The Dollarhide Field, discovered in June 1945 by Magnolia Petroleum and Humble Oil in far western Andrews County, Texas, is a stacked-pay field producing 40-gravity light oil from four intervals — most prolifically the Devonian Thirtyone chert at about 7,800 feet, along with Clearfork carbonate pay above. After primary depletion and a successful waterflood, the field’s Devonian units were converted to a patented CO2 hybrid water-alternating-gas flood that pushed production back up the curve. Well over 100 million barrels later, Dollarhide remains a working example of how tertiary recovery rewrites a field’s lifespan.
Source: Texas Railroad Commission production filings, aggregated across RRC field designations 25188400, 25188200, 25188800. Reported volumes lag the calendar by several months.
Magnolia Petroleum and Humble Oil & Refining brought in Dollarhide in June 1945, about 70 miles west of Midland on the western edge of the Central Basin Platform. Development through the late 1940s defined four productive intervals and split the structure into the Main, North, and West units, with the chert of the Devonian Thirtyone Formation — holding roughly 146 million barrels of original oil in place in the main unit alone — emerging as the field’s workhorse reservoir.
The field followed the classic recovery sequence with unusual discipline: primary depletion from 1947 to 1961, then unit waterflooding from 1962 to 1985 that lifted output to a secondary peak of about 9,000 barrels per day — higher than the primary peak. As the waterflood matured, engineers designed a tertiary program tailored to the Devonian chert: a patented CO2 hybrid water-alternating-gas miscible process intended to maximize recovery from rock the water had already swept.
CO2 injection transformed late-life Dollarhide, with production climbing under the miscible program and ten-year performance reviews published as reference material for Devonian CO2 flooding. Operatorship of the units passed through Unocal-era developers to Pure Resources and then Chevron in the early-2000s consolidation, and the mature flood has continued under successor management — a project now measured in decades, exactly as CO2 economics intend.
Dollarhide is a faulted anticline on the western Central Basin Platform with four productive intervals, from Permian Clearfork carbonates down to the field’s signature reservoir: the chert-dominated Lower Devonian Thirtyone Formation at roughly 7,800 feet. The Thirtyone’s porous, brittle chert holds light 40-gravity crude with excellent miscibility characteristics — the reason the reservoir responded so strongly to both waterflood and CO2 injection. Stacked pay also means a single mineral tract here can participate in shallow and deep units with distinct recovery histories and remaining potential.
Dollarhide’s Devonian CO2 flood is one of the Permian’s long-running tertiary success stories. After the 1962–1985 waterflood, operators implemented a patented CO2 hybrid WAG process that reversed decline — published reviews documented production climbing under miscible injection years into the program. CO2 floods of light-oil chert reservoirs recover oil for decades, and the field’s multiple units and intervals give operators a deep inventory of recompletion and optimization targets. For royalty owners, a reservoir on its third recovery mechanism is a reservoir whose payout horizon keeps moving outward.
Minerals and royalties at Dollarhide combine light-oil quality, stacked pay, and a tertiary flood with a documented record of adding recovery — fundamentals that support value well beyond simple decline math. Interests here often involve multiple units on the same acreage, and offers that price only the most visible unit leave money unexamined. Understanding each decimal you hold across the field’s units is the key preparatory step. We buy minerals and royalties in Andrews County and provide free written offers.
County-level well data, production charts, and selling guides for the counties this field spans:
Yes. Dollarhide has produced since 1945 through primary, waterflood, and CO2 phases, and its Devonian units have operated under miscible CO2 injection since the mid-1980s with performance strong enough to be published as an industry case study.
Magnolia Petroleum and Humble Oil discovered the field, and unit operatorship later passed through Unocal-era owners to Pure Resources and Chevron in the early-2000s consolidation, with successor management continuing the mature CO2 flood.
By your unit decimal, current production, and the long recovery tail CO2 injection creates in light-oil chert reservoirs. Because tertiary response can hold rates for years, insist on a valuation that models it — our written offers are free and show the assumptions.