Okla. Admin. Code § 165:10-29-1

Current through Vol. 42, No. 4, November 1, 2024

Section 165:10-29-1 - Lake Atoka and McGee Creek Reservoir

(a)Scope. The requirements of this section will apply to wells located in the areas listed below, and will supersede all field orders related to these areas. These requirements are in addition to the Commission's existing statewide requirements. The areas controlled by this section include:

(1)IN ATOKA COUNTY

(A) Sections 1-35 of Township 1 North, Range 12 East;

(B) Sections 1-18, 21-28 and 35-36 of Township 1 North, Range 13 East;

(C) Sections 1-36 of Township 1 North, Range 14 East;

(D) Section 6 of Township 1 North, Range 15 East;

(E) Sections 1-5, 8-16, 20-29 and 32-36 of Township 2 North, Range 12 East;

(F) Sections 1-36 of Township 2 North, Range 13 East;

(G) Sections 4-9 of Township 2 North, Range 14 East;

(H) Sections 1-2, 11-14, 23-26 and 36 of Township 1 South, Range 11 East;

(I) Sections 2-10, 16-20, 24-25 and 30-31 of Township 1 South, Range 12 East;

(J) Sections 1-3, 9-16, 19-30 and 32-36 of Township 1 South, range 13 East;

(K) Sections 1-11 and 13-36 of Township 1 South, Range 14 East;

(L) Sections 1-5, 8-17, 22-27 and 34-36 of Township 2 South, Range 13 East;

(M) Sections 1-24 and 26-35 of Township 2 South, Range 14 East;

(N) Sections 1-2 and 12 of Township 3 South, Range 13 East;

(O) Sections 2-9 of Township 3 South, Range 14 East.

(2)IN PITTSBURG COUNTY

(A) Sections 7, 18-22 and 25-36 of Township 2 North, Range 14 East;

(B) Section 31 of Township 2 North, Range 15 East;

(C) Sections 1-3, 9-16, 20-29 and 32-36 of Township 3 North, Range 12 East;

(D) Sections 1-36 of Township 3 North, Range 13 East;

(E) Sections 6 and 28-33 of Township 3 North, Range 14 East;

(F) Sections 26-28 and 32-36 of Township 4 North, Range 13 East.

(3)IN COAL COUNTY Sections 12-14, 22-27 and 34-36 of Township 1 North, Range 11 East.

(b)General. The design criteria for all wells shall consider all pertinent factors for well control including formation pressures and casing setting depths such that the wellbore can be maintained under control at all times and that all surface and subsurface fresh water supplies or formations are protected.

(c)Well site limitations. No oil and/or gas well shall be located within 1,320 feet of the maximum water surface level contour line of either reservoir. The maximum water surface level is 609.8 feet above sea level for McGee Creek and 590 feet above sea level for Lake Atoka Reservoir.

(d)Drill site containment. During the drilling and completion of an oil and gas well the operator shall:

(1) Maintain an earthen retaining wall downslope of the well, no closer than 50 feet from the wellbore, if the well is located within six (6) miles of the maximum water surface level contour line of either reservoir. The maximum water surface level is 609.8 feet above sea level for McGee Creek Reservoir and 590 feet above sea level for Lake Atoka. The retaining wall shall be constructed prior to the commencement of drilling and shall be of adequate size for the terrain involved with a minimum length of 330 feet and a minimum compacted height of two (2) feet;

(2) Maintain a diversion ditch upslope of the well. The diversion ditch shall be constructed prior to the commencement of drilling and shall be adequate to divert surface drainage water from the well location;

(3) Pump any fluid, other than storm water, trapped within the well site into steel tanks for storage and removal. Storm water may be discharged as necessary as long as there is no sheen or other visible evidence of hydrocarbons being present, the chloride concentration does not exceed 500 mg/l, and the operator maintains records of each discharge for a period of three (3) years. These records must be supplied to the Commission upon request.

(e)Production site containment.

(1) During production operations, all fluid separation and storage vessels shall be enclosed within earthen or equivalent retaining walls so that the enclosed area has a storage capacity of at least one and one-half (1.5) times the liquid capacity of the largest vessel in the storage area.

(2) Any fluid other than storm water and any storm water that cannot be discharged will be pumped into steel tanks for storage and removal. Storm water may be discharged as necessary as long as there is no sheen or other visible evidence of hydrocarbons being present, the chloride concentration does not exceed 500 mg/l, and the operator maintains records of each discharge for a period of three (3) years. These records must be supplied to the Commission upon request.

(f)Erosion control. During the drilling phase of operations, silt fencing or other suitable materials or practices shall be used on the downslope side of the drill site to control runoff from the location. The silt fencing or other suitable materials or practices used to control runoff at the location shall be maintained in a manner so as to consistently work to control run-off.

(g)Circulating and reserve pits.

(1) Steel tanks shall be used for circulating and reserve pits for all drilling operations located within one (1) mile of the maximum water surface level contour line of either reservoir. The maximum water surface level is 609.8 feet above sea level for McGee Creek Reservoir and 590 feet above sea level for Lake Atoka.

(2) Outside of the areas designated by OAC 165:10-29-1(g)(1), any pit shall be lined with a geomembrane liner that meets or exceeds each of the following specifications:

(A) be made of linear low density polyethylene;

(B) have a thickness of 20 millimeters; and

(C) conform to the test requirements prescribed in the Geosynthetic Research Institute (GRI) Test Method GM17; and

(D) The liner shall also comply with the requirements for geomembrane liners found in OAC 165:10-7-16(c)(7).

