives under the Gas Sales Agreement with the Petroleum Authority of Thailand ("PTT") is subject to a penalty provision if the Company does not meet the minimum delivery requirements set forth in the agreement. Commencing on October 1, 1998, and continuing throughout the first six months of 1999, the Company and its joint venture partners have not met the contractual minimum delivery requirements under the Gas Sales Agreement. This has permitted PTT to reduce the price it pays on a portion of the natural gas which the Company has sold to PTT by 25% from the then current contract price. If these penalty provisions had not been in effect, the average price that the Company would have received for its production in the Kingdom of Thailand for the second quarter and first six months of 1999 would have been approximately $1.71 and $1.73, respectively. Since production commenced from new facilities installed in the Tantawan and Benchamas Fields, the Company has generally been able to meet its contractual delivery obligations to PTT and is not experiencing a penalty under the Gas Sales Agreement. Production. The decrease in the Company's natural gas production during the second quarter and first six months of 1999, compared to the second quarter and first six months of 1998, was related in large measure to decreased production from the Company's East Cameron Block 334 "E" platform, the sale of the Lopeno Field and decreased production from the Tantawan Field in the Kingdom of Thailand that was partially attributable to extended periods during which the Tantawan Field platforms were shut-in during an in-fill drilling program. The decline in the Company's natural gas production was partially offset by successful development of the Company's Garden Banks Block 367 and Main Pass Block 226 field, its continued successful offshore and onshore drilling and workover program, and production from properties that the Company acquired in its acquisition of Arch, including its Canadian properties. The Company currently anticipates that with the recent completion of an in-fill drilling program in the Tantawan Field and the commencement of production from the Benchamas Field and a new platform in the Tantawan Field, the Company's natural gas production from the Kingdom of Thailand should increase significantly during the third quarter of 1999, as compared with the second quarter of 1999. As of August 1, 1999, the Company was not a party to any future natural gas sales contracts. -12- 14 POGO PRODUCING COMPANY AND SUBSIDIARIES Management's Discussion and Analysis of Financial Condition and Results of Operations Crude Oil and Condensate Thailand Prices. Since the inception of production from the Tantawan Field, crude oil and condensate has been stored on a Floating Production, Storage and Offloading system until an economic quantity was accumulated for offloading and sale. Prices that the Company receives for its crude oil and condensate production from Thailand are based on world benchmark prices, which are denominated in dollars. In addition, the Company is generally paid for its crude oil and condensate production from Thailand in U.S. dollars. Production. The decrease in the Company's North American crude oil and condensate production during the second quarter and first six months of 1999, compared to the second quarter and first six months of 1998, resulted from the anticipated natural decline in oil and condensate production from certain of the Company's offshore properties, that was partially offset by increased production from the Company's Permian basin properties due to an active workover and recompletion program that commenced in late 1998 and additional production from properties acquired in the Arch acquisition.. The decrease in the Company's crude oil and condensate production from the Tantawan Field declined, in part, due to disappointing reservoir performance and, in part, due to the need to shut-in production from platforms during the in-fill drilling program that commenced during the first quarter of 1999 and was recently completed. The Company currently anticipates that with the recent completion of the in-fill drilling program in the Tantawan Field and the commencement of production from the Benchamas Field and a new platform in the Tantawan Field, the Company's crude oil and condensate production from the Kingdom of Thailand should increase significantly during the third quarter of 1999, as compared with the second quarter of 1999. As of August 1, 1999, the Company was not a party to any crude oil swaps or futures contracts. NGL Production. The Company's oil and gas revenues, and its total liquid hydrocarbon production, reflect the production and sale by the Company of NGL, which are liquid products extracted from natural gas production. The decrease in NGL revenues for the second quarter of 1999, compared with the second quarter of 1998, related to a decrease in the Company's NGL production volumes, that was only partially offset by an increase in the average price that the Company received for its NGL production. The decrease in NGL revenues for the first six months of 1999, compared with the first six months of 1998, related to a decrease in the Company's NGL production volumes and, to a lesser extent to a decrease in the average price that the Company received for its NGL production. Costs and Expenses
2ND QUARTER 1ST SIX MONTHS Comparison of Increases (Decreases) in: --------------------------- % --------------------------- % 1999 1998 CHANGE 1999 1998 CHANGE ----------- ----------- ------ ----------- ----------- ------ LEASE OPERATING EXPENSES North America.......................... $11,353,000 $10,479,000 8% $22,586,000 $22,726,000 (1%) Kingdom of Thailand.................... $ 1,464,000 $ 5,596,000 (74%) $ 5,573,000 $ 9,858,000 (43%) Total Lease Operating Expenses... $12,817,000 $16,075,000 (20%) $28,159,000 $32,584,000 (14%) Pipeline Operating and Natural Gas Purchases .......................... $ 1,336,000 -- N/A $ 2,198,000 -- N/A GENERAL AND ADMINISTRATIVE EXPENSES....... $ 6,881,000 $ 5,802,000 19% $13,987,000 $11,287,000 24% EXPLORATION EXPENSES...................... $ 1,374,000 $ 2,002,000 (31%) $ 3,139,000 $ 5,834,000 (46%) DRY HOLE AND IMPAIRMENT EXPENSES.......... $ 791,000 $ 1,470,000 (46%) $ 1,030,000 $ 2,778,000 (63%) DEPRECIATION, DEPLETION AND AMORTIZATION (DD&A) EXPENSES........... $23,394,000 $28,358,000 (18%) $47,245,000 $58,818,000 (20%) DD&A rate ............................. $ 1.20 $ 1.12 8% $ 1.11 $ 1.10 -- Mcfe produced (a)...................... 18,965,000 25,087,000 (24%) 40,033,000 53,009,000 (24%)
