justicedao/ipfs_state_laws huggingface dataset:
632-010-0167 Maximum Efficient Rate Hearings A hearing to determine the maximum efficiency rate at which any pool in the state can produce oil and gas without waste may be held by the board on its own motion or at the request of any interested party. Statutory/Other Authority: ORS 520 Statutes/Other Implemented: ORS 520.095 History: DGMI 1-2013, f. & cert. ef 3-21-13 GMI 2-1995, f. & cert. ef. 3-10-95 GMI 6-1990, f. & cert. ef. 12-5-90 GMI 3-1980, f. 2-29-80, ef. 3-1-80
632-010-0168 Use of Earthen Reservoirs Oil may not be stored or retained in earthen reservoirs or in open receptacles. Statutory/Other Authority: ORS 520 Statutes/Other Implemented: ORS 520.095 History: DGMI 1-2013, f. & cert. ef 3-21-13 GMI 1, f. 1-27-54
632-010-0170 Reservoir Surveys The board, by order, may require the permittee of a well producing oil or gas to conduct periodic surveys of the reservoirs in the state that contain oil or gas or both. These surveys must be thorough and complete and conducted under the supervision of the department. Each survey must address the condition of the reservoirs containing oil or gas, or both, and the practices and methods employed by the permittee. Such investigation must include, but need not be limited to: the volume and source of crude oil and natural gas; the pressure of the reservoir as an average; the areas of regional or differential pressure; stabilized gas-oil ratios; and the producing characteristics of the field as a whole and of the individual wells within the field. Statutory/Other Authority: ORS 520 Statutes/Other Implemented: ORS 520.095 History: DGMI 1-2013, f. & cert. ef 3-21-13 GMI 2-1995, f. & cert. ef. 3-10-95 GMI 6-1990, f. & cert. ef. 12-5-90 GMI 1, f. 1-27-54
632-010-0172 Operators to Assist in Reservoir Surveys All permittees of oil or gas wells intercepting a reservoir are required to conduct a survey as required under OAR 632-010-0170 and to assist the representatives of the board and the department in making any and all tests, including bottom hole pressure and gas-oil ratio determinations, required by the board or department on any or all of such operators' wells. Statutory/Other Authority: ORS 520 Statutes/Other Implemented: ORS 520.095 History: DGMI 1-2013, f. & cert. ef 3-21-13 GMI 2-1995, f. & cert. ef. 3-10-95 GMI 6-1990, f. & cert. ef. 12-5-90 GMI 4-1985, f. & ef. 11-20-85 GMI 1, f. 1-27-54
632-010-0174 Measurement of Potential Open-Flow of Gas Wells The permittee must determine the potential open-flow of a gas well by U.S. Department of Energy back-pressure method unless the department approves in writing the use of an alternative method. Statutory/Other Authority: ORS 520 Statutes/Other Implemented: ORS 520.095 History: DGMI 1-2013, f. & cert. ef 3-21-13 GMI 6-1990, f. & cert. ef. 12-5-90 GMI 1, f. 1-27-54
632-010-0176 Supervision of Open-Flow and Pressure Tests All tests made in determining the potential flow and shut-in, well-head, or bottom hole pressure of a gas well must be conducted by the permittee and may be monitored by the department to ensure that: (1) Initial flow to the surface is accomplished during daylight hours; (2) Gas will be flared during tests when feasible; and (3) Proper safety precautions are taken to prevent fire or explosion during tests. Statutory/Other Authority: ORS 520 Statutes/Other Implemented: ORS 520.095 History: DGMI 1-2013, f. & cert. ef 3-21-13 GMI 2-1995, f. & cert. ef. 3-10-95 GMI 6-1990, f. & cert. ef. 12-5-90 GMI 4-1985, f. & ef. 11-20-85 GMI 1, f. 1-27-54
632-010-0178 Duration of Tests The permittee must test for open-flow and pressure of completed gas wells at such intervals and continue for such time as is necessary to effect accurate determination. The permittee must file a report of all tests with the department within 60 days of the completed test. Statutory/Other Authority: ORS 520 Statutes/Other Implemented: ORS 520.095 History: DGMI 1-2013, f. & cert. ef 3-21-13 GMI 6-1990, f. & cert. ef. 12-5-90 GMI 1-1979, f. & ef. 1-25-79 GMI 1, f. 1-27-54
