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6.5 DrillingCost Model Validation 6.4.2 Wellcost Lite model description Chapter 6 Drilling Technology and Costs developed for DOE and was used to evaluate research and development needs. The IMGEO model included cost components for geological studies, exploration, development drilling, gathering systems, power facilities, and poweronline. IMGEO led to the development of the Wellcost1996 model. As a part of the Advanced Drilling Study (Pierce et al., 1996), a more comprehensive costing model was developed, which could be used to evaluate advanced drilling concepts. That model has been simplified to the current Wellcost Lite model. 6.5.1 Basecase geothermal wells 619 Wellcost Lite is a sequential event and direct costbased model. This means that time and costs are computed sequentially for all events that occur in the drilling of the well. The well drilling sequence is divided into intervals, which are usually defined by the casing intervals, but can be used where a significant change in formation drilling hardness occurs. Current models are for 4, 5, and 6 intervals – more intervals can be added as required. The model calculates the cost of drilling by casing intervals. The model is EXCEL spreadsheetbased and allows the input of a casing design program, rate of penetration, bit life, and trouble map for each casing interval. The model calculates the time to drill each interval including rotating time, trip time, mud, and related costs and endofinterval costs such as casing and cementing and well evaluation. The cost for materials and the time required to complete each interval is calculated. The time is then multiplied by the hourly cost for all rig timerelated cost elements such as tool rental, blowout preventers (BOP), supervision, etc. Each interval is then summed to obtain a total cost. The cost components of the well are presented in a descriptive breakdown and on the typical authorization for expenditures (AFE) form used by many companies to estimate drilling costs. The cost of drilling geothermal wells, including enhanced geothermal wells and hot dry rock wells exclusive of well stimulation costs, was modeled for similar geologic conditions and with the same completion diameter for depths between 1,500 and 10,000 m. The geology was assumed to be an interval of sedimentary overburden on top of hard, abrasive granitic rock with a bottomhole temperature of 200°C. The rates of penetration and bit life for each well correspond to drilling through typical poorly lithified basin fill sediments to a depth of 1,000 m above the completion interval, below which granitic basement conditions are assumed. The completion interval varies from 250 m for a 1,500 m well to 1,000 m for wells 5,000 m and deeper. The casing programs used assumed hydrostatic conditions typical for geothermal environments. All the well plans for determining base costs with depth assume a completion interval drilled with a 10 5/8” bit. The wells are not optimized for production and are largely trouble free. For the basecase wells at each depth, the assumed contingency is 10%, which includes noncatastrophic costs for troubles during drilling. The well costs that are developed for the EGS consideration are for both injectors and producers. The upper portion of the cased production hole may need to accommodate some form of artificial lift or pumping. This would mean that the production casing would be run as a liner back up to the point at which the larger diameter is needed. Current technology for shaft drive pumps limits the setting depths to about 600 m (2,000 ft). If electric submersible pumps are to be set deeper in the hole, the required diameter will have to be accommodated by completing the well with liners, leaving greaterPDF Image | Drilling Technology and Costs
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