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COGIS DB
 
Facility TypeFacility ID/
API		Facility Name/
Number		Operator Name/
Number		StatusField Name/
Number		LocationLocation IDRelated Facilities
WELL05-123-38113Woolley Sosa
2F-7H-E168 		CRESTONE PEAK RESOURCES OPERATING LLC
10633		PR
7/31/2017		WATTENBERG
90750		WELD  123
SWNW 7 1N68W 6		305447View Related
 
COGIS - Conditions of Approval Results
TypeSource DocumentConditions of Approval
PermitForm: (02 )
400450179
8/27/2013		Operator must meet water well testing requirements per Rule 318A.
PermitForm: (02 )
400450179
8/27/2013		ON HOLD: Requesting corrected Rule #'s on Exception Loc Request letter. Add Location ID #.
EngineerForm: (02 )
400450179
9/15/2013		Operator acknowledges the proximity of the Woolley A 1-7 (123-09093) and Thomas E Unit 2 (123-12370) wells. Operator agrees to: provide mitigation option 1or 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 (“OTHER – AS SPECIFIED BY PERMIT CONDITION”) stating what appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well.
EngineerForm: (02 )
400450179
9/15/2013		1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU.. 2) Comply with Rule 317.i and provide cement coverage from end of 7” casing to a minimum of 200' above Niobrara and from 200’ below Shannon to 200’ above Sussex. Verify coverage with cement bond log. 3) Comply with Rule 321. Run and submit Directional Survey from TD to base of surface casing. Ensure that the wellbore complies with setback requirements in commission orders or rules prior to producing the well.
EngineerForm: (02 )
400868376
10/30/2015		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 via Form 42 for all subsequent wells drilled on the pad. 2) Comply with Rule 317.j. and provide cement coverage from TD to a minimum of 200' above Niobrara and from 200’ below Shannon to 200’ above Sussex. Verify coverage with cement bond log.
EngineerForm: (02 )
400868376
10/30/2015		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”) stating that appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well. Thomas E Unit 1 (123-10710)
EngineerForm: (04 )
401126476
10/12/2016		1) This Form 4 makes changes to the casing and cementing program approved on the Form 2 and must be displayed with the Form 2 while drilling. 2) Submit Form 42 electronically to COGCC 48 hours prior to MIRU (spud notice) for the first well activity with a rig on the pad and provide 48 hour spud notice via Form 42 for all subsequent wells drilled on the pad. 3) Comply with Rule 317.j. and provide cement coverage from TD to a minimum of 200' above Niobrara and from 200’ below Shannon to 200’ above Sussex. Verify coverage with cement bond log.
EngineerForm: (04 )
401126476
10/12/2016		Bradenhead tests shall be performed according to the following schedule and the 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 months after rig release and prior to stimulation. 3) Within 30 days after first production, as reported on Form 5A.
EngineerForm: (04 )
402757558
7/28/2021		1. Operator will implement measures to control venting, to protect health and safety, and to ensure that vapors and odors from well operations do not constitute a nuisance or hazard to public welfare. 2. Prior to starting bradenhead mitigation, if a sample has not been collected within the last twelve months collect bradenhead and production gas samples for laboratory analysis. Sampling will comply with Operator Guidance - Bradenhead Testing and Reporting Instructions, Appendix A: Liquid and Gas Sampling. Copies of all final laboratory analytical results will be provided to the COGCC within three months of collecting the samples. 3. Operator will implement measures to get an initial estimate of the gas flow rate and/or volume from the bradenhead. During the shut-in period record pressure data to adequately characterize the build-up. This mitigation plan may be used for six consecutive months from the date test reported on the Form 17. 4. At the conclusion of the six months (11/19/2021), conduct a new bradenhead test and submit the Form 17 within ten days of the test and submit a Form 4 Sundry that summarizes current well condition. The sundry should include details of the future plans, sample analysis interpretation, and the flow rate information and pressure data. Shut in bradenhead pressure shall not exceed 50 psig.
EngineerForm: (04 )
402910975
1/10/2022		1. Operator will implement measures to control venting, to protect health and safety, and to ensure that vapors and odors from well operations do not constitute a nuisance or hazard to public welfare. 2. Prior to starting bradenhead mitigation, if a sample has not been collected within the last twelve months collect bradenhead and production gas samples for laboratory analysis. Sampling will comply with Operator Guidance - Bradenhead Testing and Reporting Instructions, Appendix A: Liquid and Gas Sampling. Copies of all final laboratory analytical results will be provided to the COGCC within three months of collecting the samples. 3. Operator will implement measures to get an initial estimate of the gas flow rate and/or volume from the bradenhead. During the shut-in period record pressure data to adequately characterize the build-up. This mitigation plan may be used for six consecutive months from the date test reported on the Form 17. 4. At the conclusion of the six months (06/28/2022), conduct a new bradenhead test and submit the Form 17 within ten days of the test and submit a Form 4 Sundry that summarizes current well condition. The sundry should include details of the future plans, sample analysis interpretation, and the flow rate information and pressure data. Shut in bradenhead pressure shall not exceed 50 psig.
