3/31/04 3/31/03 -------- -------- Average Daily Production -- MCFE 63,538 62,878 Average MCFE Price Received (a) $4.91 $5.41 Average Daily Gas Production -- MCF 36,176 33,544 Average Gas Price Received (a) $4.97 $5.74 Average Daily Oil Production -- BBLS 4,220 4,644 Average Oil Price Received (a) $29.96 $30.51 Total Oil & Gas Revenues -- 000's $28,398 $30,630 Discretionary Cash Flow (note 1) -- 000's $10,333 $10,074 EBITDAX (note 2) -- 000's $13,738 $13,938 (a) -- excluding effects of hedging.
During the first quarter of 2004, Wiser produced approximately 3.3 BCF of gas and 415,000 barrels of oil and NGL's for a total of 5.8 BCFE, up 2% from the first quarter of 2003 production of 5.7 BCFE and 5% higher than the fourth quarter of 2003 production of 5.5 BCFE. Oil production for the quarter was down 8% from the first quarter of 2003 due to normal decline from mature fields in the U.S. and Canada. Gas production for the first quarter of 2004 was up 9% from the first quarter of 2003 primarily at the Wild River field in Canada, where the Wild River 15-30 well produced approximately 480 MMCF of gas in the first quarter of 2004. The Wild River 15-30 well was shut-in for almost 3 weeks in the first quarter of 2004 due to third party facility constraints. Production from the Wild River 15-30 well would have been approximately 120 MMCF higher in the first quarter of 2004 absent the shut-in. The Wild River 15-30 is currently producing approximately 20 MMCFPD.
Oil and gas revenues for the first quarter 2004 were $28.4 million, down 7% from the first quarter of 2003 due primarily to lower oil production and lower realized oil and gas prices. Realized oil prices for the quarter averaged $29.96 per barrel, down 2% from first quarter 2003. Realized gas prices for the quarter averaged $4.97 per Mcf, down 13% from first quarter 2003. Average prices received by the Company for the trailing twelve month period ending March 31, 2004 were approximately $4.31 per barrel less than the average NYMEX oil price and $0.71 per Mcf lower than the average NYMEX gas price.
Operating costs for the first quarter of 2004 were up $2.0 million over the first quarter of 2003 for several reasons. Operating costs at the Wellman project in the first quarter of 2004 were $0.4 million higher than first quarter 2003 due to unscheduled maintenance costs. Also at Wellman, CO2 sales were curtailed to $0.2 million in the first quarter of 2004 compared to $0.7 million in the previous fourth quarter of 2003. Operating costs in the first quarter of 2004 were also up at the Wild River field in Canada in connection with starting production of sour gas at the 15-30 well. Also, our operating costs in the first quarter of 2004 were adversely affected by the Canadian dollar exchange rate which increased our Canadian operating costs by $0.6 million over first quarter 2003 levels.
Depreciation, depletion and amortization for the first quarter of 2004 was $1.52 per MCFE, up 13% per MCFE from first quarter 2003 due to higher per unit rates in the Gulf of Mexico and the Wolverine field in Canada.
Derivative loss for the first quarter of 2004 was $5.7 million, consisting of $1.8 million in cash settlements and $3.9 million non-cash change in fair value of our hedge contracts.
Net loss for the first quarter of 2004 was $4.3 million, or ($0.28) per basic and diluted share, compared to net income of $2.2 million for the first quarter of 2003. Discretionary cash flow (see note 1 below) for the first quarter of 2004 was $10.3 million ($0.65 per diluted share), up 3% from the first quarter of 2003 and up 34% from fourth quarter 2003 discretionary cash flow of $7.7 million.
EBITDAX (see note 2 below) for the first quarter of 2004 was $13.7 million ($0.86 per diluted share). Capital and exploration expenditures for the first quarter of 2004 were $15.2 million, with $9.8 million of expenditures in Canada and $5.4 million in the U.S.
Commenting, George K. Hickox, Jr., Company Chairman and CEO said, "The Company had a solid quarter operationally, highlighted by a successful Canadian winter drilling program and the closing of our 140,000 acre Sabine leasehold acquisition. Production began ramping up in the quarter and is now averaging approximately 73 MMCFE per day. With production up and prices staying high, we expect to see increased cash flows for the balance of the year."
Guidance for 2004
The Company estimates its second quarter 2004 production will be in the range of 6.3 to 6.6 BCFE and reiterates its previously provided 2004 production guidance in the range of 25.5 to 26.5 BCFE. The Company continues to project its 2004 capital and exploration expenditures will be in the range of $48 to $50 million. Second quarter capital expenditures are projected to be in the range of $9 to $10 million.
Discretionary cash flow is defined as cash flows from operating activities before changes in operating assets and liabilities and exploration expense. Management believes that discretionary cash flow is a better liquidity measure for oil and gas companies because; (a) exploration expense is a discretionary component of the Company's capital budget that effects cash flows from operating activities and; (b) changes in operating assets and liabilities relate to the timing of cash receipts and disbursements, which the Company may not control and may not relate to the period that the operating activities occurred. Discretionary cash flow should not be considered in isolation or as a substitute for cash flows from operating activities prepared in accordance with generally accepted accounting principles. Discretionary cash flow as defined above may not be comparable to similarly titled measures of other companies. Following is a reconciliation of discretionary cash flow to cash flows from operating activities:
First Quarter ----------------- 2004 2003 -------- -------- Cash flows from operating activities $11,681 $10,682 Add back exploration expense (a) 802 2,495 Add back (deduct) net changes in operating assets and liabilities (2,150) (3,103) -------- -------- Discretionary Cash Flow $10,333 $10,074 ======== ======== (a) Excluding impairments and abandonments.
EBITDAX is defined as net income before interest, income taxes, DD&A, impairments, exploration expense, non-cash gains, and non-cash gain or loss on derivative value. Wiser has included information concerning EBITDAX because it is used by management and certain investors as a measure of the ability of a company to service or incur indebtedness and because it is a financial measure commonly used in the energy industry. EBITDAX should not be considered in isolation or as a substitute for net income, cash flow from operating activities or other income or cash flow data prepared in accordance with generally accepted accounting principles or as a measure of the Company's profitability or liquidity. EBITDAX as defined above may not be comparable to similarly titled measures of other companies. Following is a reconciliation of EBITDAX to net income:
First Quarter ----------------- 2004 2003 -------- -------- Net income (loss) $(4,321) $2,216 Cumulative effect of accounting change -- (5,238) Preferred dividends & amortization -- 1,913 Add back interest expense 3,575 3,551 Deduct income tax benefit -- (441) Add back DD&A 8,797 7,643 Add back exploration expense 1,730 3,626 Add back non-cash loss on derivative value 3,957 668 -------- -------- EBITDAX $13,738 $13,938 ======== ========
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