- ----------------------------- (a) "Mcfe" stands for thousands of cubic feet equivalent. -13- 15 POGO PRODUCING COMPANY AND SUBSIDIARIES Management's Discussion and Analysis of Financial Condition and Results of Operations
2ND QUARTER 1ST SIX MONTHS Comparison of Increases (Decreases) in: --------------------------- % --------------------------- % 1999 1998 CHANGE 1999 1998 CHANGE ----------- ----------- ------ ----------- ----------- ------ INTEREST-- Charges.................................... $ 9,234,000 $ 5,209,000 77% $19,109,000 $11,277,000 69% Interest Income............................ $ 238,000 $ 102,000 133% $ 310,000 $ 250,000 24% Capitalized Interest Expense............... $ 5,017,000 $ 2,219,000 126% $ 8,767,000 $ 4,064,000 116% MINORITY INTEREST - Dividends and costs Associated with Preferred Securities of a Subsidiary Trust ........................ $ (799) -- N/A $ (799) -- N/A FOREIGN CURRENCY TRANSACTION GAIN (LOSS)................................. $ 460,000 $ (804,000) N/A $ 409,000 $ 193,000 112% INCOME TAX BENEFIT (EXPENSE).................. $ 3,077,000 $ 2,068,000 49% $(3,387,000) $ 2,194,000 N/A
Lease Operating Expenses. The increase in North American lease operating expenses for the second quarter of 1999, compared to the second quarter of 1998, was primarily related to increased operating expenses related to properties acquired in the Arch acquisition for which no similar expenses were incurred during the second quarter of 1998, that was not entirely offset by the results of a company-wide cost reduction program. The decrease in North American lease operating expenses for the first six months of 1999, compared to the first six months of 1998, was primarily related to a non-recurring maintenance project on the Company's East Cameron 334 "E" platform that occurred during the first six months of 1998 for which no similar expenses were incurred during the first six months of 1999 and, to a lesser extent, the results of a company-wide cost reduction program and decreased severance taxes. The decrease in Thailand lease operating expenses for the second quarter and first six months of 1999, compared to the second quarter and first six months of 1998, related to recognition of previously deferred billings to third parties and, to a lesser extent, to an ongoing cost reduction program. Pipeline Operating and Natural Gas Purchases The Company acquired the Saginaw pipeline as part of its acquisition of Arch in August 1998. Consequently, prior to that time the Company did not separately report its pipeline operating expenses, nor did it purchase any natural gas for resale to customers of its pipelines. General and Administrative Expenses The increase in general and administrative expenses for the second quarter and first six months of 1999, compared with the second quarter and first six months of 1998, was primarily related to an increase in the size of the Company's work force due to the Arch acquisition and, to a lesser extent increased legal fees and expenses. Exploration Expenses Exploration expenses consist primarily of rental payments required under oil and gas leases to hold non-producing properties ("delay rentals") and exploratory geological and geophysical costs which are expensed as incurred. The decrease in exploration expense for the second quarter and first six months of 1999, compared to the second quarter of and first six months of 1998, resulted primarily from generally decreased geophysical activity by the Company in most of its operational areas. except Canada, where the Company participated in a significant 3-D survey during the first quarter of 1999. -14- 16 POGO PRODUCING COMPANY AND SUBSIDIARIES Management's Discussion and Analysis of Financial Condition and Results of Operations Depreciation, Depletion and Amortization Expenses The decrease in the Company's depreciation, depletion and amortization ("DD&A") expense for the second quarter and first six months of 1999, compared to the second quarter and first six months of 1998, resulted primarily from a decrease in the Company's natural gas and liquid hydrocarbon production, that was only partially offset by an increase in the Company's composite DD&A rate. The increase in the composite DD&A rate for all of the Company's producing fields for the second quarter and first six months of 1999, compared to the second quarter and first six months of 1998, resulted primarily from an increased percentage of the Company's production coming from certain of the Company's fields that have DD&A rates that are higher than the Company's recent historical composite rate and a corresponding decrease in the percentage of the Company's production coming from fields that have DD&A rates that are lower than the Company's recent historical composite DD&A rate. Management currently anticipates that this trend will continue for the foreseeable future, resulting in generally increasing DD&A rates. Interest Interest Charges. The increase in the Company's interest charges for the second quarter and first six months of 1999, compared to the second quarter and first six months of 1998, resulted primarily from an increase in the average amount of the Company's outstanding debt and, to a lesser extent, increased average interest rates on the debt outstanding (resulting primarily from the issuance of the 10 3/8% Senior Subordinated Notes due 2009 (the "2009 Notes") on January 15, 1999). As of August 1,1999, the Company was not a party to any interest rate swap agreements. Capitalized Interest. The increase in capitalized interest for the second quarter and first six months of 1999, compared to the second quarter and first six months of 1998, resulted primarily from an increase in the amount of capital expenditures subject to interest capitalization during the second quarter and first six months of 1999 ($248,340,000 and $218,044,000 , respectively), compared to the second