Cymric, straddling Highway 33 near McKittrick on the west side of Kern County, is proof that an oil field’s best years can come nearly a century after discovery. Found in 1909, Cymric produced modestly for decades until intensive steam development — led by Chevron through the 1990s and 2000s — pushed it into the ranks of California’s top-producing fields, with output peaking in the mid-1990s and cumulative recovery on the order of half a billion barrels. Its shallow, heavy-oil reservoirs remain one of the state’s most concentrated thermal operations.
The Nacirema Oil Company completed Cymric’s discovery well in November 1909, finding heavy 15-degree oil at about 900 feet. For its first several decades the field was a minor neighbor to the giants at Midway-Sunset and McKittrick, producing viscous crude in modest volumes from shallow zones where primary recovery could not move most of the oil in place.
The transformation began when thermal methods matured. Chevron and predecessor companies expanded cyclic steaming and steam drives across the Tulare sands and diatomite intervals, and Cymric’s production climbed through the 1980s and 1990s — the field’s peak year came in 1996, more than 11 million barrels, followed by continued strong output through the 2000s as steam projects widened.
Cymric also illustrates the hazards of heating shallow, fractured ground: the field drew statewide attention in 2019 when large surface expressions — uncontrolled flows of oil and water linked to high-pressure steam injection — prompted regulatory scrutiny and changes to injection practices. Chevron has remained the principal operator, managing the field within California’s tightened thermal-injection oversight.
Cymric produces from stacked reservoirs on a faulted anticlinal trend along the basin’s western margin: unconsolidated Pleistocene Tulare sands charged with heavy oil, underlying diatomite and porcelanite of the Monterey and McKittrick sections, and deeper Miocene zones with lighter crude. The shallow zones combine high oil saturation with low natural mobility — classic thermal-recovery geology. Faulting and steep dips complicate steam placement, and the diatomite’s weak mechanical character demands careful pressure management, a lesson underscored by the field’s surface-expression events.
Steam is the engine of Cymric’s production. Operators use cyclic steaming — inject, soak, produce — on dense well patterns, plus continuous steam drives in suitable zones, to cut the viscosity of crude that otherwise will not flow. Royalty income accordingly tracks steam intensity and oil price together. Regulation is a live factor here: after the 2019 surface expressions, CalGEM tightened oversight of high-pressure cyclic steaming, and statewide setback rules govern work near sensitive locations. These are operating realities, not death sentences — the field continues to produce at scale under the revised rules.
Cymric royalties come from a field that hit peak production within living memory yet carries more regulatory friction than it did in the 1990s. Honest valuation prices both facts: substantial remaining heavy oil under active steam, and a California permitting environment that has narrowed how aggressively operators can chase it. The result is a wide gap between what informed and uninformed buyers will pay. We evaluate the actual wells and injection activity behind your decimal — we buy minerals and royalties in Kern County and provide free written offers.
County-level well data, production charts, and selling guides for the counties this field spans:
No. Regulators scrutinized and restricted certain high-pressure steaming practices, and the operator adjusted injection programs, but the field has continued producing. The episode is one reason current, well-level information matters more than field headlines when valuing an interest.
Steam is generated largely by burning natural gas, so high gas prices raise the operator’s cost per barrel and can reduce steam injection in marginal areas. Your royalty is paid on oil sold, not on costs, but injection decisions influence how much oil your wells produce.
The most useful are a recent revenue statement showing operator, property name, and decimal interest, plus the deed or probate documents in your chain of title. With those we can match your interest to specific wells and produce a free written offer.