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A single set of production and injection wells, producing an average of 122oF water at 500 gpm and extracting a ΔT of 25oF (i.e. injecting the spent water at 97oF), would provide up to 6,250,000 Btu/hr (1.8 MWt). This is enough for heating about 1.2 blocks of the downtown area with a mix of two and three storied buildings (180,000 ft2), or about 165 single family homes. If an average building peak load of 35 Btu/hr/ft2 is used this would require 6.30 million Btu/hr and 13.80 billion Btu/yr (0.25 load factor). Assuming a natural gas cost of $1.15/therm, then the heat charges to customers by the City would be about 70% of natural gas rates or about $0.80/therm (therm = 100,000 Btu). The above production would generate about $110,000 annually (137,000 therms at $0.80/therm) in revenue less $18,000 in annual operation and maintenance cost (including $8,000 in electricity cost for the 75 hp well pump and 50 hp distribution pump at $0.04/kWh), gives a net income of $92,000/year. We estimate the investment cost of the two wells at $150,000, main supply and return pipeline cost of $100,000, distribution pipeline costs of $200,000, well pump cost of $50,000, circulating pumps cost of $50,000, plate heat exchanger to isolate the geothermal fluid from the building heating system at $50,000, building retrofit costs of $210,000 ($1.40/ft2 average), and miscellaneous costs of $50,000, for a total capital cost of $860,000, thus the simple payback would be 9.3 years with 100% of the customers hooking up to the system. At 75% and 50% customer penetration rate, the simple payback would be 11.7 and 16.5 years respectively. If the building retrofit costs were assumed by the building owner, then the cost to the City would be less and the payback time reduced to 7.1, 9.4 and 14.1 years respectively. Drilling of wells and retrofitting individual buildings can be time consuming, thus three years should be allowed for project implementation. 5. Direct-Use with Downhole Heat Exchanger Downhole heat exchangers have been used extensively in Klamath Falls, Oregon; Reno, Nevada (Moana area); Rotorua, New Zealand; and Turkey. The downhole heat exchanger (DHE) eliminates the problem of producing and disposing of the geothermal fluid, since only heat is taken from the well. The exchanger consists of a system of pipes or tubes suspended in the well through which “clean” secondary water is pumped or allowed to circulate by natural convection. These systems offer substantial economic savings over surface heat exchangers where a single- well system is adequate (typically less than 0.8 MWt, with well depths up to about 500 feet). Typically, a heating loop of black-iron pipe 1.5 to 3-inches in diameter is used, along with a 3⁄4- inch diameter pipe for the domestic hot water, however, recent experimental work in Klamath Falls has proven that a cross-linked polyethylene (PEX) pipe can be used successfully and thus eliminate the corrosion and pitting problems associated with metal pipe, especially at the air- water interface. Normally, the well is drilled from 10 to 16 inches in diameter, with an 8 to 12- inch casing emplaced. The casing is slotted just below the water surface and at the bottom near the water inflow zone. This produces a vertical convection cell in the well water, and thus maximizes the heat transfer from the well water to the fluid in the DHE (Figures 13 and 14). In Klamath Falls inquirers are normally advised that well water temperature above 140oF is necessary for the adequate performance of the DHE. During our visit to Glenwood Springs, we learned that Civil Engineer Thomas Zancanella had tested a DHE in the Wright well; however he could not find the test results. His recollection was that a 3⁄4-inch diameter copper pipe loop was place in the well and that 5 gpm of 40oF city water was circulated all winter producing 104oF 32PDF Image | GEOTHERMAL RESOURCES GLENWOOD SPRINGS, COLORADO
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