quarter and first six months of 1998 ($129,098,000 and $118,084,000, respectively), and from an increase in the computed rate that the Company uses to apply to such capital expenditures to arrive at the total amount of capitalized interest. A substantial percentage of the Company's capitalized interest expense resulted from capitalization of interest related to capital expenditures for the development of the Benchamas Field in the Gulf of Thailand and, to a lesser extent, several development projects in the Gulf of Mexico. With the completion of the Benchamas Field in the third quarter of 1999, and the completion of the Company's construction project at Garden Banks Block 367 in the Gulf of Mexico in second quarter of 1999, management currently expects that capitalized interest expense should decrease significantly in the next several quarters. Minority Interest -- Dividends and Costs Associated with Preferred Securities of a Subsidiary Trust Pogo Trust I, a business trust in which the Company owns all of the issued common securities, issued $150,000,000 of 6 1/2% Cumulative Quarterly Income Convertible Preferred Securities, Series A (the "Trust Preferred Securities") on June 2, 1999. The amounts recorded for the second quarter and first six months of 1999 under Minority Interest -- Dividends and Costs Associated with Preferred Securities of a Subsidiary Trust principally reflect cumulative unpaid dividends and, to a lesser extent, the amortization of issuance expenses related to the offering and sale of the Trust Preferred Securities. Foreign Currency Transaction Gain (Loss) The foreign currency transaction gain and loss each resulted primarily from the fluctuation against the U.S. dollar of cash and other monetary assets and liabilities denominated in Thai Baht that were on the Company's -15- 17 POGO PRODUCING COMPANY AND SUBSIDIARIES Management's Discussion and Analysis of Financial Condition and Results of Operations subsidiary's financial statements during the respective periods. In early July 1997, the government of the Kingdom of Thailand announced that the value of the Baht would be set against the dollar and other currencies under a "managed float" program arrangement. The Company cannot predict what the Thai Baht to U. S. dollar exchange rate may be in the future. Moreover, it is anticipated that this exchange rate will remain volatile. As of August 1, 1999, the Company was not a party to any financial instrument that was intended to constitute a foreign currency hedging arrangement. Income Tax Benefit (Expense) The increase in the Company's income tax benefit for the second quarter of 1999, compared to the second quarter of 1998, resulted primarily from decreased income and the tax benefit of accrued foreign losses from the Company's operations in the Kingdom of Thailand. The Company's income tax expense for the first six months of 1999, compared to its income tax benefit for the first six months of 1998, resulted primarily from a pre-tax gain on the sale of the Lopeno Field, that was only partially offset by substantially lower revenues in the United States and the tax benefit of accrued foreign losses from the Company's operations in the Kingdom of Thailand. LIQUIDITY AND CAPITAL RESOURCES Cash Flows The Company's Condensed Consolidated Statement of Cash Flows for the first six months of 1999 reflects net cash provided by operating activities of $16,331,000. In addition to net cash provided by operating activities, the Company received $81,983,000 from the sale of certain non-strategic and/or underperforming properties, proceeds of $300,000,000 from the sale of Trust Preferred Securities and 2009 Notes and net proceeds of $59,000 from the exercise of stock options. During the second quarter of 1999, the Company invested $129,179,000 of such cash flow in capital projects, repaid a net $219,947,000 under its senior debt arrangements, paid $11,425,000 in financing issuance expenses and paid $2,407,000 (two quarterly dividends of $0.03 per share) in cash dividends to holders of the Company's common stock. As of June 30, 1999, the Company's cash and cash investments were $43,069,000, its long-term debt stood at $365,000,000 and its net obligations on mandatorily redeemable convertible preferred securities of its subsidiary Pogo Trust I, were $145,044,000. Future Capital Requirements The Company's capital and exploration budget for 1999, which does not include any amounts that may be expended for the purchase of proved reserves or any interest which may be capitalized resulting from projects in progress, was recently increased by the Company's Board of Directors to $195,000,000. The Company currently anticipates that its available cash and cash investments, cash provided by operating activities, funds available under its credit agreement, uncommitted credit lines and banker's acceptance facilities will be sufficient to fund the Company's ongoing operating, interest and general and administrative expenses, any currently anticipated costs associated with the Company's projects during 1999, and future dividend payments at current levels (including a dividend payment of $0.03 per share to be paid on August 27, 1999 to shareholders of record on August 13, 1999). The declaration of future dividends on the Company's common stock will depend upon, among other things, the Company's future earnings and financial condition, liquidity and capital requirements, its ability to pay dividends under certain covenants contained in its debt instruments, the general economic and regulatory climate and other factors deemed relevant by the Company's Board of Directors. -16- 18 POGO PRODUCING COMPANY AND SUBSIDIARIES Management's Discussion and Analysis of Financial Condition and Results of Operations Capital Structure Credit Agreement. On July 16, 1999, the Company and its lenders entered into an amendment to its amended and restated credit agreement which, among other things, extended the maturity date of the lenders' revolving loan commitments to July 1, 2001, and, if applicable, their term loan commitments to July 2, 2003. Trust Preferred Securities. Pogo Trust I, a business trust in which the Company owns all of the issued common securities (the "Trust"), issued 3,000,000 Trust