EngineerForm: (04 )
403085835
7/11/2022		1. Operator will implement measures to control venting, to protect health and safety, and to ensure that vapors and odors from well operations do not constitute a nuisance or hazard to public welfare. 2. Bradenhead gas is not to be vented to the atmosphere; any gas from the Bradenhead will be routed to an enclosed tank and/or combustor. Shut in bradenhead pressure shall not exceed 50 psig. Operator will implement measures to get an estimate of the gas flow rate and/or volume from the bradenhead. 3. Within thirty days of 06/28/2023, conduct a bradenhead test, submit a Form 17, and submit a Form 4 Sundry that summarizes current well condition. The sundry should include details of the future plans, sample analysis interpretation, bradenhead test description, and the flow rate information and pressure data. 4. Shut well in for at least seven days to monitor and collect data to characterize build up pressures then conduct a new bradenhead test and submit the Form 17 within ten days of the test. 5. If a sample has not been collected from surface casing within the last twelve months collect bradenhead gas samples for laboratory analysis. Sampling will comply with Operator Guidance - Bradenhead Testing and Reporting Instructions, Appendix A: Liquid and Gas Sampling. Copies of all final laboratory analytical results will be provided to the COGCC within three months of collecting the samples.
EngineerForm: (04 )
403444795
7/14/2023		1. Operator will implement measures to control venting, to protect health and safety, and to ensure that vapors and odors from well operations do not constitute a nuisance or hazard to public welfare. 2. Bradenhead gas is not to be vented to the atmosphere; any gas from the Bradenhead will be routed to an enclosed tank and/or combustor. Shut in bradenhead pressure shall not exceed 50 psig. Operator will implement measures to get an estimate of the gas flow rate and/or volume from the bradenhead. 3. Within thirty days of 06/28/2024, conduct a bradenhead test, submit a Form 17, and submit a Form 4 Sundry that summarizes current well condition. The sundry should include details of the future plans, sample analysis interpretation, bradenhead test description, and the flow rate information and pressure data. 4. Shut well in for at least seven days to monitor and collect data to characterize build up pressures then conduct a new bradenhead test and submit the Form 17 within ten days of the test. 5. If a sample has not been collected from surface casing within the last twelve months collect bradenhead gas samples and production gas samples for laboratory analysis. Sampling will comply with Operator Guidance - Bradenhead Testing and Reporting Instructions, Appendix A: Liquid and Gas Sampling. Copies of all final laboratory analytical results will be provided to the COGCC within three months of collecting the samples.
EngineerForm: (04 )
403861292
8/8/2024		1. Operator shall implement measures to control venting, to protect health and safety, and to ensure that vapors and odors from well operations do not constitute a nuisance or hazard to public welfare. 2. Bradenhead gas is not to be vented to the atmosphere; any gas from the Bradenhead will be routed to the specified abatement system. Shut in bradenhead pressure shall not exceed 50 psig. Operator shall implement measures to get an estimate of the gas flow rate and/or volume from the bradenhead. 3. Within thirty days of 08/08/2025, submit a Form 4 Sundry that summarizes current well condition. The sundry should include details of the future plans, sample analysis interpretation, bradenhead test description, and the flow rate information and pressure data. 4. Shut well in for at least seven days to monitor build up pressures then conduct a new bradenhead test and submit the Form 17 within ten days of the test. 5. If a sample has not been collected from surface casing within the last twelve months collect bradenhead gas samples for laboratory analysis. Sampling shall comply with Operator Guidance - Bradenhead Testing and Reporting Instructions, Appendix A: Liquid and Gas Sampling. Copies of all final laboratory analytical results shall be provided to the ECMC within three months of collecting the samples.
 
COGIS - Best Management Practice Results
BMP TypeSource DocumentBest Management Practices
Drilling/Completion OperationsForm: (02 )
400450179
9/19/2013		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.
Drilling/Completion OperationsForm: (02 )
400450179
9/19/2013		Encana will comply with the “COGCC Policy for Bradenhead Monitoring During Hydraulic Fracturing Treatments in the Greater Wattenberg Area”, dated May 29, 2012.
PlanningForm: (02 )
400868376
11/5/2015		Maximize equipment and wellhead setbacks from occupied buildings and residences to the extent feasible and practicable, as determined by Encana.
