| Engineer | Form: (02 )
400263680
4/12/2012 | 1) Note surface casing setting depth change from 2010’ to 2060’. Increase cement coverage accordingly.
2) Submit Form 42 electronically to COGCC 48 hours prior to MIRU.
3) Comply with Rule 317.i and provide cement coverage from end of 7” casing to a minimum of 200' above Niobrara. Verify coverage with cement bond log.
4) 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.
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| Permit | Form: (04 )
400530608
1/14/2014 | 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 Form 5 for every well on the pad shall identify which well was logged. |
| Engineer | Form: (04 )
401493545
1/31/2020 | This approval is good for one year and a new application must be made before Jan 31, 2020. Updates for the planned utilization of the well should be included with the application.
The Form 7 reporting must reflect the well status dates reported on the Form 4-TA request.
A Form 5A is required to report all plugs currently downhole which isolate the perforated interval.
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| OGLA | Form: (06 )
403880793
8/19/2024 | Due to proximity to surface water, Operator will review the stormwater program and implement stormwater BMPs and erosion control measures as needed to prevent fine-grained sediment and impacted stormwater runoff from entering surface water. |
| Engineer | Form: (06 )
403880793
9/10/2024 | 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) Pump surface casing shoe plug at 2100' 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 1946' or shallower and provide a minimum of 10 sx plug at the surface.
3) Plug at 1206'. If cement is not circulated to surface, shut-in, WOC 4 hours then tag plug – must be at 707' 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 cut 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 )
403880793
9/10/2024 | 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 )
403880793
9/10/2024 | 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. |
|
| Drilling/Completion Operations | Form: (02 )
400263680
8/3/2012 | 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. |
| Drilling/Completion Operations | Form: (02 )
400263680
8/3/2012 | 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 operated by the operator within 300 feet of the well to be fracture stimulated.
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.
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: (04 )
400530608
1/26/2014 | MEMORANDUM OF UNDERSTANDING
This Memorandum of Understanding (“MOU”) is made and entered into this _____ day of ______, 2013, by and between Arapahoe County, a Colorado County (“County”) with an address of 5334 S. Prince St., Littleton, Colorado 80120 and (“Operator”), with an address of . The Operator and the County may be referred to individually as a “Party” or collectively as the “Parties.”
BACKGROUND
A. Operator is the owner or lessee of oil and gas leasehold and/or mineral interests within unincorporated parts of the County, and, as of the time of the execution of this MOU, has the right and intent to further develop its oil and gas leasehold and/or mineral interests within said portion of the County.
B. The intent of this MOU is to provide the conditions under which Operator will develop and operate future oil and gas facilities or newly expanded facilities in the unincorporated portions of the County, in order to foster the efficient and economic production of oil and gas resources, to protect human health, safety and welfare and to protect the environment and wildlife resources, while at the same time providing for a predictable and expeditious administrative process for obtaining County land use approvals and permits for oil and gas facilities. The terms “facility” or “facilities” are defined here as including oil and gas wellsites, flowlines, tank batteries, compressor stations, pits/ponds, below-grade tanks, dehydration units, vapor recovery units (VRUs), and associated roads. Pipelines and gathering systems, other than flowlines, as well as salt water disposal wells and injection wells are excluded. Locations with more than one of the above mentioned types of equipment will also be considered to be one facility. Unless indicated otherwise, the definitions of terms used in the MOU shall be the same as in the Colorado Oil and Gas Conservation Commission’s ("Commission") Rules.
NOW, THEREFORE, the Parties agree as follows:
1. Intent to Supplement Commission Rules and Regulations. The Parties recognize that pursuant to the Colorado Oil and Gas Conservation Act, C.R.S. §§ 34-60-101, et seq. ( “Act”), the Commission regulates the development and production of oil and gas resources in Colorado, and the Act authorizes the Commission to adopt statewide rules and regulations. The provisions of this MOU are intended to supplement and add to the Commission’s rules and regulations. To the extent that any of the provisions of this MOU are in conflict with the Act or COGCC rules and regulations, the stricter standards shall govern.