Preferred Securities having a liquidation preference of $50 per Trust Preferred Security, on June 2, 1999. The proceeds from the issuance of the Trust Preferred Securities were used to purchase $150,000,000 of the Company's 6 1/2% Junior Subordinated Convertible Debentures, due 2029 (the "Debentures"). The financial terms of the Debentures are generally the same as those of the Trust Preferred Securities. The Trust Preferred Securities accrue and pay distributions quarterly in arrears at a rate of 6 1/2% per annum on the stated liquidation amount of $50 per Trust Preferred Security on March 1, June 1, September 1, and December 1 of each year to securities holders of record on the business day immediately preceding the distribution payment date. The Company has guaranteed, on a subordinated basis, distributions and other payments due on the Trust Preferred Securities to the extent that there are funds available in the Trust. The Company may cause the Trust to defer the payment of distributions for successive periods up to 20 consecutive quarterly periods unless an event of default on the Debentures has occurred and is continuing. During such periods, accrued distributions on the Trust Preferred Securities will compound quarterly and the Company will generally not be permitted to declare or pay distributions on its common stock or debt securities that rank equal or junior to the Debentures. The Trust Preferred Securities are convertible at the option of the holder at any time into common stock of the Company at the rate of 2.1053 shares of Company common stock per Trust Preferred Security. This conversion rate will be subject to adjustment to prevent dilution and is currently equivalent to a conversion price of $23.75 per share of Company common stock. The Trust Preferred Securities are mandatorily redeemable upon maturity of the Debentures on June 1, 2029, or to the extent of any earlier redemption of any Debentures by the Company and are callable by the Trust at any time after June 1, 2002. In addition, if certain tax changes occur so that the Trust becomes subject to federal income taxes or interest payments made by the Company to the Trust on the Debentures are no longer deductible for federal income tax purposes, the Trust may liquidate and distribute Debentures to holders of the Trust Preferred Securities and, in certain circumstances, the Company may shorten the stated maturity of the Debentures to as early as June 2, 2014. Other Matters Year 2000 Readiness Disclosure. Information regarding the Company's Year 2000 readiness is contained in the Company's annual report on Form 10-K for the year ended December 31, 1998 and reference is made to the information contained there. There has been no material change in the Company's Year 2000 readiness since that information was disclosed. -17- 19 POGO PRODUCING COMPANY AND SUBSIDIARIES Management's Discussion and Analysis of Financial Condition and Results of Operations PART II. OTHER INFORMATION Item 4. Submission of Matters to a Vote of Security-Holders The registrant held its annual meeting of stockholders in Houston, Texas on April 27, 1999. The following sets forth the items that were put to a vote of the stockholders and the results thereof concerning: (A) the election of three directors, each for a term of three years. Proxies for the meeting were solicited pursuant to Regulation 14A under the Securities Exchange Act of 1934. There were no solicitations in opposition to management's nominees as listed in the proxy statement and all such nominees were elected; (B) the appointment of Arthur Andersen LLP, independent public accountants, to audit the financial statements of the registrant for the year 1999, with 35,459,930 shares of stock cast for the appointment, 25,805 against the appointment, and 27,650 abstentions and broker non-votes. Item 6. Exhibits and Reports on Form 8-K (A) Exhibits 4.1 -- Second Amendment dated July 16, 1999, to Amended and Restated Credit Agreement dated as of August 1, 1997 among Pogo Producing Company, certain commercial lending institutions, Bank of Montreal as the Agent and Banque Paribas as the Co-Agent. 27 -- Financial Data Schedule (B) Reports on Form 8-K Report filed on May 28, 1999, relating to the issuance of the Trust Preferred Securities and filing the final form of certain documents related therewith. -18- 20 POGO PRODUCING COMPANY AND SUBSIDIARIES Signatures Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. POGO PRODUCING COMPANY (Registrant) /s/ Thomas E. Hart ------------------------- Thomas E. Hart Vice President and Chief Accounting Officer /s/ John W. Elsenhans ------------------------- John W. Elsenhans Vice President and Chief Financial Officer Date: August 11, 1999 -19- 21 INDEX TO EXHIBITS
EXHIBIT NO. DESCRIPTION - ----------- ----------- 4.1 -- Second Amendment dated July 16, 1999, to Amended and Restated Credit Agreement dated as of August 1, 1997 among Pogo Producing Company, certain commercial lending institutions, Bank of Montreal as the Agent and Banque Paribas as the Co-Agent. 27 -- Financial Data Schedule
EX-4.1 2 SECOND AMEND. TO CREDIT AGREEMENT 1 EXHIBIT 4.1 ================================================================================ POGO PRODUCING COMPANY ---------------------- Second Amendment Dated as of July 16, 1999 to Amended and Restated Credit Agreement Dated as of August 1, 1997 ================================================================================ 2 SECOND AMENDMENT TO AMENDED AND RESTATED CREDIT AGREEMENT THIS SECOND AMENDMENT TO AMENDED AND RESTATED CREDIT AGREEMENT, dated as of July 16, 1999 (the "Amendment"), among POGO PRODUCING COMPANY, a Delaware corporation (the "Borrower"), the various financial institutions which are or may become parties to the Credit Agreement, as amended hereby (collectively, the "Lenders"), BANK OF MONTREAL, acting through its Chicago, Illinois branch, (the "Bank"), as administrative agent (the "Agent") for the Lenders, and PARIBAS, formerly known as Banque Paribas, as documentation agent (either the "Documentation Agent" or "Co-Agent", and together with the Agent, the "Agents"), for the Lenders, W I T N E S S E T H WHEREAS the Borrower, the Lenders and the Agents are parties to a certain Amended and Restated Credit Agreement, dated as of August 1, 1997, as previously amended (the "Credit Agreement"); and WHEREAS the Borrower desires to amend certain provisions of the Credit Agreement; NOW, THEREFORE, the parties hereto hereby agree as follows: 1. DEFINITIONS. Unless otherwise defined herein or the context otherwise requires, or except as the definition may be amended by this Amendment, terms used in this Amendment, including its preamble and recitals, shall have the meanings provided in the Credit Agreement, as hereby amended. 