632-010-0182 Gas to Be Metered (1) Meters: All gas sold must be metered with a meter of sufficient capacity, provided that gas may be metered from a lease or unitized property as a whole, if it is shown that a ratable taking can be maintained. Meters are not required for gas produced and used on the lease for development purposes and lease operations. (2) Meter Charts and Records: Purchasers must keep meter charts and gas purchase records for a period of at least two years and make the charts and records available to the department. (3) Bypasses: Bypasses are not to be connected around meters or points where custody of the fluid is transferred. Statutory/Other Authority: ORS 520 Statutes/Other Implemented: ORS 520.095 History: DGMI 1-2013, f. & cert. ef 3-21-13 GMI 2-1995, f. & cert. ef. 3-10-95 GMI 6-1990, f. & cert. ef. 12-5-90 GMI 4-1985, f. & ef. 11-20-85 GMI 1-1982, f. & ef. 6-25-82 GMI 1, f. 1-27-54
632-010-0184 Direct Well Pressure Where gas release to the atmosphere is involved, the use of direct well pressure to operate any machinery is prohibited. Statutory/Other Authority: ORS 520 Statutes/Other Implemented: ORS 520.095 History: DGMI 1-2013, f. & cert. ef 3-21-13 GMI 2-1995, f. & cert. ef. 3-10-95 GMI 6-1990, f. & cert. ef. 12-5-90 GMI 1, f. 1-27-54
632-010-0186 Gas-Oil Ratio No well is permitted to produce gas in excess of the maximum ratio determined for a pool unless all gas produced in excess is returned to the pool. Statutory/Other Authority: ORS 520 Statutes/Other Implemented: ORS 520.095 History: DGMI 1-2013, f. & cert. ef 3-21-13 GMI 1, f. 1-27-54
632-010-0188 Gas-Oil Ratio Surveys and Reports Gas-oil ratios and surveys must be taken in the manner prescribed by the board for individual fields where gas-oil ratio limits have been fixed and in accordance with the rules prescribed for each individual pool. (1) Flowing Wells Intermittently (Stop-Cocked) Produced: In computing the operating gas-oil ratio, the total volume of gas and the total barrels of oil that are produced in order to obtain the daily oil allowable must be used regardless of the flowing time in the 24-hour period. (2) Gas Lift or Jet Wells: The total volume of gas to be used in computing the operating gas-oil ratio is the total output volume minus the total input volume. (3) Pumping Wells: Gas withdrawn from the casing in an attempt to maintain a fluid seal, or for any other reason, must be added to the gas produced through tubing in computing the gas-oil ratio. Statutory/Other Authority: ORS 520 Statutes/Other Implemented: ORS 520.095 History: DGMI 1-2013, f. & cert. ef 3-21-13 GMI 6-1990, f. & cert. ef. 12-5-90 GMI 4-1985, f. & ef. 11-20-85 GMI 1-1982, f. & ef. 6-25-82 GMI 1, f. 1-27-54
632-010-0190 Gas Utilization (1) A permittee must not allow hydrocarbon gas to escape to the atmosphere except for short periods outside of normal drilling operations and testing or flowing wells during workovers or repairs when an escape has been preauthorized by the department. (2) Unless otherwise directed by the board, produced gas must be flared. Statutory/Other Authority: ORS 520 Statutes/Other Implemented: ORS 520.095 History: DGMI 1-2013, f. & cert. ef 3-21-13 GMI 2-1995, f. & cert. ef. 3-10-95 GMI 6-1990, f. & cert. ef. 12-5-90 GMI 1-1979, f. & ef. 1-25-79 GMI 1, f. 1-27-54
