Business Context and Reporting Period
Company: MESA ROYALTY TRUST
Filing Type: Form 10-Q (Quarterly Report)
Period Ended: March 31, 2002
Trustee: JPMorgan Chase Bank
Outstanding Units: 1,863,590 (as of April 24, 2002)
The Trust holds a 90% net profits overriding royalty interest in producing oil and gas properties located in the Hugoton field (Kansas), San Juan Basin (New Mexico and Colorado), and Yellow Creek field (Wyoming). Operations are managed by working interest owners including Pioneer Natural Resources Company (PNR), Conoco, and Amoco.
Key Financial Metrics
| Metric | Q1 2002 | Q1 2001 |
|---|---|---|
| Royalty Income | $903,004 | $3,830,016 |
| Interest Income | $1,723 | $44,123 |
| General & Admin Expenses | $(11,797) | $(5,934) |
| Distributable Income | $892,930 | $3,868,205 |
| Distributable Income Per Unit | $0.4791 | $2.0757 |
| Cash and Short-term Investments | $891,207 | $1,167,273 |
| Total Assets | $11,508,081 | $12,037,014 |
| Trust Corpus | $10,615,151 | $10,865,266 |
Material Changes vs. Prior Period
- Revenue Decline: Distributable income decreased by approximately 77% year-over-year, dropping from $3.87 million to $0.89 million. This was driven primarily by a significant drop in royalty income.
- Price Volatility: Average sales prices for natural gas and natural gas liquids fell sharply.
- Hugoton Field: Natural gas prices dropped from $5.39/Mcf to $2.36/Mcf; liquids dropped from $24.88/Bbl to $13.54/Bbl.
- San Juan Basin: Natural gas prices dropped from $5.50/Mcf to $2.49/Mcf; liquids dropped from $28.48/Bbl to $13.32/Bbl.
- Production Volumes: Net production volumes attributable to the Royalty decreased significantly due to lower prices affecting allowable production rates.
- Hugoton natural gas production fell from 294,498 Mcf to 181,634 Mcf.
- San Juan Basin natural gas production fell from 271,325 Mcf to 38,775 Mcf.
- Colorado Properties: No royalty income was received from the San Juan Basin properties in Colorado for either period due to unrecovered costs associated with the Fruitland Coal drilling program.
Outlook, Risks, and Management Commentary
- Market Conditions: Management notes that overall market prices for natural gas and liquids were lower in Q1 2002 compared to Q1 2001. The Hugoton field allowable production rates for April 1, 2002, through September 30, 2002, were set at 141 Bcf, down from 156.2 Bcf in the same period the prior year.
- Contractual Arrangements: PNR continues to market Hugoton gas under short-term and multi-month contracts. A Gas Transportation Agreement with Midcontinent Market Center (formerly Western Resources) remains in effect through June 1, 2002.
- Cost Recovery: Capital costs incurred for the Fruitland Coal drilling program in Colorado have not been fully recovered. Consequently, no distributions have been made from this portion of the Trust since 1990.
- Tax Credits: Production from the Fruitland Coal formation may qualify for tax credits under Section 29 of the Internal Revenue Code, potentially benefiting unitholders.
- Forward-Looking Statements: The filing includes standard disclaimers that actual results may differ materially from expectations due to market price fluctuations and production volumes.
Investor Verification Checklist
- Price Sensitivity: Verify current natural gas and NGL spot prices to assess the impact on future royalty income, given the Trust's heavy reliance on these commodities.
- Production Allowables: Monitor Kansas Corporation Commission (KCC) rulings on Hugoton field allowable production rates, as these directly cap revenue potential.
- Cost Recovery Status: Track the status of capital cost recovery for the Fruitland Coal drilling program in Colorado to determine when, if ever, this asset will begin generating income.
- Operator Performance: Review the operational reports of PNR, Conoco, and Amoco regarding production volumes and marketing strategies for the respective fields.
- Liquidity Position: Confirm the Trust's cash balance ($891,207) is sufficient to cover upcoming quarterly distributions and administrative expenses.