PlanningForm: (02 )
400868376
11/5/2015		Distance to Erie Building Units. For theVessels Minerals Well Pad, the minimum distance between a well or surface equipment, and the nearest exterior wall of an existing Erie Building Unit (as of the Effective Date) shall not be less than the following 1,050 feet. Compliance with this requirement shall be determined from the actual asbuilt locations of the well or surface equipment. Nothing herein shall be construed to grant Encana any surface rights on property owned by the Town or another person. No Pad Site will be located on Town property without authorization by the Town Board of Trustees.
PlanningForm: (02 )
400868376
11/5/2015		Encana shall conduct all operations in accordance with the plans discussed during the Conceptual Review Process as updated from time to time.
Community Outreach and NotificationForm: (02 )
400868376
11/5/2015		Prior to commencement of any new drilling or completion operations, provide notification to landowners within one-half (1/2) mile of the well-site.
Community Outreach and NotificationForm: (02 )
400868376
11/5/2015		Prior to commencement of any new drilling or completion operations, provide to an Erie designated staff member the following for the well-site for informational purposes only, which Encana may revise from time to time during operations: a) A summary of planned operations, including identified access points and operational timeline, for posting to a local community information web-page b) A site plan for site preparation, mobilization and demobilization c) A plan for interim reclamation and vegetation of the site and final reclamation of the site d) A plan for noise, light and dust mitigation, to the extent feasible e) A traffic management plan f) Updates of this information if any change during operations
Community Outreach and NotificationForm: (02 )
400868376
11/5/2015		Encana shall include its contact information on both the mailed notice required by Article III, Section 8 and the posted notice required by Article III, Section 9. This information shall include both a telephone number for Encana and the address and hours of Encana’s Erie community office. Members of the public with concerns or complaints regarding the oil and gas development covered by this Agreement may use this information to speak with Encana.
Traffic controlForm: (02 )
400868376
11/5/2015		Encana will implement the Traffic Management Plan required by Article III, Section 3, Subpart 10.
Traffic controlForm: (02 )
400868376
11/5/2015		To reduce truck traffic, Erie and Encana will encourage the use of nearby water resources for the drilling and hydraulic fracturing of wells at the pad sites, including the use of Erie municipal water when determined technically feasible and economically practicable by Encana.
General HousekeepingForm: (02 )
400868376
11/5/2015		Encana will install down cast lighting or some other form of lighting that mitigates light pollution and spill-over onto adjacent properties; provided, however, that Encana may still use lighting that is necessary for public and occupational safety.
General HousekeepingForm: (02 )
400868376
11/5/2015		Access roads to well and production facilities that connect to a street within Erie shall be improved from the point of connection to a street within Erie a minimum distance of two hundred (200) feet on the access road as specified by the then current requirements of the Code.
General HousekeepingForm: (02 )
400868376
11/5/2015		Upon the request of either party, the Parties may revise one or more of these BMPs if they mutually agree such revision would better avoid or mitigate impacts the BMP(s) is intended to address.
General HousekeepingForm: (02 )
400868376
11/5/2015		Encana will recycle and reuse water at the pad sites and otherwise minimize waste water production to the extent that it determines such recycling, reuse, and waste water minimization is technically and economically feasible.
General HousekeepingForm: (02 )
400868376
11/5/2015		Oil and gas well facilities (above ground) within the Erie Town Limits shall be fenced as specified by the then current requirements of the Code.
General HousekeepingForm: (02 )
400868376
11/5/2015		Road repairs. (a) Erie and Encana recognize that truck traffic accessing the Identified Well Pads may cause damage to Erie roads and that road repairs may be needed to mitigate such damage. To this end, Encana will arrange for a qualified outside consultant to perform a road impact study for all Erie roads that are used to access an Identified Well Pad during the Term of this Agreement. The consultant will conduct the first part of the study prior to Encana’s operations at such Well Pad and the second part of the study after Encana completes all drilling and hydraulic fracturing at such Well Pad. Encana and Erie will use these studies to determine the extent of any damage accruing to the road during the study period. Encana will then promptly pay Erie to repair such damage or else arrange and pay the cost of such repairs itself whichever Erie prefers. (b) Encana shall maintain Financial Assurance to secure its road repair obligations under this Agreement. The amount of such Financial Assurance shall equal Erie’s annual road maintenance budget as of the Effective Date multiplied by the percentage yielded by dividing the total number of Erie road miles as of the Effective Date into the number of such road miles that Encana will use to access the Identified Well Pads. Encana shall select the form of such Financial Assurance and shall maintain such Assurance until Encana fulfills its obligation to repair road damage under Subsection (a).