2. AMENDMENTS TO CREDIT AGREEMENT. (a) The definition of "Fixed Charges", "Guarantee", "Indebtedness", "Non-Standard Determination", "Senior Debt" and "Stated Maturity Date" appearing in Section 1.1 of the Credit Agreement is amended hereby in its entirety to the following: " "Fixed Charges" means, for any period, without duplication, the sum of (i) the total interest charges (including the interest component of capitalized leases) which, in accordance with GAAP, would be included on the consolidated statements of income for the Borrower, its Subsidiaries and Affiliates, for such period, net of interest income, plus (ii) dividends paid by the Borrower on its preferred and preference stock during such period plus (iii) the current portion of Specified Debt (including Non-Recourse Indebtedness but excluding current maturities of any Loan outstanding hereunder) and the current portion of production payments to be paid by the Borrower, its Subsidiaries and Affiliates, as of the end of such period, plus (iv) the amount of mandatory redemptions of preferred stock to be made by the Borrower in cash during the succeeding twelve-month period (excluding redemptions of shares 3 of such preferred stock held by Subsidiaries or Affiliates of the Borrower), plus (v) distributions made in respect of any Hybrid Preferred Securities issued by any Hybrid Preferred Securities Subsidiary." " "Guarantee" means any agreement, undertaking or arrangement by which any Person guarantees, endorses or otherwise becomes or is contingently liable upon (by direct or indirect agreement, contingent or otherwise, to provide funds for payment, to supply funds to, or otherwise to invest in, a debtor, or otherwise to assure a creditor against loss) the debt or other obligation to pay money of or, in respect of, any other Person (other than by endorsements of instruments in the course of collection), or guarantees the payment of dividends or other distributions upon the shares of any other Person, provided, however, that any agreement, undertaking or arrangement by which the Borrower or any Subsidiary guarantees any payments with respect to any Hybrid Preferred Securities shall not constitute a Guarantee hereunder. The amount of any Person's obligation under any Guarantee shall (subject to any limitation set forth therein) be deemed to be the outstanding principal amount (or maximum outstanding principal amount, if larger) of the debt, obligation or other liability guaranteed thereby." " "Indebtedness" of any Person means, without duplication: (a) all obligations of such Person for borrowed money and all obligations of such Person evidenced by bonds, debentures, notes or other similar instruments; (b) all obligations, contingent or otherwise, relative to the face amount of all letters of credit (except those which have as collateral cash or Cash Equivalent Investments, whether or not drawn), and banker's acceptances issued for the account of such Person; (c) all obligations of such Person as lessee under leases which have been or should be, in accordance with GAAP, recorded as Capitalized Lease Liabilities except to the extent such obligations are offset by the contractual obligations of a third party to make payments to such Person to reimburse such Person for a portion of such Capitalized Lease Liabilities and such third party is current with respect to such payments; (d) all other items which, in accordance with GAAP, would be included as liabilities on the liability side of the balance sheet of such Person as of the date at which Indebtedness is to be determined except that, in the case of the Borrower, any preferred stock of the Borrower, now existing or hereafter issued, which by its express terms is not required to be redeemed in cash, property, notes or other debt instruments by either 2 4 the Borrower or the holder of such preferred stock prior to a date seven years after the Effective Date, is excluded from Indebtedness; (e) net liabilities of such Person under all Hedging Obligations; (f) whether or not so included as liabilities in accordance with GAAP, advance payment agreements on which performance is incomplete and all obligations of such Person to pay the deferred purchase price of property or services, and indebtedness (excluding prepaid interest thereon) secured by a Lien on property owned or being purchased by such Person (including indebtedness arising under conditional sales or other title retention agreements), whether or not such indebtedness shall have been assumed by such Person or is limited in recourse; and (g) all Guarantees of such Person in respect of any of the foregoing. For all purposes of this Agreement, the Indebtedness of any Person shall include the greater of that portion of the Indebtedness of any partnership or joint venture for which such Person is (a) by operation of law, or (b) contractually liable. Indebtedness of a Person shall not include any Hybrid Preferred Securities issued by such Person, any subordinated debt or other obligations of such Person initially issued to any Hybrid Preferred Securities Subsidiary in connection with the issuance of Hybrid Preferred Securities by such Hybrid Preferred Securities Subsidiary or any guarantee by such Person of payments with respect to any Hybrid Preferred Securities." " "Non-Standard Determination" means a determination or redetermination of the Borrowing Base that may be made either (i) in the event that Borrower fails to comply with the delivery requirements for Reserve Reports or Alternate Reserve Reports set forth in Section 7.2(e), (ii) upon the occurrence of any event that permits redetermination of the Borrowing Base under Section 8.8, (iii) at the discretion of the Required Lenders, no more than once