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Facility Type	Facility ID/ API	Facility Name/ Number	Operator Name/ Number	Status	Field Name/ Number	Location	Location ID	Related Facilities
WELL	05-123-39555	Heartland C30-79-1HN	NOBLE ENERGY INC 100322	SI 3/1/2023	WATTENBERG 90750	WELD 123 SESE 25 4N65W 6	437468

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Engineer	Form: (02 ) 400550055 5/1/2014	Operator acknowledges the proximity of the listed wells: Operator agrees to: provide mitigation option 1 or 2 (per the DJ Basin Horizontal Offset Policy) to mitigate the situation, ensure all applicable documentation is submitted based on the selected mitigation option chosen, and submit a Form 42 (“OFFSET MITIGATION COMPLETED”) for the remediated wells, referencing the API number of the proposed horizontal well(s) stating what appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well. COLLINS 1-1 ( API NO 123-13363),FARR 1 ( API NO 123-11714), VICTOR C 19-13 ( API NO 123-13508),VICTOR C 19-12 ( API NO 123-13761), FREEDOM ONE C 19-5 ( API NO 123-14300),FREEDOM TWO C 19-4 ( API NO 123-14624), STEWART 30-1 ( API NO 123-11797),JOHNSON A-30 ( API NO 123-11961), STEWART 30-2 ( API NO 123-13302),BROSNAHAN 13-30 ( API NO 123-18990), OCOMA UPRR C31-13 ( API NO 123-13400),OCOMO C 31-14 ( API NO 123-13401), OCOMA-UPRR C 31-11 ( API NO 123-13404),OCOMA-UPRR C31-12 ( API NO 123-13405), HUNTSMAN G 13-16 ( API NO 123-14665),MILLER 24-1 ( API NO 123-14440), BURKE 24-3 ( API NO 123-14522),API 24-1 ( API NO 123-14684), CPC PLUSS 25-1 ( API NO 123-12573),PLUSS G 25-8 ( API NO 123-13149), OCOMA G25-8 ( API NO 123-13149),OCOMA G 25-9 ( API NO 123-13355), OCOMA G 25-16 ( API NO 123-13356),OCOMA G25-23 ( API NO 123-15626), GERRITY STATE G 36-01 ( API NO 123-13291),GERRITY STATE G 36-9 ( API NO 123-13292), GERRITY STATE G 36-08 ( API NO 123-13313),STATE G 36-16 ( API NO 123-13314)
Engineer	Form: (02 ) 400550055 5/1/2014	1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU. 2) Comply with Rule 317.i and provide cement coverage from the bottom of the production casing to a minimum of 200' above Niobrara. Verify coverage with cement bond log. 3) Run and submit Directional Survey from TD to base of surface casing. The operator shall comply with Rule 321, and it shall be the operator’s responsibility to ensure that the wellbore complies with setback requirements in commission orders or rules prior to producing the well.
Permit	Form: (02 ) 400550055 5/8/2014	Open hole resistivity and gamma logs shall be run to describe the stratigraphy of the entire well bore and to adequately verify the setting depth of surface casing and aquifer coverage. On a multi-well pad, these open hole logs are only required on one of the first wells drilled on the pad and the Drilling Completion Report - Form 5 for every well on the pad shall identify which well was logged.
Permit	Form: (02 ) 400550055 6/6/2014	Operator must comply with COGCC Policy for Bradenhead Monitoring During Hydraulic Fracturing Treatments in the Greater Wattenberg Area dated May 29, 2012.
OGLA	Form: (06 ) 403999293 12/2/2024	Operator provided COAs: 3rd party wildlife surveys will be conducted on this well prior to rigging up for P&A activities. Should sensitive HPH conditions be identified during the screening process, Chevron will delay the work until conditions (nesting) clear and/or consult directly with CPW for guidance and discussion of potential mitigation measures that may be incorporated. Notification will be given to any adjacent building unit occupants within a 1000 feet of the wellhead of planned P&A start date.
