COAs

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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	05-123-45584	Booth S-8-7HN	BAYSWATER EXPLORATION & PRODUCTION LLC 10261	PR 9/1/2021	WATTENBERG 90750	WELD 123 SESE 8 6N66W 6	452439

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Permit	Form: (02 ) 401358088 9/26/2017	This Permit to Drill is approved subject to all the BMPs and COAs on the most recently approved Form 2A and any subsequently approved Form 4 for the Oil and Gas Location. The most recently approved Form 2A and any subsequent Form 4s containing applicable COAs for this location shall be posted onsite during construction, drilling, and completions operations.
Engineer	Form: (02 ) 401358088 9/28/2017	Operator has stated that they will not complete the wellbore at the following measured depths since a 317.s. Stimulation Setback Consent hasn't been obtained from the offset operators: 10,627'-10,850' (Hergert 8-35) 13,581'-13,748' (Schaefer 7DD) 12,133-12,370' (Schaefer 7XD) In the operator comment box of the Form 5A, operator must certify that the operator did not stimulate within 150’ of an existing wellbore operated by a different operator without a signed waiver from that operator and documentation exists to demonstrate this fact. This will include existing wellbores from a different operator that were not originally within 150’ of the planned wellbore, but did end up within 150’ of the as-drilled wellbore. Operator agrees to provide this documentation within two business days via email if requested by COGCC staff. Additionally for the wells below, operator must provide in that same operator comment box, the name and API of the well, nearest perforation to that well, and final separation (wellbore to wellbore distance) from that well: Schaefer 7DD (API #123-32117) Schaefer 7XD (API #123-32119) Hergert 8-35 (API #123-25977)
Engineer	Form: (02 ) 401358088 9/28/2017	Bradenhead tests shall be performed and reported according to the following schedule and Form 17 submitted within 10 days of each test: 1) Within 60 days of rig release and prior to stimulation and 2) If a delayed completion, 6-7 months after rig release and prior to stimulation. 3) Within 30 days after first production, as reported on Form 5A.
Engineer	Form: (02 ) 401358088 9/28/2017	1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU for the first well activity with a rig on the pad and provide 48 hour spud notice for each subsequent well drilled on the pad. 2) Comply with Rule 317.j and provide cement coverage from TD to a minimum of 200' above the Niobrara. Verify coverage with cement bond log. 3) Oil-based drilling fluid is to be used only after all aquifers are covered.
Engineer	Form: (04 ) 402101221 10/18/2019	Submit a Sundry Form 4, Other, "Bradenhead Mitigation" at 6 months with the results from the 6 months of the mitigation.
Engineer	Form: (04 ) 402330774 3/17/2020	Bradenhead test on 2/21/2020 had 1 psig and is now in compliance with Order 1-232. Return well to annual testing.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
Planning	Form: (02 ) 401358088 9/29/2017	Plugged and abandoned wells will be identified pursuant to 319.a.(5)
Emissions mitigation	Form: (02 ) 401358088 9/29/2017	Green Completions - Emission Control System: Test separators and associated flow lines and sand traps shall be installed to accommodate green completions techniques pursuant to COGCC Rules. Operator is working with midstream operators in the area. Operator will connect to a gas sales line prior to flowback and immediately direct salable quality gas down line. The flowback gas shall be thermally oxidized in an emissions control device (ECD), which will be installed and kept in operable condition for at least the first 90 days of production pursuant to CDPHE rules. This ECD shall have an adequate capacity for 1.5 times the largest flowback within a 10 mile radius, will be flanged to route gas to other or permanent oxidizing equipment, and shall be provided with the equipment needed to maintain combustion where non-combustible gases are present.
Odor mitigation	Form: (02 ) 401358088 9/29/2017	Equipment shall be operated in such a manner that odors and dust do not constitute a nuisance or hazard to public welfare. Oil and gas operations shall be in compliance with the Department of Public Health and Environment, Air Quality Control Commission, Regulation No. 2 Odor Emission, 5 C.C.R. 1001-4, Regulation No. 3 (5 C.C.R. 1001-5), and Regulation No. 7 Section XVII.B.1 (a-c) and Section XII.
Drilling/Completion Operations	Form: (02 ) 401358088 9/29/2017	A closed–loop system will be used for drilling operations. Blowout Prevention Equipment (“BOPE”): A double ram and annular preventer will be used during drilling. Stabbing valves shall be installed in the event of reverse circulation and shall be prior tested with low and high pressure fluid. Bradenhead Monitoring: Operator acknowledges and will comply with COGCC Policy for Bradenhead Monitoring during Hydraulic Fracturing Treatments in the Greater Wattenberg Area dated May 29, 2012.
Drilling/Completion Operations	Form: (02 ) 401358088 9/29/2017	One of the first wells drilled on the pad will be logged with Cased hole Pulsed Neutron Log with Gamma Ray Log from TD into the surface casing. All wells on the pad will have a cement bond log with gamma-ray run on production casing (or on intermediate casing if production liner is run) into the surface casing. The horizontal portion of every well will be logged with a measured while-drilling gamma-ray log. The Form 5, Completion Report, for each well on the pad will list all logs run in that well and have those logs attached. The Form 5 for each well shall clearly state “No open-hole logs were run” and shall reference the Rule 317.p Exception granted for the well.
Drilling/Completion Operations	Form: (02 ) 401358088 9/29/2017	Anti-collision: Operator will perform an anti-collision evaluation of all active (producing, shut in, or temporarily abandoned) offset wellbores that have the potential of being within 150 feet of a proposed well prior to drilling operations for the proposed well. Notice shall be given to all offset operators prior to drilling.