during any six month period ending either October 31st, or April 30th, as applicable, or (iv) at the request of the Borrower, no more than once during any six month period ending either October 31st, or April 30th, as applicable, in any case as provided in Section 2.6(b)." " "Senior Debt" means all indebtedness for borrowed money (including Loans outstanding under this Agreement) other than (a) Subordinated Indebtedness, (b) Non-Recourse Indebtedness, (c) intercompany loans from the Borrower, (d) any Hybrid Preferred Securities issued by such Person, (e) any subordinated debt or other obligations of such Person initially issued to any Hybrid Preferred Securities Subsidiary in connection with the issuance of Hybrid Preferred 3 5 Securities by such Hybrid Preferred Securities Subsidiary, and (f) any guarantee by such Person of payments with respect to any Hybrid Preferred Securities." " "Stated Maturity Date" means (a) with respect to Revolving Loans, July 1, 2001; and (b) with respect to the Term Loans, July 2, 2003." (b) Section 1.1 of the Credit Agreement is amended hereby by adding the following definitions of "Hybrid Preferred Securities" and "Hybrid Preferred Securities Subsidiary" in appropriate alphabetical order: " "Hybrid Preferred Securities" means preferred or common equity interests issued by any Hybrid Preferred Securities Subsidiary." " "Hybrid Preferred Securities Subsidiary" means any business trust (or similar entity) (i) all of the common equity interest of which is owned (either directly or indirectly through one or more wholly-owned Subsidiaries) by the Borrower, (ii) that has been formed for the purpose of issuing Hybrid Preferred Securities, and (iii) substantially all of the assets of which consist at all times of subordinated debt or other obligations of the Borrower or a Subsidiary of the Borrower and payments made from time to time on such subordinated debt or other obligations." (c) Section 2.6 of the Credit Agreement is amended hereby in its entirety to the following: SECTION 2.6 Determination of Borrowing Base. (a) Upon delivery of a Reserve Report or Alternate Reserve Report pursuant to Section 7.2 hereof and provided, that such delivery shall be on or before the dates required therein, then with respect to the annual or semi-annual, as the case may be, determination of the Borrowing Base, the Agent will propose to the Lenders a Borrowing Base for acceptance by the Required Borrowing Base Lenders. If such Borrowing Base, as proposed by the Agent is accepted by the Required Borrowing Base Lenders, then such agreed Borrowing Base shall be communicated by the Agent to the Borrower on or before (i) the next April 30th, in the case of a Reserve Report and (ii) the next October 31st, in the case of an Alternate Reserve Report, and shall remain in effect until the next October 31st or April 30th; provided that if such proposed Borrowing Base is not approved by the Required Borrowing Base Lenders prior to the applicable date then, within thirty (30) days following the applicable date, the Required Borrowing Base Lenders will establish and agree to a Borrowing Base, and such amount will be 4 6 promptly communicated to the Borrower; provided that the then current Borrowing Base shall remain in effect until the Borrower is notified of the new Borrowing Base. The new Borrowing Base shall become effective as of the date that the Borrower receives notification from the Agent of the new Borrowing Base. The Borrowing Base, as determined and established pursuant to this Section 2.6(a) shall be subject, at all times, to the redetermination of the then effective Borrowing Base as a result of a Non-Standard Determination. (b) With respect to a Non-Standard Determination of the Borrowing Base, (i) the Agent or the Required Lenders shall have the right, but not the obligation, at any time to notify the Borrower of their intent to perform a Non-Standard Determination of the Borrowing Base and (ii) the Borrower shall have the right to request a Non-Standard Determination by sending a written request to the Agent for the performance of a Non-Standard Determination of the Borrowing Base. In connection with any Non-Standard Determination and notwithstanding the delivery of any new Alternate Reserve Report, the Agent shall propose, and the Required Borrowing Base Lenders shall agree to and approve, a new Borrowing Base which shall become effective upon receipt by the Borrower of notice of such new Borrowing Base until such new Borrowing Base may be redetermined as a result of a scheduled semi-annual determination of the Borrowing Base pursuant to Section 2.6(a). In connection with any Non-Standard Determination, the Borrower shall deliver promptly upon the request of the Agent a new Alternate Reserve Report to the Agent; provided that such Alternate Reserve Report, whether or not delivered, shall in no way impact the Non-Standard Determination of the Borrowing Base by the Agent or the approval of such Borrowing Base by the Required Borrowing Base Lenders." (d) Subsection 8.3(k) of the Credit Agreement is amended hereby by inserting the following prior to the semicolon at the end thereof: "and deposit arrangements constituting Liens providing for payments under the bareboat charter and operating agreement relating to the "Tantawan Explorer". (e) Subsection 8.4(a) of the Credit Agreement is amended hereby in its entirety to the following: " (a) the Indebtedness of the Borrower and its Subsidiaries, less current liabilities (except for current maturities of long-term Indebtedness), Non-Recourse Indebtedness, deferred taxes, deferred credits and, to the extent the same constitutes Indebtedness, Thaipo Limited's Guarantee and assumption of Tantawan Services, LLC's obligations under the bareboat charter and operating agreement relating to the FPSO "Tantawan Explorer", to exceed $500,000,000 on a consolidated basis;". 