Dorchester Minerals, L.P. - 10-Q Summary (Q2 2006)
Business Context and Reporting Period
This report covers the quarterly period ended June 30, 2006 for Dorchester Minerals, L.P., a Delaware limited partnership. The company owns producing and nonproducing mineral, royalty, overriding royalty, net profits, and leasehold interests (Royalty Properties) across 25 states. It also holds a 96.97% net profits overriding royalty interest in properties operated by Dorchester Minerals Operating LP. As of August 2, 2006, there were 28,240,431 common units outstanding.
Key Financial Metrics
| Metric | Q2 2006 | Q2 2005 | YTD 2006 | YTD 2005 |
|---|---|---|---|---|
| Total Operating Revenues | $23,128,000 | $16,970,000 | $42,407,000 | $31,389,000 |
| Net Earnings | $16,789,000 | $10,191,000 | $29,849,000 | $18,067,000 |
| Net Earnings Per Unit (Basic/Diluted) | $0.58 | $0.35 | $1.02 | $0.62 |
| Operating Cash Flow (YTD) | $44,511,000 (2006) vs $29,482,000 (2005) | |||
| Cash and Equivalents (End of Period) | $23,359,000 | |||
| Total Liabilities | $1,353,000 | |||
| Distributions Paid (YTD) | $44,567,000 |
Revenue Composition (Q2 2006): Royalties ($11.8M), Lease Bonus ($6.0M), Net Profits Interests ($5.3M).
Material Changes vs. Prior Period
- Revenue Growth: Operating revenues increased 36.3% in Q2 2006 compared to Q2 2005. This was driven by higher crude oil prices, increased royalty natural gas sales volumes, and a significant lease bonus payment.
- Commodity Prices: Weighted average oil sales prices for Royalty Properties rose 35.2% to $65.86/bbl in Q2 2006. Natural gas prices for Royalty Properties remained relatively flat ($6.18/mcf vs $6.19/mcf).
- Volume Trends: Royalty Properties natural gas sales volumes increased 4.1% in Q2 2006 due to new wells. Oil sales volumes for Royalty Properties decreased 6.7% due to natural decline, though new wells offset this in the first six months.
- Costs: Total costs and expenses decreased 4.7% in Q2 2006, primarily due to a 10.3% reduction in depletion and amortization, despite higher production taxes.
- Unusual Items: The company received a $5,535,000 final lease bonus payment related to the Fayetteville Shale Lease Transaction in Arkansas, which significantly boosted Q2 revenues.
Outlook, Risks, and Management Commentary
- Liquidity: The Partnership maintains strong liquidity with $23.4 million in cash. It has no debt other than trade payables and is not liable for exploration or development costs of the operating partnership.
- Distributions: The Q2 2006 distribution was $0.778120 per unit. The next distribution is required by November 15, 2006.
- Market Risk: Profitability is highly sensitive to oil and natural gas price volatility. The company does not engage in financial hedging.
- Legal Contingencies: A lawsuit filed in 2002 by "Rural Residents for Natural Gas Rights" regarding domestic gas usage rights in Texas County, Oklahoma, remains pending. Management believes the claims are without merit and potential damages are minimal, though an adverse decision could impact Net Profits Interest payments.
- Taxation: The Partnership expects to be exempt from the new Texas margin tax as a "passive entity," though unitholders may be subject to the tax individually.
- Future Activity: The operating partnership anticipates drilling possibly two wells in the Oklahoma Council Grove formation in 2006/2007, with costs estimated at $350,000 to $400,000 per well.
Investor Verification Checklist
- Verify the sustainability of the $5.5M Fayetteville Shale lease bonus as a one-time event versus recurring revenue.
- Monitor the outcome of the Texas County, Oklahoma litigation regarding domestic gas rights.
- Track future oil and natural gas price volatility, as the company has no hedging strategy.
- Confirm the status of the 2003/2004/2005 NPI and 2006 NPI deficits, which are excluded from current financial statements but may impact future cash flows.
- Review the impact of the Texas margin tax on individual unitholders.