| Drilling/Completion Operations | Form: (02 )
400288419
6/22/2012 | It was agreed in a consultation with Anadarko personnel on June 13, 2012 that precautions shall be taken during drilling and/or stimulation to decrease the risk of communicating with the William Katchen et al #1 (API# 123-05100), a dry and abandoned well. The referenced well lacks isolation of the Fox Hills Aquifer and Sussex, Niobrara and Codell Formations. To reduce the risk of impacting any un-isolated zones, no segments of the wellbore within 300’ of the referenced well shall be stimulated. At the Operator’s discretion, a portion of or the entire 300’ setback may be created during the drilling of the proposed wellbore. If this option is selected, a revised directional drilling plan must be submitted via Sundry Form 4 prior to drilling to ensure the wellbore is still within the lease. Also at least ten (10) days prior to stimulation, the Operator shall provide a Form 4 and Form 5 for COGCC approval. The Form 4 shall detail the stimulation plan and any segment of the borehole to be eliminated from stimulation due to the setback referenced above. The Form 5 shall contain an uploaded directional template to confirm either the setback distances were created during drilling or any segment of wellbore that may not be stimulated. This Sundry notice shall be submitted via email to the appropriate engineer. Should the Operator decide to re-enter and properly plug and abandon the referenced well prior to the stimulation of the proposed well, these required setbacks could be eliminated by COGCC staff. |
| Drilling/Completion Operations | Form: (02 )
400288419
6/22/2012 | 1. At least seven (7) days prior to fracture stimulation, the operator is to notify all operators of non-operated wells within 300 feet of the wellbore to be fracture stimulated of the anticipated date stimulation date and the recommended best management practice to shut-in all wells within 300’ of the stimulated wellbore completed in the same formation.
2. The operator will monitor the bradenhead pressure of all wells operator has identified within 300 feet of the well to be fracture stimulated. All wells within 300 feet are operated by Kerr-McGee Oil & Gas Onshore LP.
3. Bradenhead pressure gauges are to be installed 24 hours prior to stimulation. The gauges are to read at least once during every 24-hour period until 24-hours after stimulation is completed (post flowback). The gauges are to be of the type able to read current pressure and record the maximum encountered pressure in a 24-hour period. The gauge is to be reset between each 24-hour period. The pressures are to be recorded and saved. Alternate electronic measurement may be used to record the prescribed pressures. Data shall be kept for a period of one year.
4. If at any time during stimulation or the 24-hour post-stimulation period, the bradenhead annulus pressure of the treatment well or offset wells increases more than 200 psig, as per Rule 341, the operator of the well being stimulated shall verbally notify the Director as soon as practicable, but no later than twenty-four (24) hours following the incident. Within fifteen (15) days after the occurrence, the operator shall submit a Sundry Notice, Form 4, giving all details, including corrective actions taken.
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| Drilling/Completion Operations | Form: (02 )
400288419
6/22/2012 | “Prior to drilling operations, Operator may perform an anti-collision review of existing offset wells that have the potential of being within close proximity of the proposed well. This anti-collision review may include MWD or gyro surveys and surface locations of the offset wells with included error of uncertainty per survey instrument, and compared against the proposed wellpath 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 may only be drilled if the anti-collision review results indicate that the risk of collision is sufficiently low as defined by the anti-collision plan, with separation factors greater than 1.5, or if the risk of collision has been mitigated through other means including shutting in wells, plugging wells, increased drilling fluid in the event of lost returns or as is appropriate for the specific situation. In the event of an increased risk of collision, that risk will be mitigated to prevent harm to people, the environment or property. For the proposed well, upon conclusion of drilling operations, an as-constructed directional survey will be submitted to COGCC with the Form 5.”
At the time of permitting; the operator has identified the following well(s) as being within close proximity of the proposed well:
CANNON 15N-W3HZ:
- CANNON 24-3
- CANNON 37-3 |