5 7 (f) Subsection 8.5(l) of the Credit Agreement is amended hereby in its entirety to the following: " (l) Guarantees constituting Indebtedness permitted by Section 8.4 and Thaipo Limited's Guarantee and assumption of Tantawan Services, LLC's obligations under the bareboat charter and operating agreement relating to the FPSO "Tantawan Explorer";". (g) Subsection 8.6(a) of the Credit Agreement is amended hereby by inserting the following prior to the semicolon at the end thereof: ",and provided further that Hybrid Preferred Securities shall not be treated as capital stock of the Borrower for purposes of this Section 8.6(a)". (h) Subsection 8.6(b)(i) of the Credit Agreement is amended hereby by replacing "July 1, 2000" with "July 2, 2001". (i) Subsection 8.7(a) of the Credit Agreement is amended hereby in its entirety to the following: " (a) any such Subsidiary may liquidate or dissolve voluntarily into, and may consolidate or merge with and into, the Borrower or any other Subsidiary and Tantawan Services LLC may liquidate or dissolve voluntarily and may transfer the bareboat charter and operating agreement (and associated deposit arrangements) relating to the FPSO "Tantawan Explorer" to the joint venturers in the Block B8/32 concession located in the Gulf of Thailand;". (j) Section 8.8 of the Credit Agreement is amended hereby in its entirety to the following: " SECTION 8.8 Asset Dispositions. At the request of the Agent or the Required Lenders, in their sole discretion, the Borrowing Base may be redetermined at any time in the event that: (a) the aggregate value of assets (including cash accounts, accounts receivable, production payments, and capital stock of or partnership interests in Subsidiaries, but excluding oil, gas, and other liquid or gaseous hydrocarbons sold in the ordinary course of business) sold, transferred, leased, contributed, or otherwise conveyed by the Borrower and its Subsidiaries other than to the Borrower or its Subsidiaries or as permitted by Section 8.7, or to which the Borrower and its Subsidiaries may grant options, warrants, or other rights, shall exceed, in any one transaction or in the aggregate since the last redetermination of the Borrowing Base, $10,000,000. Notwithstanding the foregoing, the Borrower and its Subsidiaries may grant, sell, or convey production payments as 6 8 permitted by this Agreement in connection with Non-Recourse Indebtedness. For purposes of this Section 8.8(a), the value of any asset is the greater of its book value or fair market value at the time of any disposition; or (b) the Discounted Present Value of Borrowing Base Properties sold, transferred, leased, contributed or otherwise conveyed by the Borrower to any Subsidiary shall exceed, in any one transaction or in the aggregate since the last redetermination of the Borrowing Base, ten percent (10%) of the Discounted Present Value of all Borrowing Base Properties without first obtaining the consent of the Required Lenders, which consent shall not be unreasonably withheld, and shall not require the payment of a fee or other compensation by the Borrower. Any redetermination of the Borrowing Base pursuant to this Section 8.8 shall be a Non-Standard Determination." (k) Subsection 8.9(a) of the Credit Agreement is amended hereby by replacing "July 2, 2002" with "July 2, 2003". 3. REPRESENTATIONS AND WARRANTIES. In order to induce the Lenders and the Agents to enter into this Amendment, the Borrower hereby reaffirms, as of the date hereof, its representations and warranties contained in Article VI of the Credit Agreement (except to the extent any such representation and warranty relates solely to an earlier date) and additionally represents and warrants as follows: 3.1 Organization. The Borrower and each of its corporate Subsidiaries is a corporation validly organized and existing and in good standing under the laws of the state, or country, of its incorporation, and is duly qualified to do business and is in good standing as a foreign corporation in each jurisdiction where the nature of its business requires such qualification, except where failure to qualify would not have a material adverse effect on the business or financial condition of the Borrower and its Subsidiaries taken as a whole or the Borrower's ability to perform the Loan Documents, as such may be amended hereby, or this Amendment. Each of the Borrower's Subsidiaries which is organized as a partnership is validly organized and existing and in good standing under the laws of the state of its formation, and is duly qualified to do business and is in good standing as a foreign partnership where the nature of its business requires such qualification, except where failure to qualify would not have a material adverse effect on the business or financial condition of the Borrower, or the Borrower and its Subsidiaries taken as a whole or the Borrower's ability to perform under the Loan Documents, as such may be amended hereby, or this Amendment. The Borrower and each of its Subsidiaries has full power and authority and holds all requisite governmental licenses, permits and other approvals to enter into and perform its Obligations under the Credit Agreement, as amended hereby, each other Loan Document and this Amendment and to own and hold under lease its property and to conduct its business substantially as currently conducted by it. 7 9 3.2 Due Authorization, Non-Contravention. The execution, delivery and performance by the Borrower of this Amendment and the consummation of the transactions contemplated hereby and by the Credit Agreement as so amended, are within the Borrower's corporate powers, have been duly authorized by all necessary corporate action, and do not (a) contravene the Borrower's Organic Documents; (b) contravene any contractual restriction, law or governmental regulation or court decree or order binding on or affecting the Borrower or any Subsidiary; or (c) result in, or require the creation or imposition of, any Lien on any properties of the Borrower or its Subsidiaries except as Liens will be imposed, created, or required upon execution and delivery of the Security Documents pursuant to Section 7.11 of the Credit Agreement. 3.3 Governmental Approval. No authorization or approval or other action by, and no notice to or filing with, any governmental authority or regulatory body is required for the due execution, delivery or performance by the Borrower of this Amendment. 