632-010-0192 Disposal of Brine or Salt Water In addition to the requirements of ORS 520.095(1), and in addition to applicable rules of the Oregon Department of Environmental Quality and the Oregon Water Resources Department, the following requirements apply to the disposal of brine or saltwater liquids: (1) Disposal in pits, sumps or above ground tanks: (a) Brine or saltwater may be disposed of by evaporation when impounded in excavated earthen pits, but only when the pits are lined with impervious material and a Water Pollution Control Facilities permit has been obtained from the Oregon Department of Environmental Quality; (b) Impounding brine or saltwater in porous earthen pits is prohibited. Earthen pits used for impounding brine or saltwater must be constructed and maintained to prevent the escape of fluid; (c) The department has the authority to prohibit the use of any pit that does not properly impound water and to order the proper disposal of water impounded in the pit; (d) The level of brine or saltwater in earthen pits may not rise above the lowest point of the ground surface level. All pits must have a continuous embankment surrounding them sufficient to prevent surface water from running into the pit. An embankment may not be used to impound brine or saltwater; and (e) Brine or saltwater impounded in earthen pits may not escape onto adjacent land or into waters of the state. (2) Disposal by Injection: Saltwater may also be disposed of by injection into the strata from which it was produced or into other proved saltwater-bearing strata pursuant to an Underground Injection Control permit issued by the Oregon Department of Environmental Quality. (3) Ocean discharge of saltwater may be permitted pursuant to a National Pollutant Discharge Elimination System permit issued by the Oregon Department of Environmental Quality. Statutory/Other Authority: ORS 520 Statutes/Other Implemented: ORS 520.095 History: DGMI 1-2013, f. & cert. ef 3-21-13 GMI 2-1995, f. & cert. ef. 3-10-95 GMI 6-1990, f. & cert. ef. 12-5-90 GMI 4-1985, f. & ef. 11-20-85 GMI 1-1982, f. & ef. 6-25-82 GMI 1-1979, f. & ef. 1-25-79 GMI 1, f. 1-27-54
632-010-0205 Drilling Surety Bond (1)(a) Every person who engages in the drilling, redrilling, or reworking of any well or disposal well must file and maintain with the department, on a form provided by the department a bond or alternative form of financial security in the sum of $25,000 for each well drilled, redrilled, deepened, or reworked to a depth less than 10,000 feet, or $50,000 for each well to a depth greater than 10,000 feet. The security must be filed with the department prior to the approval of an application to drill, redrill, deepen, or rework as required in OAR 632-010-0010. A security may be submitted individually for each well, or a blanket security may be filed as described in (b) below. (b) In multi-well operations, a blanket bond or alternative form of security in the minimum amount of $150,000 may be filed in lieu of individual bonds or securities. The blanket amount must be computed as the sum of the applicable individual bond or security amounts required for each well. The department may exclude the following wells from the blanket bond or security computation: (A) Any well that has a gross annual wellhead production in dollars during the past twelve months that is greater than the amount of the required individual well bond. It is the responsibility of the well permittee to file for exclusions annually prior to the permit anniversary date. (c) The bond or security must be executed by the permittee, as principal, and by a company authorized to do business as a surety insurer in the State of Oregon, as surety, and be conditioned upon the faithful compliance by the principal with the statutes, rules, and orders of the department and the board. (2) Any bond or security submitted as required by this section may, with the consent of the department, be terminated and cancelled and the surety relieved of all obligations thereunder. However, the department will not consent to termination and cancellation of any bond until the well or wells covered by such bond have been properly plugged and decommissioned including site reclamation, with the approval of the department, or another valid bond has been submitted and approved. Statutory/Other Authority: ORS 520 Statutes/Other Implemented: ORS 520.095 History: DGMI 1-2013, f. & cert. ef 3-21-13 DGMI 2-1999, f. & cert. ef. 8-30-99 GMI 3-1997, f. & cert. ef. 12-3-97 GMI 2-1995, f. & cert. ef. 3-10-95 GMI 6-1990, f. & cert. ef. 12-5-90 GMI 4-1985, f. & ef. 11-20-85 GMI 1-1979, f. & ef. 1-25-79
