Headlee is a Devonian carbonate field straddling the Ector and Midland county line in the western Midland Basin. It was found in the early 1950s, when Permian Basin operators had begun drilling routinely through the shallow Permian pays into much older rock. Fields of this generation are smaller in area than the great platform fields but often carry good pay thickness and light, high-quality oil, and Headlee was developed with gas injection rather than a conventional waterflood. It is a mature property today, valued for steadiness rather than for growth.
Source: Texas Railroad Commission production filings, aggregated across RRC field designations 39969400, 39969600. Reported volumes lag the calendar by several months.
Ector County had been an oil county since the great strike of 1926 on W. E. Connell’s ranch, followed by the Penn field in 1929 and the Cowden field in 1930. Between 1926 and 1990 the county produced 2,726,524,140 barrels of petroleum, making it the second most productive oil county in Texas. Midland County next door came in much later, with its first oil in 1945 and the Midland South Pool success in 1947. By the early 1950s the ground along the county line had been thoroughly leased and was being drilled aggressively.
The 1950s brought the deep drilling phase. Better rigs and better logs let operators push below the San Andres and Grayburg into Devonian and Ellenburger carbonates, and a cluster of new fields resulted along the western edge of the Midland Basin. Headlee belongs to that group. Because these reservoirs sit thousands of feet deeper than the shallow platform pays, wells cost far more, and operators developed them on wide spacing with careful attention to reservoir management from the beginning rather than as an afterthought.
Gas injection was chosen here rather than water. Reinjecting produced gas maintains reservoir pressure, keeps light oil from dropping its dissolved gas and losing mobility, and conserves gas volumes at times when there is no ready market for them. That approach has kept the field producing for decades, but it is a pressure-maintenance strategy rather than a growth strategy. Midland County output has fallen from nearly seventeen million barrels in 1956 to a fraction of that today, and Headlee has followed the same long downward curve.
The Devonian of the western Midland Basin is a cherty carbonate and siliceous section deposited long before the Permian rocks that made the region famous. Pay is deep, porosity is concentrated in specific intervals rather than spread evenly, and permeability can vary sharply over short distances. Traps here are generally broad structural closures, sometimes with a stratigraphic element where porosity develops or dies out laterally. That heterogeneity is why well results within a single Devonian field can differ substantially and why pressure maintenance matters more than well count.
Headlee has been produced with gas injection, a pressure-maintenance method rather than a displacement flood in the way a waterflood is. Reinjected gas keeps reservoir pressure above the point at which dissolved gas breaks out of the oil, preserving the oil’s mobility and preventing the sharp recovery losses that follow pressure collapse in a deep, light-oil carbonate. The practical implication for owners is that production is steady but that the field depends on the operator continuing to reinject rather than sell the gas, a decision that responds to gas prices as much as to reservoir engineering.
A Headlee interest is deep-reservoir, pressure-maintained income: modest but durable, and dependent on the operator’s injection discipline. Because the field crosses a county line, a single family’s holdings can carry separate decimals in Ector and Midland counties. Many owners in this area also hold rights in the Spraberry and Wolfcamp intervals above, which have been leased separately for horizontal development and are valued on a completely different basis. Separating those interests is the first step in any honest valuation. We buy minerals and royalties in Ector and Midland counties and provide free written offers.
County-level well data, production charts, and selling guides for the counties this field spans:
Deep, light-oil carbonate reservoirs lose recoverable oil quickly if pressure falls below the point where dissolved gas comes out of solution. Reinjecting produced gas holds pressure above that threshold and keeps the oil mobile. It also stores gas volumes in the reservoir at times when selling them is uneconomic. Whether gas or water is used depends on the fluid properties and on the availability of injection gas.
Generally injected gas does not generate royalty at the time of injection, because it is not sold, though it supports future oil production that does. Your lease and division order language controls the treatment, so it is worth reading before assuming gas volumes should appear on the check. If the language is unclear, that is a question for a Texas oil and gas attorney.
Usually not. Modern horizontal development in this area targets Spraberry and Wolfcamp intervals well above the Devonian, typically under separate leases. Whether you participate depends on whether your mineral ownership covers all depths and on how each lease was written. Depth-severed minerals are common here, so the leases and deeds need to be checked individually.