3.4 Validity, etc. This Amendment and the Credit Agreement as amended hereby constitute the legal, valid and binding obligations of the Borrower, enforceable in accordance with their respective terms except as such enforceability is subject to the effect of (i) any applicable bankruptcy, insolvency, reorganization or similar law relating to or affecting creditors' rights generally and (ii) general principles of equity (regardless of whether such enforceability is considered in a proceeding in equity or at law), including concepts of materiality, reasonableness, good faith and fair dealing. 4. COVENANT. The Borrower agrees that, at the request of the Agent, Borrower will enter into a restated Credit Agreement with the Agents and the Lenders in substantially the form of the Credit Agreement as amended by this Amendment. 5. EFFECT OF AMENDMENT. This Amendment shall be deemed to be an amendment to the Credit Agreement, and the Credit Agreement, as amended hereby, is hereby ratified, approved and confirmed in each and every respect. All references to the Credit Agreement in any other document, instrument, agreement or writing shall hereafter be deemed to refer to the Credit Agreement as amended hereby. 8 10 6. GOVERNING LAW, SEVERABILITY, ETC. THIS AMENDMENT SHALL BE A CONTRACT MADE UNDER AND GOVERNED BY THE INTERNAL LAWS OF THE STATE OF ILLINOIS. Whenever possible each provision of this Amendment shall be interpreted in such manner as to be effective and valid under applicable law, but if any provision of this Amendment shall be prohibited by or invalid under applicable law, such provision shall be ineffective to the extent of such prohibition or invalidity, without invalidating the remainder of such provision or the remaining provisions of this Amendment. THIS WRITTEN AMENDMENT AND THE CREDIT AGREEMENT AS AMENDED BY THIS AMENDMENT REPRESENT THE FINAL AGREEMENT AMONG THE PARTIES AND MAY NOT BE CONTRADICTED BY PRIOR, CONTEMPORANEOUS OR SUBSEQUENT ORAL AGREEMENTS OF THE PARTIES. THERE ARE NO UNWRITTEN ORAL AGREEMENTS BETWEEN THE PARTIES. 7. MISCELLANEOUS. 7.1 Successors and Assigns. This Amendment shall be binding upon and shall inure to the benefit of the parties hereto and their respective successors and assigns. 7.2 Counterparts. This Amendment may be executed in one or more counterparts, each of which shall be deemed an original but all of which together shall constitute one and the same instrument. 7.3 Effectiveness. This Amendment shall become effective when (i) counterparts hereof executed on behalf of the Borrower and each Lender (or notice thereof satisfactory to the Agent) shall have been received by the Agent, and (ii) notice thereof shall have been given by the Agent to the Borrower and each Lender. 9 11 IN WITNESS WHEREOF, the parties hereto have caused this Amendment to be executed by their respective officers thereunto duly authorized as of the day and year first written above. POGO PRODUCING COMPANY By: /s/ JOHN W. ELSENHANS ----------------------------------- Name: John W. Elsenhans Title: Vice President and Chief Financial Officer S - 1 12 BANK OF MONTREAL, acting through its U.S. branches and agencies, including initially its Chicago Illinois branch, as Agent By: /s/ SARA J. TEASDALE --------------------------------------- Name: Sara J. Teasdale Title: Director S - 2 13 PARIBAS, formerly known as Banque Paribas, as Documentation Agent By: /s/ DOUGLAS R. LIFTMAN --------------------------------------- Name: Douglas R. Liftman Title: Director By: /s/ MARIAN LIVINGSTON --------------------------------------- Name: MARIAN LIVINGSTON Title: VICE PRESIDENT S - 3 14 BANK OF MONTREAL, as a Lender By: /s/ MELISSA BAUMAN --------------------------------------- Name: Melissa Bauman Title: Director S - 4 15 PARIBAS, formerly known as Banque Paribas, as a Lender By: /s/ MARIAN LIVINGSTON --------------------------------------- Name: MARIAN LIVINGSTON Title: VICE PRESIDENT By: /s/ BETSY JOCHER --------------------------------------- Name: BETSY R. JOCHER Title: ASSISTANT VICE PRESIDENT S - 5 16 BANKBOSTON, N.A., as a Lender By: /s/ TERRENCE RONAN --------------------------------------- Name: Terrence Ronan Title: Director S - 6 17 BANK OF AMERICA, N.A., formerly NationsBank, N.A., as a Lender By: /s/ MARY LOUISE ALLEN --------------------------------------- Name: Mary Louise Allen Title: Vice President S - 7 18 ABN AMRO BANK N.V., as a Lender By: /s/ ROBERT J. CUNNINGHAM --------------------------------------- Name: Robert J. Cunningham Title: Group Vice President By: /s/ W. BRYAN CHAPMAN --------------------------------------- Name: W. Bryan Chapman Title: Group Vice President S - 8 19 SOCIETE GENERALE, as a Lender By: /s/ RICHARD A. ERBERT --------------------------------------- Name: RICHARD A. ERBERT Title: VICE PRESIDENT S - 9 20 TORONTO DOMINION (TEXAS), INC., as a Lender By: /s/ CAROL BRANDT --------------------------------------- Name: CAROL BRANDT Title: VICE PRESIDENT S - 10 21 THE SANWA BANK LIMITED, NEW YORK BRANCH, as a Lender By: /s/ [ILLEGIBLE] --------------------------------------- Name: Title: S - 11 EX-27 3 FINANCIAL DATA SCHEDULE
5 This Financial Data Schedule contains summary financial information extracted from the Consolidated Financial Statements (Unaudited) of Pogo Producing Company, including the Consolidated Balance Sheets as of June 30, 1999 and the Consolidated Statements of Income for the six months ended June 30, 1999, and is qualified in its entirety by reference to such Consolidated Financial Statements. 1,000 6-MOS DEC-31-1998 JUN-30-1999 43,069 0 51,326 0 14,898 111,671 1,689,163 965,674 901,111 59,169 365,000 0 0 40,157 218,608 901,111 83,124 120,874 30,357 30,357 65,401 0 19,109 14,694 3,387 11,307 0 0 0 11,307 0.28 0.28 This amount is not disclosed on the face of the Consolidated Financial Statements due to lack of materiality, but is included as a contra-asset in Accounts Receivable. Does not include Gains or Losses on Property Sales. Includes Lease Operating Expense, but excludes General and Administrative, Exploration, Dry Hole and Impairment and Depreciation, Depletion and Amortization Expenses. Includes General and Administrative, Exploration, Dry Hole and Impairment and Depreciation, Depletion and Amortization Expenses. This amount is not disclosed on the face of the Consolidated Financial Statements due to lack of materiality, but is included in Oil and Gas Revenues.
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