(3) No pit shall be constructed or maintained so as to receive outside runoff water and the fluid level of earthen pits shall be maintained at all times as least 24 vertical inches below the lowest point of embankment.

(4) If there is flowback during the fracing of a well, the flowback must be to steel tanks prior to being placed into a lined pit if the temperature of the flowback exceeds 150 degrees Fahrenheit.

(5) The Oklahoma Corporation Commission shall inspect all pits within the purview of these rules prior to the liner being installed. The operator shall notify the District Office at least one (1) business day prior to installation of the liner. If the Commission has not inspected the pit within one (1) business day following the notification, the operator may proceed to install the liner.

(6) Any reserve/circulation pit shall be closed within six (6) months after drilling operations cease. Upon request by the operator, a six (6) month extension shall be granted by the District Office, after review by a field inspector to confirm the pit is in compliance with Commission requirements.

(h)Air drilling. When drilling with air for circulation, an unlined earthen pit to contain the wellbore cuttings is allowed, provided the chloride concentration of any fluids discharged into the pit does not exceed 1000 mg/l. Discharge of air and cuttings from the "blooey line" shall be subjected to fresh water injection or spray to eliminate, to the greatest extent possible, the drift of dust and particulates from the well site. Water and additives for liquid drilling fluid shall be maintained at the well site at all times in sufficient volumes to circulate the wellbore if needed. All water in the unlined earthen pit shall be removed and properly disposed of as soon as air drilling ceases.

(i)Casing. All casing shall be new or reconditioned and tested to conform to API specifications.

(1)Surface casing. Surface casing shall be set to a minimum depth of 700 feet, or 50 feet below the deepest treatable water, whichever depth is greater. In setting the surface casing, a minimum of six (6) centralizers shall be used in the bottom portion of the casing string.

(2)Production casing. Production casing of four and one-half (4.5) inches or greater OD, and all related equipment items, such as the wellhead valves, shall have a pressure rating sufficiently in excess of the highest formation pressure encountered in the well. In setting the production casing, the annular space between the wellbore and the production casing shall be filled with cement calculated to fill at least 500 feet above the shallowest planned zone to be tested. Centralizers shall be used across the planned zone(s) to be tested. The production casing shall be pressure tested to conform to OAC 165:10-3-4(h). In the event the total depth of the well is less than 500 feet, the annular space between the wellbore and the production casing shall be filled with cement calculated to fill at least that portion of the wellbore to the base of the surface casing. Centralizers shall be used across the planned zone to be tested. The production casing shall be pressure tested to comply with OAC 165:10-3-4(h).

(j)Blowout prevention equipment. Before drilling below the surface casing and until drilling operations are completed, a blowout preventer (BOP) with a minimum of two (2) hydraulically operated rams, one (1) blind type and one (1) pipe type to fit the drill pipe, and related well control equipment, including a manifold and a floor valve, with a working pressure that exceeds the maximum anticipated surface pressure, shall be installed, used and tested in a manner to prevent blowouts. The BOP stack shall include a drilling spool with side outlets if side outlets are not provided on the BOP body. BOPs shall be tested to the rated pressure of the blowout stack assembly. All blowout prevention equipment is to be tested prior to drilling out from the surface casing. While drilling operations are in progress, the BOP shall be actuated once each trip. When removing drill pipe from any hole that utilized drilling fluids, the annulus shall be filled with mud before the mud level drops 100 feet from surface. A Kelley-cock shall be installed below the swivel. Wells being drilled to a depth less than 4,000 feet may use annular type blowout preventers.

(k)Drill stem testing. Drill stem testing shall only be allowed during daylight hours. Fluid removed from the well during testing must be flowed or pumped into steel pits or tanks and promptly removed from the location at the conclusion of testing. The formation fluids in the hole shall be reversed-out prior to the removing of the drill stem test tool from the hole.

(l)Prevention of leakage and pollution. Equipment, pipe, pumps, tanks, and other appurtenances used in conducting operations shall be maintained at all times to prevent leakage and the escape of saltwater, oil and other deleterious substances. All oil, water and deleterious substances from wet strings of tubing shall be drained into steel tanks. All cellars with oil and oil sumps shall be promptly pumped out.

(m)Exceptions to this section. When good cause is shown, and when it is not reasonably likely to result in any pollution to either reservoir, an administrative exception to a requirement of this section may be granted by the Oklahoma Corporation Commission. Notice of an application for an exception to this section shall be sent at least 15 days in advance to:

(1) the manager of the District 4 Office of the Oil and Gas Conservation Division of the Oklahoma Corporation Commission;

(2) the General Manager of the Oklahoma City Water Utilities Trust, 420 W. Main, Suite 500, Oklahoma City, Oklahoma 73102; and

(3) the General Manager of the McGee Creek Authority, 420 W. Main, Suite 500, Oklahoma City, Oklahoma 73102. A 15-day period from the date of the written notice should be established for any party to file an objection to such an administrative application. If an objection is filed, a full hearing shall be held on the merits.

(n)Other. In reviewing an application for a permit-to-drill (form 1000), the Technical Services Department of the Oklahoma Corporation Commission will determine whether or not the well lies within any of the areas designated in OAC 165:10-29-1(c), OAC 165:10-29-1(d)(1) and OAC 165:10-29-1(g)(1).

Okla. Admin. Code § 165:10-29-1

Added at 25 Ok Reg 2187, eff 7-11-08

Amended by Oklahoma Register, Volume 32, Issue 23, August 17, 2015, eff. 8/27/2015.

Amended by Oklahoma Register, Volume 39, Issue 24, September 1, 2022, eff. 10/1/2022