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. 1. The wellhead on 29-24 will be modified to ANSI class 900 valves and fittings. A logging head will be installed on top of the long string tubular. The logging head will facilitate pressure control while performing the temperature fogs. 2. Natural gas will be directed through flow and pressure instrumentation and will be initiated down either or both the short tubing string or the short string casing on well 29-24. Concurrent with the natural gas injection, fluid from the cavity will be directed from the long string tubing on well 29- 24 through flow and pressure measurement and combined with the wellfield production fluid and transported by pump to the plant stripping facility. 3. ASLLP envisions initiating the test at rates between 20 - 50 gallons per minute of displaced fluid from the cavity for the initial startup. This will allow ASLLP to address any equipment or instrumentation issues that may be present. 4. During the startup phase, well 29-24 will be temperature logged every 24 hours. At present, it is unknown the degree of resolution that the temperature log will provide. It is anticipated that by shutting in the well for a period of 4 - 8 hours, a measurable temperature difference between the fluid and gas can be observed. 5. The initial temperature logs will be performed after 0, 2, 4, 6, and 8 hours of shutting in the wall. The "wait :ime" procedure for the temperature log • will be adopted to correspond with the highest degree of gas-fluid intertace resolution. 6. As information and experience is gained on the temperature logging procedure, the time interval between temperature logs may be adjusted. It is possible that the temperature log time interval could be increased up to 96 hours between logs. 7. After completion of the startup phase, the injection rate of natural gas and the subsequent flow of displaced fluid will be slowly increased. The flow of displaced fluid will be the operational control. It is anticipated that displaced fluid flow rates of 200 gallons per minute can be achieved and maintained. 8. As the injection pressure of the natural gas approaches the natural gas pipeline pressure, compression of the natural gas will be initiated. The compressor will increase the pressure of the natural gas. Natural gas flow rates will be maintained at a higher pressure. 9. The displacement will continue until the majority of the fluid is displaced from the cavity. ASLLP proposes placing a 50' - 100' safety buffer from the bottom of the long string tubing. The safety buffer would insure that natural gas would not be introduced into the displaced fluid. The safety buffer will prevent the characterization of the last 50' - 100' of the cavity. 10. Upon completion of the displacement, the well will be shut in. The gas pressure from the well will be slowly vented and directed through the gas • pipelines to the Piceance facility boilers and/or gas separator flares.