632-010-0210 Disposal of Solid and Liquid Wastes (1)(a) Permit stipulations by the Oregon Department of Environmental Quality regarding disposal of solid and liquid wastes generated by drilling, redrilling, deepening, or reworking operations are deemed to be a requirement of every permit issued under OAR 632-010-0010. (b) All wells used for disposal of solid and liquid wastes must be equipped with tubing and packers and be tested for mechanical integrity at least once every five years to determine that there are no leaks in the casing, tubing, or packers, and that there is no fluid movement into an underground source of water, other than that from which the fluid was produced, unless otherwise approved by the department. Acceptable tests include pressuring the tubing and casing annuli to demonstrate the integrity of the casing, tubing, and packers. Tracer surveys, noise logs, temperature logs, spinner surveys, or other methods approved by the department may be used to detect water movement adjacent to the wellbore. The department must be notified of all mechanical integrity tests, and the results submitted as required by OAR 632-010-0017. (2) Once field development is initiated, a separate permit is required from the Oregon Department of Environmental Quality for disposal of liquid and solid wastes. Statutory/Other Authority: ORS 520 Statutes/Other Implemented: ORS 520.095 History: DGMI 1-2013, f. & cert. ef 3-21-13 GMI 2-1995, f. & cert. ef. 3-10-95 GMI 4-1985, f. & ef. 11-20-85 GMI 1-1979, f. & ef. 1-25-79
632-010-0220 Measurement of Oil The volume of production of oil must be computed in terms of barrels of clean oil on the basis of properly calibrated meter measurements or tank measurement of oil level differences made and recorded to the nearest quarter inch, using 100 percent tank capacity tables, subject to the following corrections: (1) Correction for Impurities: The percentage of impurities (water, sand, and other foreign substances not constituting a natural component part of oil) must be determined to the satisfaction of the department, and the observed gross volume of oil must be corrected to exclude the entire volume of such impurities. (2) Temperature Correction: The observed volume of oil corrected for impurities must be further corrected to the standard volume at 15.55 degrees Centigrade (60 degrees Fahrenheit), in accordance with industry standards or any revisions thereof approved by the department. (3) Gravity Determination: The gravity of oil at 15.55 degrees Centigrade (60 degrees Fahrenheit) must be determined in accordance with A.S.T.M. standards or any revisions thereof and any supplements thereto or any close approximation thereof approved by the department. Statutory/Other Authority: ORS 520 Statutes/Other Implemented: ORS 520.095 History: DGMI 1-2013, f. & cert. ef 3-21-13 GMI 2-1995, f. & cert. ef. 3-10-95 GMI 6-1990, f. & cert. ef. 12-5-90 GMI 1-1979, f. & ef. 1-25-79
632-010-0225 Spacing Plan (1) For purposes of this section, the Mist Gas Field refers to the following area: (a) Sections 1 through 18, 20 through 29, 32 through 36 of T. 5 N., R. 4 W.; (b) Sections 1, 2, 11, 12, of T. 5 N., R. 5 W.; (c) Sections 3 through 10, 14 through 23, 25 through 36 of T. 6 N., R. 4 W.; (d) Sections 1 through 36 of T. 6 N., R. 5 W.; (e) Section 31 of T. 7 N., R. 4 W.; and (f) Sections 13 through 36 of T. 7 N., R. 5 W., W.M. (2) The minimum spacing for gas wells in the Mist Field is 160 acres when the top of the producing zone is less than 7,000 feet in vertical depth. (3) The minimum spacing for gas wells in the Mist Field is 640 acres when the top of the producing zone is 7,000 feet or more in vertical depth. (4) The spacing units are based upon the federal land grid of sections and quarter sections, or projected extensions of the grid if the affected lands are not surveyed. Statutory/Other Authority: ORS 520 Statutes/Other Implemented: ORS 520.095 History: DGMI 1-2013, f. & cert. ef 3-21-13 DGMI 2-1999, f. & cert. ef. 8-30-99 GMI 4-1985, f. & ef. 11-20-85 GMI 2-1983, f. & ef. 12-8-83 GMI 2-1980, f. 2-29-80, ef. 3-1-80