Material Handling and Spill PreventionForm: (02 )
400868376
11/5/2015		Utilize steel-rim berms around tanks and separators instead of sand or soil berms
Material Handling and Spill PreventionForm: (02 )
400868376
11/5/2015		Encana shall use steel rim berms or some other state of the art technology that will contain fluids and other material instead of sand or soil berms. 13
Noise mitigationForm: (02 )
400868376
11/5/2015		Encana will comply with the following noise mitigation requirements at all pad sites: (a) For db(A) scale noise, Encana will insure that the noise level from operations subject to the light industrial zone noise standard under COGCC Regulations 802.b and 604.c.(2)(A) does not exceed sixty (60) db(A) and that the noise level from operations subject to the industrial zone noise standard under COGCC Regulations 802.b and 604.c.(2)(A) is reduced at least five (5) db(A) below the maximum level permitted by those Regulations. For this purpose, the noise level shall be measured as set forth in COGCC Regulations 802.b & c, except no measurements shall be taken when traffic is passing the sound level meter, Encana shall be present during all measurements, and building units shall be limited to those units existing as of the Effective Date. As set forth in COGCC Regulation 802.b, the noise levels shall be subject to increase for a period not to exceed fifteen (15) minutes in any one (1) hour period and reduction for periodic, impulsive or shrill noises. (b) For db(C) scale noise, Encana shall comply with the requirements of COGCC Regulation 802, as such requirements may be amended during the term of this Agreement. Date
Emissions mitigationForm: (02 )
400868376
11/5/2015		Well leak detection and repair (a) To identify leaks, Encana will perform audio, visual and olfactory inspections on a monthly basis at all of its new and existing wells and related facilities and equipment within Erie’s Town Limits, provided that such related facilities and equipment are located on the pads for such wells, are part of adjacent tanks used for such pad sites, or are part of storage tanks for such pad sites authorized under Article IV, Section 4 of the Operator Agreement. Encana will also inspect each such well with an infra-red camera on a monthly basis. The initial baseline inspections will occur within sixty (60) calendar days after the Effective Date. After a well has produced for twelve (12) months, the frequency of such inspections shall decrease from monthly to quarterly. If Encana determines that any repairs are required based on these inspections, Encana will promptly initiate these repairs. (b) Encana will report to Erie on the inspection results and any associated repairs the month after the inspection or repair occurs. This information will be collectively reported on a monthly basis in the same format that Encana uses for reporting to the Air Pollution Control Division under Regulation 7, but that is specific to wells located within the Erie Town Limits. Erie will make this information publicly available. (c) This BMP will terminate five (5) years after the Effective Date, after which Encana will continue to comply with the leak detection, repair, and reporting requirements of Regulation 7, as such requirements may be amended.
Emissions mitigationForm: (02 )
400868376
11/5/2015		In an effort to reduce air emissions, Encana intends to construct a central gathering and storage facility at a location in 1N-68W-Section 21 (the “Hub”) to receive liquids from the wells which are the subject of this Agreement. As a result, Encana will not install hydrocarbon storage tanks at these pad sites, which will eliminate potential sources of hydrocarbons from the sites. However, Encana will still install at the pad sites all other equipment and facilities necessary for the production of hydrocarbons, including wellhead equipment, separation equipment, electrical equipment, and temporary flowback equipment (including temporary storage tanks). In addition, this BMP is subject to Article IV, Sections 3 and 4 of the Agreement.
Drilling/Completion OperationsForm: (02 )
400868376
11/5/2015		Utilize a high-low pressure vessel (HLP) and vapor recovery unit (VRU) for new wells drilled. Encana may remove the VRU system at such time Encana determines that the VRU system is no longer necessary due to reduced emission recoveries and/or efficiencies, but no earlier than one (1) year after the new well is drilled
Drilling/Completion OperationsForm: (02 )
400868376
11/5/2015		Utilize closed-loop systems for drilling and completion operations to minimize the need for earthen pits
Drilling/Completion OperationsForm: (02 )
400868376
11/5/2015		Upon initial rig-up and at least once every thirty (30) days during drilling operations thereafter, pressure testing of the casing string and each component of the blowout prevention equipment including flange connections will be performed to seventy percent (70%) of working pressure or seventy percent (70%) of the internal yield of casing, whichever is less. Pressure testing shall be conducted and the documented results will be retained by the operator for inspection by the Director for a period of one (1) year. Activation of the pipe rams for function testing shall be conducted on a daily basis when practicable.
Drilling/Completion OperationsForm: (02 )
400868376
11/5/2015		Adequate blowout prevention equipment will be used on all well servicing operations.
12