“With EcoVapor it's simple. They completely take care of and manage all my tank pressure and emissions. EcoVapor also eliminates any O2 in my lines.”

- Operator Feedback

Case Study: Oxygen Destroyer System

As gathering systems have increasingly tightened and enforced their oxygen specifications to 10 PPM or less, vapor recovery units (VRUs) pulling off of oil storage tanks are becoming unusable. Since oxygen invariably contaminates tank vapors, standard VRUs cannot process this gas stream within oxygen specifications. While EcoVapor has long had a line of VRUs integrated with its patented Oxygen Destroyer System (ODS), a large Permian producer challenged us to develop a stand-alone ODS that could be paired with their existing fleet of VRUs.

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Case Study: Southern Oklahoma - New Completion

New wells often have initial production that comes on at high rates and pressures. In this case, an established producer in southern Oklahoma drilled three wells from a pad site. While all of the wells were “keepers,” one of the wells was extraordinarily strong. Based on initial test data, EcoVapor recommended the site be piped to accommodate at least two of our largest ERS170 systems. The oil produced from the target formation has an API° in the high 50’s, so with the high production rates we were expecting correspondingly high amounts of flash gas off the tanks.

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Case Study: North Dakota

An established Williston Basin producer with production in the core Bakken area with many multi-well pads and lots of undrilled acreage. The producing sites were often making in excess of 2,000 Bbl/d. The site facilities included high and low pressure treaters, used LACT units for oil transfer, and had access to a gas gathering system operating at approximately 150 psi. The vertical heater treaters were operating between 115oF and 138oF. North Dakota has put in place well-publicized rules on flaring with annually declining limits. This is being done to address the concerns regarding wasted resources, royalty matters, unnecessary emissions, and light pollution associated with flaring on a large scale.

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Case Study: DJ Basin - Tank Vapor Recovery Downstream of VRT

A mid-sized independent producer had developed a pad site with eight horizontal Niobrara wells. The production facilities included sixteen 400 barrel tanks, high pressure separators, low pressure separators, as well as two vapor towers operating <1 psi. The operator was able to safely capture flash gas, control tank pressures, cut site emissions of CO, NOx and VOCs by 90%, avoid regulatory entanglements and fines, and earn revenue from the recovered flash gas that exceeded the lease cost of the ERS unit.

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Case Study: Southern Oklahoma – Vapor Tower Replacement

A large independent operator was developing deep horizontal shale wells in southern Oklahoma. The oil produced had a high API gravity and generated large volumes of flash gas. The operator’s standard production equipment consisted of a horizontal three-phase separator operating at approximately 100 psi, a vapor recovery tower with dedicated compression, and four to eight 500 bbl oil tanks. The operator eventually installed eighteen ERS units and removed every vapor tower compressor from those sites.

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Case Study: The Pipeline’s Perspective

A large gas gatherer was experiencing frequent high oxygen events on its system. The interstate pipeline taking gas from the gatherer’s processing plant had an oxygen limit of 10 ppm in its tariff specifications, began to actively enforce it, and at one point refused to take gas until the oxygen level was back below the 10 ppm limit. The gatherer required operators to only use vapor recovery systems upstream of condensate tanks. Despite claims that vapor recovery systems installed upstream of the oil storage tanks are in an oxygen-free environment, the gatherer continued to see frequent high oxygen events.

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