632-010-0230 Location of Wells The completion location of each permitted well to be drilled on any spacing unit is the location of the well at the top of the producing horizon. For gas wells, the completion location of the well may not be located nearer than 250 feet from the unit boundary and 500 feet from the nearest producing well from the same pool. Statutory/Other Authority: ORS 520 Statutes/Other Implemented: ORS 520.095 History: DGMI 1-2013, f. & cert. ef 3-21-13 GMI 4-1985, f. & ef. 11-20-85 GMI 2-1980, f. 2-29-80, ef. 3-1-80
632-010-0235 Exceptions The department may grant exceptions to OAR 632-010-0225 and 632-010-0230 after holding a hearing, based on the geology, productivity, topography, enhancement requirements, or environmental protection. Statutory/Other Authority: ORS 520 Statutes/Other Implemented: ORS 520.095 History: DGMI 1-2013, f. & cert. ef 3-21-13 GMI 2-1995, f. & cert. ef. 3-10-95 GMI 4-1985, f. & ef. 11-20-85 GMI 2-1980, f. 2-29-80, ef. 3-1-80
632-015-0005 Information and Seismic Test Holes These rules provide requirements for seismic and information hole operations, including financial security, groundwater protection, and surface reclamation. Statutory/Other Authority: ORS 520 Statutes/Other Implemented: ORS 520.095 History: DGMI 2-2013, f. & cert. ef 3-21-13 GMI 2-1990, f. 8-9-90, cert. ef. 8-31-90
632-015-0010 Definitions The definitions in ORS 520.005 apply to this rule division. In addition, the following definitions apply: (1) "Board" means the Governing Board of the State Department of Geology and Mineral Industries. (2) "Department” means the Oregon Department of Geology and Mineral Industries. (3) "Drilling Records” means an operational summary of any hole. (4) "Groundwater" means any water, except capillary moisture, beneath the land surface or beneath the bed of any stream, lake, reservoir or other body of surface water within Oregon, whatever may be the geological formation or structure in which such water stands, flows, percolates or otherwise moves. (5) "Information Hole" means a hole drilled for information purposes in conjunction with oil or gas exploration operations and includes, but is not limited to, stratigraphic test holes, core holes, or other test holes. (6) "Nonmetallic Plug" means a plugging device made of nonmetallic and noncorrosive material that can be placed in a hole to prevent excess settling at the surface. An example of a nonmetallic plug is a plastic plug which conforms to the diameter of the hole. (7) “Operator” means any person who is in charge of the development of a lease or the construction, development or operation of a seismic program or information hole operation subject to the division. (8) “Permittee" means any person who has the right to conduct a seismic program or information hole operation and has received a permit or is an operator. (9) "Seismic Explorer" means a person who conducts seismic research work by the means of drilling seismic shot holes for the placing or detonating of explosives. (10) "Seismic Shot Hole (Seismic Hole)" means a hole that will be used for seismic operation purposes only. (11) "Stratigraphic Test Hole" means an information hole that is less than 500 feet deep drilled for stratigraphic or geologic data or information only and not for production under any foreseeable conditions as determined by the department. (12) "Sump" means an earthen containment area or a tank or other container, lined with a low permeability liner, located at the drilling site for the storage of drilling fluids or other material as part of a drilling operation. Statutory/Other Authority: ORS 520 Statutes/Other Implemented: ORS 520.095 History: DGMI 2-2013, f. & cert. ef 3-21-13 GMI 2-1990, f. 8-9-90, cert. ef. 8-31-90
