COGIS - Conditions of Approval Results

   TEP ROCKY MOUNTAIN LLC    Speciality Restaurants SG 334-32   WELL#: 412199   Status:IJ as of 4/1/2020   SWSE 32 7S 96W GARFIELD COUNTY
Search Results - 6 record(s) returned.
Type Source Conditions of Approval
Best Management Practices
Engineer
02
401961247
7/17/2019
1) Operator shall comply with the most current revision of the Northwest Notification Policy.

2) Operator shall comply with the most current revision of the Garfield County Rulison Field Notice to Operators, with the following exception: All field notice requirements specified in that Notice to Operators are superseded by the requirements of the most current revision of the Northwest Colorado Notification Policy (see Condition of Approval #1).

3) The Operator shall monitor the bradenhead pressure of the proposed well and all offset wells under Operatorís control which penetrate the stimulated formation and have a treated interval separation of 300 feet or less. Monitoring shall occur from 24 hours prior to stimulation and shall continue until 24 hours after stimulation is complete. Recording shall be at a frequency of at least once per 24 hours with the capability of recording the maximum pressure observed during each 24 hour period. Operator shall notify COGCC Engineering staff if bradenhead pressures increase by more than 200 psig. 

Engineer
02
401961247
7/17/2019


1. Operator required to contact COGCC to discuss Step Rate Test criteria for Maximum Surface Injection Pressure determination.

2. Prior approval of Form 4 is required for step rate and injectivity tests.

3. Operator shall provide any missing formations tops encountered from surface to TD that were not previously reported, including Ohio Creek. Missing formation tops shall be reported on a Form 4, unless a Form 5 is submitted for changes in well construction, in which case, the formation tops shall be reported on the new Form 5.

UIC
02
401961247
7/15/2019
1. Injection is not authorized until approval of Subsequent Forms 31 and 33.
2. Retrieve water sample(s) from new injection zone(s) before stimulating formation. Samples must be analyzed for Total Dissolved Solids at a minimum.
3. PRIOR TO PERFORMING OPERATIONS: Operator is required to contact COGCC to discuss acid and fracturing jobs. Approval of Form 4 may be required for acid and fracturing jobs. (As of 4/13/2016)
4. PRIOR TO PERFORMING OPERATIONS: Operator is required to contact COGCC to discuss Step Rate Test or Injectivity Test criteria for Maximum Surface Injection Pressure determination. Prior approval of Form 4 may be required for step rate and injectivity tests.
5. Well must pass MIT witnessed by COGCC before Subsequent Forms 31 and 33 will be approved. Well in must be in injection configuration.
6. Operator must have approved Form 26(s) on file before Form 31-Subsequent and Form 32-Subsequent will be approved.

UIC
02
400790912
3/25/2015
1. Injection is not authorized until approval of Forms 31 and 33.
2. Operator required to contact COGCC to discuss Step Rate Test criteria for Maximum Surface Injection Pressure determination.
3. Prior approval of Form 4 is required for step rate and injectivity tests.
4. Retrieve water sample(s) from injection zone(s) before stimulating formation. Samples must be analyzed for Total Dissolved Solids at a minimum.
5. Operator shall provide any missing formations tops encountered from surface to TD that were not previously reported, including Ohio Creek.  Missing formation tops shall be reported on a Form 4, unless a Form 5 is submitted for changes in well construction, in which case, the formation tops shall be reported on the new Form 5. 

Engineer
02
400790912
3/25/2015
1) Operator shall comply with the most current revision of the Northwest Notification Policy. See attached notice.

Agency
02
400061626
N/A
1)COMPLIANCE WITH THE MOST CURRENT REVISION OF THE NORTHWEST COLORADO NOTIFICATION POLICY IS REQUIRED.

2)GARFIELD COUNTY RULISON FIELD NOTICE TO OPERATORS. NOTE: ALL NOTICES SHALL BE GIVEN VIA E-MAIL. SEE ATTACHED NOTICE

3)CEMENT TOP VERIFICATION BY CBL REQUIRED. 

4)OPERATOR MUST ENSURE 110 PERCENT SECONDARY CONTAINMENT FOR ANY VOLUME OF FLUIDS CONTAINED AT WELL SITE DURING DRILLING AND COMPLETION OPERATIONS. IF FLUIDS ARE CONVEYED VIA PIPELINE, OPERATOR MUST IMPLEMENT BEST MANAGEMENT PRACTICES TO CONTAIN ANY UNINTENTIONAL RELEASE OF FLUIDS.

5)THE MOISTURE CONTENT OF ANY DRILL CUTTINGS IN A CUTTINGS PIT, TRENCH, OR PILE SHALL BE AS LOW AS PRACTICABLE TO PREVENT ACCUMULATION OF LIQUIDS GREATER THAN DE MINIMIS AMOUNTS. AT THE TIME OF CLOSURE, THE DRILL CUTTINGS MUST ALSO MEET THE APPLICABLE STANDARDS OF TABLE 910-1.

6)THE PROPOSED SURFACE CASING IS MORE THAN 50' BELOW THE DEPTH OF THE DEEPEST WATER WELL WITHIN 1MILE OF THE SURFACE LOCATION WHEN CORRECTED FOR ELEVATION DIFFERENCES. THE DEEPEST WATER WELL WITHIN 1 MILE IS 95 FEET DEEP. 


COGIS - Best Management Practices COGIS - Best Management Practices Results

Search Results - 1 record(s) returned.
BMP TypeSource BMP

02
401961247
6/12/2019