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Review of EGS and Related Technology

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Review of EGS and Related Technology ( review-egs-and-related-technology )

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Review of EGS and Related Technology – Status and Achievements Chapter 4 4­31 • In contrast to what happened at Rosemanowes – where stimulation almost always focused on the bottom of the wells – the upper zones at the Soultz project would stimulate readily when fresh water was used; while, with heavier brines, the lower zones would be stimulated. • While microseismic monitoring works well overall to map fractures, we still do not completely understand the relationship between mapped acoustic emissions events and fluid flow. • We can drill deep wells into hard crystalline rock, control their direction, and log them. • There are aspects of drilling these wells that still need work. Problems with high­temperature mud motors make directional control of deep, high­temperature wells difficult. • Near­wellbore pressure drop can have a significant impact on the overall pressure drop throughout the system. • There are several methods for reducing near­wellbore pressure drops such as acidizing, emplacing proppants, and stimulating with fracturing fluids. Further testing is needed to determine which of these is most beneficial. • Acidizing reduced the injection pressure for a given flow rate but the reason for this is not clear. • Injection testing shows a nearly linear correlation between wellhead pressure and injection rate. This is typical of flow in porous media in general, suggesting that there was an overall fracturing pattern, not separate discrete fractures. It also reinforces the suspicion that the permeability is not dependent on pressure. • While injecting at high pressures can increase flow rates during operation of the reservoir, it can also stimulate fracture growth. Another alternative to high­pressure injection is pumping the production well. • Logging tools have temperature limits, and there is little incentive for oil and gas to raise these limits to very high temperatures.

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