632-015-0020 Seismic Shot Hole Operations Seismic shot hole programs may not be conducted within 1/8 mile of any existing building, water well, flowing spring, stock water pipeline, sewer line, utility tunnel, or water or gas line, unless a written exception is granted by the department based on the applicant’s demonstration, to the department’s satisfaction, that the operation presents no significant danger to human health or the environment. Statutory/Other Authority: ORS 529 Statutes/Other Implemented: ORS 520.095 History: DGMI 2-2013, f. & cert. ef 3-21-13 GMI 2-1995, f. & cert. ef. 3-10-95 GMI 2-1990, f. 8-9-90, cert. ef. 8-31-90
632-015-0025 Financial Security Requirements (1) Before a permit may be issued for seismic programs or information hole operations, the applicant must submit a surety bond or other form of financial security acceptable to the department. The department will establish the amount of financial security based on estimated costs, but the amount may not be less than $50,000. A surety bond must be executed by the applicant, as principal, and by a surety company authorized to do business in the State of Oregon, as surety, and conditioned upon the faithful compliance by the principal with Oregon statutes, Oregon Administrative Rules, any applicable order of the board, and permit conditions. (2) Any security submitted as required by this section may, with the consent of the department, be terminated and cancelled and the surety relieved of all obligations thereunder. However, the department shall not consent to termination and cancellation of any security until the hole or holes covered by such security have been properly reclaimed, or another valid security has been submitted. (3) Following completion of operations, the permittee may request that the department release the bond or other form of security. A bond or security may not be released until the department has determined that the permittee has complied with Oregon statutes, Oregon Administrative Rules, any applicable order of the board, and permit conditions. Statutory/Other Authority: ORS 516.090 & 520.095 Statutes/Other Implemented: ORS 520.027 & 520.095 History: DGMI 2-2013, f. & cert. ef 3-21-13 GMI 2-1995, f. & cert. ef. 3-10-95 GMI 2-1990, f. 8-9-90, cert. ef. 8-31-90
632-015-0030 Compliance with Law The permittee for a seismic program or information hole operation is responsible for conducting all operations in compliance with Oregon statutes, Oregon Administrative Rules, any applicable order of the board or department, and permit conditions, and is subject to the penalties provided by Oregon statutes and these rules for failure to comply. Statutory/Other Authority: ORS 516.090 & 520.095 Statutes/Other Implemented: ORS 520.027 & 520.095 History: DGMI 2-2013, f. & cert. ef 3-21-13 GMI 2-1990, f. 8-9-90, cert. ef. 8-31-90
632-015-0035 Notices The permittee must give the department a minimum of 24 hours advance notice of plugging operations. For seismic shot hole plugging operations that are not a continuation of the initial drilling of the shot hole or part of the plugging procedures immediately following seismic program operations, the permittee must give the department a minimum of 24 hours advance notice of the plugging operations. Statutory/Other Authority: ORS 516.090 & 520.095 Statutes/Other Implemented: ORS 520.027 & 520.095 History: DGMI 2-2013, f. & cert. ef 3-21-13 GMI 2-1995, f. & cert. ef. 3-10-95 GMI 2-1990, f. 8-9-90, cert. ef. 8-31-90
632-015-0045 Conversion to Water Well Permittee may convert the shot or information hole to a water well upon approval from the Oregon Department of Water Resources. The department may not release the permittee from complying with the requirements of ORS 520.005 to 520.991 until such conversion is accomplished. Statutory/Other Authority: ORS 516.090 & 520.095 Statutes/Other Implemented: ORS 520.027 & 520.095 History: DGMI 2-2013, f. & cert. ef 3-21-13 GMI 2-1990, f. 8-9-90, cert. ef. 8-31-90