2. Operator’s Pit Practices within the County. The Operator will comply, at a minimum, with the following pit practices, after the date of this MOU:
a. Preferred Option: It is the intent of the County that operators utilize closed-loop or modified closed-loop systems for drilling and completion operations in order to minimize or eliminate the need for earthen pits; however, notwithstanding the foregoing, where appropriate, and subject to prior County approval, the County generally supports: 1) the use of unlined drilling pits when bentonite or a similar clay additive is used during the drilling process, and 2) the use of lined single- or multi-well water storage pits in order to minimize the transport of water and promote recycling, subject to the requirements set forth in this subsection. Permitted modified closed-loop systems include oil and gas wells where air or fresh water is used to drill through the surface casing interval, defined as fifty (50) feet below the depth of the deepest aquifer, and a closed loop system is used for the remainder of the drilling and/or completion or recompletion procedures. Multi-well pits are defined as lined, engineered pits, constructed over an engineered base, with construction or liner specifications meeting or exceeding Commission pit lining rules, that will serve the functions of drilling, completion, and/or flowback pits for more than one well.
b. Water Storage Pits to Contain Fresh Water or Brine Water: Water stored in pits approved by the County and allowed under Commission Rules, must meet the definition of fresh water or brine water, except for water stored in pits listed in 2c below. Fresh water is defined as containing total dissolved solids (TDS) less than or equal to 5,000 milligrams/liter (mg/l). Brine water is defined as water produced from an oil and/or gas well with TDS of greater than 5,000 mg/l. The Operator is required to remove all free and visible oil within 24 hours of discovery. Upon closure of the pit, the Operator will ensure the protection of the public health and environment by following all Commission pit closure rules, including collecting analytical data to ensure compliance with state standards. As long as the pit is open and containing fluid, a representative water sample shall be taken every six months from the surface of the pit fluids, the first sample to be taken within 6 months of the pit becoming operational. Water quality data will also include an analysis of Sodium Adsorption Ratio (SAR). The County will review water quality data provided by the Operator every six (6) months. TDS, pH, and specific conductance can be measured with a field meter. TEPH (total extractable petroleum hydrocarbons), BTEX (Benzene, Toluene, Ethylbenzene, and Xylenes), and SAR will be analyzed by an accredited laboratory. If the presence of TEPH and/or BTEX is indicated after County review and/or inspection, other water quality analyses may be required by the County.
c. Additional Pits that Require County Review and Approval: Skimming, settling, percolation, evaporation, and any type of netted pits are generally discouraged by the County; however such pits may be approved on a case-by-case basis through the Use by Special Review ("USR") process. A copy of the Pit Plan submitted to the Commission will be provided to the County at the same time as the plans are submitted to the Commission. Construction of these pits will be preceded by collection of “baseline” soil samples from the center of the planned pit at 6 and 18 inches depth. Soil samples will be analyzed for pH, Sodium Adsorption Ratio (SAR), and Electrical Conductivity (EC). The Operator shall stake and photograph from the center of the planned pit (toward north, south, east, and west directions) for inclusion in the County’s copy of the Pit Plan. Upon closure of these pits, pH, SAR, EC, BTEX (Benzene, Toluene, Ethylbenzene, and Xylenes), and TEPH (total extractable petroleum hydrocarbons) analyses may be required if there is evidence of leaks or spills in the immediate area of the pits.
d. Pits That Do Not Require County Approval: Flare, Emergency, Plugging, and Workover pits will not require county review or approval prior to construction (unless within 1/4 mile of a residence as set forth below); however, the County will be copied on the notification(s) sent to the Commission and any pit plans, remediation plans, or analytical results submitted to the Commission.
e. Pit Setbacks: All pit construction within ¼ mile of a residence
or water well is generally discouraged by the County and may have additional County requirements, such as fencing. Such pits will be reviewed on a case-by-case basis by the County.
f. Multi-Well Pits: In additi |
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