Mesa Royalty Trust - 10-Q Summary (Q2 1999)
Business Context and Reporting Period
This Form 10-Q covers the quarterly period ended June 30, 1999, for Mesa Royalty Trust. The Trust holds a 90% net profits overriding royalty interest in producing oil and gas properties located in the Hugoton field (Kansas), the San Juan Basin (New Mexico and Colorado), and the Yellow Creek field (Wyoming). As of August 10, 1999, there were 1,863,590 Units of Beneficial Interest outstanding. The Trust is administered by Chase Bank of Texas, National Association.
Key Financial Metrics
| Metric | Q2 1999 | Q2 1998 | YTD 1999 | YTD 1998 |
|---|---|---|---|---|
| Royalty Income | $1,206,359 | $1,620,266 | $2,415,240 | $3,803,345 |
| Distributable Income | $1,207,226 | $1,633,078 | $2,419,121 | $3,822,587 |
| Distributable Income Per Unit | $0.6478 | $0.8763 | $1.2981 | $2.0512 |
| Cash and Short-Term Investments | $1,200,738 | N/A | $1,200,738 | $1,002,130 |
| Net Overriding Royalty Interest (Net of Amortization) | $13,138,253 | N/A | $13,138,253 | $13,889,555 |
| Amortization of Royalty Interest | $(386,836) | $(419,967) | $(751,302) | $(861,435) |
Note: The Trust has no debt. Liquidity is maintained through cash reserves and royalty receipts. Margins are not applicable in the traditional sense as the Trust receives net proceeds after operating and capital costs are deducted by the working interest owners.
Material Changes vs. Prior Period
- Revenue Decline: Distributable income decreased by approximately 26% for the quarter and 37% year-to-date compared to the prior year periods.
- Price and Volume Impact: The decline is primarily attributed to lower average sales prices for natural gas and natural gas liquids (NGLs) and reduced production volumes.
- Hugoton Field: Royalty income dropped from $1.12M to $0.77M in Q2. Average natural gas prices fell from $2.09/Mcf to $1.69/Mcf. Production volumes also decreased due to seasonal fluctuations and lower allowable rates set by the Kansas Corporation Commission.
- San Juan Basin: Income from New Mexico properties decreased due to lower gas prices ($1.88/Mcf in 1998 vs. $1.51/Mcf in 1999). No income was generated from Colorado properties as capital costs for the Fruitland Coal drilling program have not yet been recovered.
Outlook, Risks, and Management Commentary
- Year 2000 Compliance: The filing details extensive Year 2000 remediation efforts by operators Pioneer Natural Resources (PNR) and Conoco. PNR estimates 99% completion of the assessment phase and 83% of remediation. Conoco targets mid-1999 for completion. The Trustee is also implementing its own compliance program. No Year 2000 costs are passed through to the Trust.
- Market Conditions: Natural gas from the Hugoton field is sold under short-term contracts at market clearing prices. The Trust expects to continue this marketing strategy.
- Colorado Properties: No distributions are expected from the Colorado portion of the San Juan Basin until the Fruitland Coal drilling costs are recovered. This has been the case 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.
Investor Verification Checklist
- Verify the current status of natural gas spot prices and their impact on future royalty receipts.
- Confirm the progress of Year 2000 remediation for operators PNR and Conoco to assess potential disruption risks.
- Review the capital cost recovery status for the Fruitland Coal drilling program in Colorado to estimate when income might resume from that region.
- Monitor the Kansas Corporation Commission's allowable production rates for the Hugoton field.
- Check the Trust's cash balance against upcoming quarterly distribution obligations.