Engineer	Form: (06 ) 403999293 12/10/2024	1) Provide electronic Form 42 Notice of MIRU 2 business days ahead of operations and electronic Form 42 Notice of Plugging Operations 48 hours prior to mobilizing for plugging operations. These are two separate notifications, required by Rules 405.e and 405.l. 2) Prior to placing cement above the base of the Upper Pierre (1580') : verify that all fluid (liquid and gas) migration has been eliminated. If evidence of fluid migration or pressure remains, contact ECMC Engineer for an update to plugging orders. 3) Pump surface casing shoe plug only after isolation has been verified. If surface casing cement is not circulated to surface, shut-in, WOC 4 hours then tag plug – must be at 657’ or shallower and provide a minimum of 10 sx plug at the surface. 4) Leave at least 100’ of cement in the wellbore for each plug without mechanical isolation. 5) After surface plug and prior to cap, verify isolation by either a 15 minute bubble test or 15 minute optical gas imaging recording. If there is indication of flow contact ECMC Engineering. Provide a statement on the 6SRA which method was used and what was observed. Retain records of final isolation test for 5 years. 6) With the Form 6 SRA operator must provide written documentation which positively affirms each COA listed above has been addressed.
Engineer	Form: (06 ) 403999293 12/10/2024	Consistent with Rule 911.a, a Form 27 must be approved prior to cut and cap, conducting flowline abandonment, or removing production equipment. Allow 30 days for Director review of the Form 27; include the Form 27 document number on the Form 44 for offsite flowline abandonment (if applicable) and on the Form 6 Subsequent. Properly abandon flowlines per Rule 1105. If flowlines will be abandoned in place, include with the Form 27: pressure test results conducted in the prior 12 months as well as identification of any document numbers for a ECMC Spill/Release Report, Form 19, associated with the abandoned line.
Engineer	Form: (06 ) 403999293 12/10/2024	Operator shall implement measures to control venting, to protect health and safety, and to ensure that vapors and odors from well plugging operations do not constitute a nuisance or hazard to public welfare.
Engineer	Form: (06 ) 403999293 12/10/2024	Prior to starting plugging operations a bradenhead test shall be performed if there has not been a reported bradenhead test within the 60 days immediately preceding the start of plugging operations. 1) If, before opening the bradenhead valve, the beginning pressure is greater than 25 psi, sampling is required. 2) If pressure remains at the conclusion of the test, or if any liquids were present during the test, sampling is required. The Form 17 shall be submitted within 10 days of the test. Sampling shall comply with Operator Guidance - Bradenhead Testing and Reporting Instructions. If samples are collected, copies of all final laboratory analytical results shall be provided to the ECMC within three (3) months of collecting the samples. If there is a need for sampling, contact ECMC engineering for verification of plugging procedure.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
General Housekeeping	Form: (02 ) 400550055 6/6/2014	Housekeeping will consist of neat and orderly storage of materials and fluids. Wastes will be temporarily stored in sealed containers and regularly collected and disposed of at offsite, suitable facilities. If spills occur prompt cleanup is required to minimize any commingling of waste materials with stormwater runoff. Routine maintenance will be limited to fueling and lubrication of equipment. Drip pans will be used during routine fueling and maintenance to contain spills or leaks. Any waste product from maintenance will be containerized and transported offsite for disposal or recycling. There will be no major equipment overhauls conducted onsite. Equipment will be transported offsite for major overhauls. Cleanup of trash and discarded materials will be conducted at the end of each work day. Cleanup will consist of patrolling the roadway, access areas, and other work areas to pickup trash, scrap debris, other discarded materials, and any contaminated soil. These materials will be disposed of properly.
Storm Water/Erosion Control	Form: (02 ) 400550055 6/6/2014	Stormwater management plans (SWMP) are in place to address construction, drilling and operations associated with Oil & Gas development throughout the state of Colorado in accordance with Colorado Department of Public Health and Environment (CDPHE) General Permit No. COR-038637. BMP's will be constructed around the perimeter of the site prior to, or at the beginning of construction. BMP's used will vary according to the location, and will remain in place until the pad reaches final reclamation.
Material Handling and Spill Prevention	Form: (02 ) 400550055 6/6/2014	Spill prevention Control and Countermeasures (SPCC) plans are in place to address any possible spill associated with Oil & Gas operations throughout the state of Colorado in accordance with CFR 112.
Drilling/Completion Operations	Form: (02 ) 400550055 6/6/2014	Anti-collision: Prior to drilling operations, Operator will perform an anti-collision scan of existing offset wells that have the potential of being within close proximity of the proposed well. This anti-collision scan will include definitive MWD or gyro surveys of the offset wells with included error of uncertainty per survey instrument, and compared against the proposed well path with its respective error of uncertainty. If current surveys do not exist for the offset wells, Operator may have gyro surveys conducted to verify bottomhole location. The proposed well will only be drilled if the anti-collision scan results indicate that there is not a risk for collision, or harm to people or the environment. For the proposed well, upon conclusion of drilling operations, an as-constructed gyro survey will be submitted to COGCC with the Form 5.