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Five Key Indicators That Show Your Mineral Rights Are Ready for Evaluation
A mineral-rights evaluation can begin when the property, ownership trail, operating context, economic evidence, and unresolved questions are identifiable, even if every record is not yet complete.
Existing Wells vs. Future Locations in a DCF Model
A mineral-rights DCF should keep observed producing-well cash flow separate from uncertain future-location scenarios until their evidence, timing, and risks are explicit.
Essential Steps to Assess the Value of Your Mineral Rights Accurately and Confidently
A confident mineral-rights value assessment starts with a dated evidence file, not a price shortcut. Identify the interest, reconcile records, separate facts from assumptions, and document what could change the range.
Discount Rates in Mineral Rights DCF: A Plain-Language Guide
A mineral-rights DCF converts a forecast of future owner cash flows into a present-value indication. The discount rate matters, but it must match the cash-flow definition and the risks not already modeled elsewhere.
Depth Severances and Formation Rights in Mineral Valuation
A depth severance can divide one surface tract into different vertical mineral interests. Valuation starts by defining the exact interval and formation rights that the records support.
Decline Curves and Future Royalty Cash Flow
A decline curve estimates a future production path. A royalty cash-flow scenario adds separately documented price, ownership, deduction, tax, timing, and discounting assumptions.
Curative Title Risk as a Valuation Adjustment
A defensible title-risk adjustment identifies the issue, affected interest, cure path, timing, cost evidence, payment effect, and residual uncertainty before changing value.
Converting Monthly Royalty History Into a Valuation Baseline
A useful royalty-history baseline preserves each production month, property, product, decimal, price, tax, deduction, adjustment, and net payment before summarizing cash flow.
Comparable Mineral Sales: What Makes a Transaction Relevant?
A comparable mineral sale is relevant only when the interest conveyed, property evidence, market timing, and transaction terms are sufficiently similar and verifiable.
Basis Differentials and Mineral Rights Cash Flow
A basis differential is the location-related difference between a benchmark and a regional market price. It can affect royalty cash flow, but it is not the same thing as a post-production deduction.
Acreage Contiguity and Its Role in Development Potential
Acreage contiguity can make a tract easier to evaluate as part of a connected development area, but it does not establish title, pooling authority, a permit, a drilling schedule, or a specific value.
Eagle Ford Shale and South Texas Mineral Rights
The Eagle Ford Shale is a South Texas formation with public geology, production, and price data. This article explains those sources and how an owner can use them.
How Horizontal Drilling Affects Texas Mineral Rights Values
Horizontal drilling is a well-completion technique that public RRC well records document. Learn what those records show and how MRX uses them in its reviews.
Oil Prices and Texas Mineral Rights Value
Oil prices can change royalty revenue quickly, but owners still need production, lease, and ownership records before drawing value conclusions.
How Royalty Payments Work for Texas Mineral Owners
Royalty payments for Texas mineral owners depend on the lease, the division order, and the operator-reported production. This article explains those inputs.
Texas Mineral Rights: Producing vs. Non-Producing
Producing interests can be reviewed from payment and production history, while non-producing interests usually depend more on acreage, location, lease terms, and development uncertainty.
Midland vs. Delaware Basin Mineral Rights
Midland and Delaware are both Permian Basin sub-basins, but owners should compare formations, well results, operator activity, and tract records before treating them as interchangeable.
Natural Gas vs. Oil Mineral Rights in Texas
Oil and gas interests can behave differently on a statement and in a review because products, pricing, decline patterns, and deductions are not always the same.
Texas Oil and Gas Production by County: An Owner Primer
Texas oil and gas production by county is reported publicly by the RRC and EIA. Learn what those records show, what they do not, and how an owner can use them.
Texas Railroad Commission: Public Records for Mineral Rights
Use RRC records to research production, leases, operators, and permits. Investigate title separately through county instruments and qualified review.
The Permian Basin Explained: An Owner Overview
The Permian Basin is a major oil-producing region spanning West Texas and southeastern New Mexico. This article explains its geology, agencies, and how owners can research their interests.
How Title Review Findings Can Change a Mineral Rights Offer
Title review may identify a different ownership fraction, missing records, liens, or tract issues. Learn how those findings can change an offer.
What Is a Net Royalty Acre? NRI and Mineral Rights Value
Net royalty acres normalize acreage and royalty burden for comparison. NRI describes the decimal share of production revenue credited to an owner.
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