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2. A cast-iron bridge plug (CIBP) shall be set inside each string of casing at <br />approximately the elevation of the bottom of the short string casing. If it <br />is not possible to run a CIBP inside each string of casing due to <br />irregularities, acement basket shall be run inside the casing to establish a <br />cement plug. The bridge plug or cement basket will be set at least 25 feet <br />below the Dissolution Surface. If the bridge plug or cement basket cannot <br />be set at least as deep as 25 feet below the Dissolution Surface, the <br />permittee shall file an approvable well repair plan with the Director <br />within 30 days or the well shall be plugged and abandoned per an EPA- <br />approved plugging and abandonment plan within 60 days. <br />3. The well bore will be filled with a conditioned 10 lb. bentonite gel or <br />equivalent. An oil blanket maybe used at the surface to prevent freezing. <br />b. After completion of temporary well plugging, an evaluation will be made as to <br />whether any partial or complete reclamation of affected well sites and roads should <br />be conducted. Reclamation and re-vegetation will be conducted as prescribed by <br />BLM and CDMG Permit requirements and as influenced by weather factors. <br />c. Temporary Plugging Report. Within sixty (60) days after plugging the well, the <br />permittee shall submit a plugging completion report to the Director. The report <br />shall be certified as accurate by the person who performed the plugging operation <br />and the report shall consist of either: (1) a statement that the well was plugged in <br />accordance with the plan; or (2) where actual plugging differed from the plan, a <br />statement that specifies the different procedures followed. <br />5. Resuming Injection After Conclusion of Temporary Suspension: Prior to resuming injection <br />into any well in temporary suspension status, the permittee shall notify the Director of its <br />intent to resume normal mining operations and shall successfully demonstrate mechanical <br />integrity, Part I (no significant leak from the casing). Because American Soda's wells do not <br />use a packer, a successful Part I demonstration shall include passing an MIT pressure test <br />on the casing (as referenced in Part II G(3)(a) of this section) at or above the maximum <br />allowable injection pressure for the well, with no more than 10% change over a 30-minute <br />period. When a well is returned to service, the monitoring analysis in Part II, Section <br />D(1)(i) shall apply to well operations to evaluate cavity integrity. In addition, if a well has <br />been shut in for more than 5 years, the permittee shall run a baseline temperature log, noise <br />log, or oxygen activation log from surface to the top of the cavity, to be used to compare <br />against temperature, noise, or oxygen activation logs run after resuming normal injection <br />operations for the purpose of demonstrating Part II of mechanical integrity (no vertical <br />movement behind casing). Only after a successful Part I mechanical integrity test and <br />notification to the Director have occurred, and EPA written permission received, shall the <br />permittee resume injection. <br />IV Ground Water Monitoring Plan• Back round and Proposed Modifications <br />FINAL Addendum to SOB For Modification No. 9, UIC Area Permit No. C030858-00000 Page 14 of 29 <br />