reglab/statecodes huggingface dataset:
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.20 - Notification of Fire Breaks, Leaks, or Blow-Outs

Current through Reg. 49, No. 28; July 12, 2024
(a) General requirements.
(1) Operators shall give immediate notice of
				a fire, leak, spill, or break to the appropriate commission district office by
				telephone or telegraph. Such notice shall be followed by a letter giving the
				full description of the event, and it shall include the volume of crude oil,
				gas, geothermal resources, other well liquids, or associated products
				lost.
(2) All operators of any oil
				wells, gas wells, geothermal wells, pipelines receiving tanks, storage tanks,
				or receiving and storage receptacles into which crude oil, gas, or geothermal
				resources are produced, received, stored, or through which oil, gas, or
				geothermal resources are piped or transported, shall immediately notify the
				commission by letter, giving full details concerning all fires which occur at
				oil wells, gas wells, geothermal wells, tanks, or receptacles owned, operated,
				or controlled by them or on their property, and all such persons shall
				immediately report all tanks or receptacles struck by lightning and any other
				fire which destroys crude oil, natural gas, or geothermal resources, or any of
				them, and shall immediately report by letter any breaks or leaks in or from
				tanks or other receptacles and pipelines from which oil, gas, or geothermal
				resources are escaping or have escaped. In all such reports of fires, breaks,
				leaks, or escapes, or other accidents of this nature, the location of the well,
				tank, receptacle, or line break shall be given by county, survey, and property,
				so that the exact location thereof can be readily located on the ground. Such
				report shall likewise specify what steps have been taken or are in progress to
				remedy the situation reported and shall detail the quantity (estimated, if no
				accurate measurement can be obtained, in which case the report shall show that
				the same is an estimate) of oil, gas, or geothermal resources, lost, destroyed,
				or permitted to escape. In case any tank or receptacle is permitted to run
				over, the escape thus occurring shall be reported as in the case of a leak.
				(Reference Order Number 20-60,399, effective 9-24-70.)
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.22 - Protection of Birds

Current through Reg. 49, No. 28; July 12, 2024
(a) If an operator
				who maintains a tank or pit does not take protective measures necessary to
				prevent harm to birds, the operator may incur liability under federal and state
				wildlife protection laws. Federal statutes, such as the Migratory Bird Treaty
				Act, provide substantial penalties for the death of certain species of birds
				due to contact with oil in a tank or pit. These penalties may include
				imprisonment. State statutes also protect certain species of birds. The
				Railroad Commission of Texas (commission) is cooperating with federal and state
				wildlife authorities in their efforts to protect birds.
(b) An operator must screen, net, cover, or
				otherwise render harmless to birds the following categories of open-top tanks
				and pits associated with the exploration, development, and production of oil
				and gas, including transportation of oil and gas by pipeline:
(1) open-top storage tanks that are eight
				feet or greater in diameter and contain a continuous or frequent surface film
				or accumulation of oil; however, temporary, portable storage tanks that are
				used to hold fluids during drilling operations, workovers, or well tests are
				exempt;
(2) skimming pits as
				defined in §
										RSA
				3.8 of this title (relating to Water
				Protection) (Statewide Rule 8); and
(3) collecting pits as defined in §
										RSA
				3.8 of this title (relating to Water
				Protection) that are used as skimming pits.
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.23 - Vacuum Pumps

Current through Reg. 49, No. 28; July 12, 2024
The installation of a vacuum pump or other device for the
				  purpose of putting vacuum on any gas or oil-bearing formation, or the
				  application of any vacuum to any gas or oil-bearing formation is prohibited,
				  except as follows.
(1) If casinghead
				gas is utilized in a casinghead-gas plant, vacuum may be used, but no more than
				is sufficient to gather the gas and deliver it at the plant. In no event shall
				more than two points of vacuum (two inches of mercury) be used at the
				casinghead.
(2) In a field which is
				depleted or practically depleted vacuum may be used, but no vacuum pump shall
				be installed or used without a permit from the commission obtained upon
				application after notice to adjacent lease owners and operators and a public
				hearing on such application.
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.24 - Check Valves Required

Current through Reg. 49, No. 28; July 12, 2024
(a) Where two
				or more wells are being produced through a common line, a common separator, or
				a common manifold, the flow lines leading from each well to such common line,
				common separator, or common manifold shall be equipped with a check valve or
				other means of shut-off which shall at all times be kept in good working order.
				The check valve or other means of shut-off shall be placed in each flow line
				above the surface of the ground and shall be located in the flow line as close
				to the wellhead connection as is practicable. Where a manifold system is
				employed in which each well produced through the manifold system has its own
				individual flow line leading from the wellhead to the manifold, then it shall
				be permissible for the check valve or other means of shut-off to be placed in
				the flow line near a point where the flow line enters the manifold system. The
				check valve or other means of shut-off must be above ground, and must be in the
				flow line serving the well and must be located between the wellhead and the
				point where the flow line connects with any other flow line, common separator,
				or common manifold. Each check valve or other means of shut-off shall be placed
				in the flow line serving the well so that it will permit the passage of fluids
				from the well and will act as a check to prevent any fluid from entering the
				well through the flow line from any outside source.
(b) Operator shall do all things necessary to
				keep the check valve or other means of shut-off in good working order, and
				operators, when requested by an agent of the commission, will test the check
				valve or other means of shut-off for leakage.
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.25 - Use of Common Storage

Current through Reg. 49, No. 28; July 12, 2024
(a)
				Where oil and/or other liquid hydrocarbons are produced from two or more
				separate reservoirs or zones and separate proration schedules are published by
				the Commission for each reservoir or zone, the use of common storage is
				authorized as long as the requirements of §
									RSA
				3.26 and §
									RSA
				3.27 of this title (relating to Separating
				Devices, Tanks, and Surface Commingling of Oil, and Gas to be Measured and
				Surface Commingling of Gas, respectively) are met. An operator utilizing common
				storage pursuant to this section shall not be required to file a separate Form
				P-4, Certificate of Compliance and Transportation Authority, for each reservoir
				or zone, but may file one form to authorize the transportation of oil or gas
				from all reservoirs or zones producing into common storage.
(b) A gatherer transporting oil from such
				common storage shall not be required to file a separate transporter's report
				for each separate reservoir or zone or each separate lease but shall file such
				report on a combined basis for the total amount of commingled oil in common
				storage.
(c) The operator of a
				lease or leases for which the Commission has authorized the use of common
				storage of oil produced from two or more reservoirs or zones and from two or
				more leases shall file Form PR, Monthly Production Report, for each separate
				reservoir or zone and/or for each separate lease and, in addition thereto, said
				operator shall file a report showing the data included on the individual
				reports on a combined basis for the total amount of commingled oil in common
				storage.
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.26 - Separating Devices, Tanks, and Surface Commingling of Oil

Current through Reg. 49, No. 28; July 12, 2024
(a) Where oil and
				gas are found in the same stratum and it is impossible to separate one from the
				other, or when a well has been classified as a gas well and such gas well is
				not connected to a cycling plant and such well is being produced on a lease and
				the gas is utilized under Texas Natural Resources Code §§
									RSA
				86.181 -
				RSA
				86.185, the operator shall install a
				separating device of approved type and sufficient capacity to separate the oil
				and liquid hydrocarbons from the gas.
(1) A
				separating device shall be kept in place as long as a necessity for it exists,
				and its use shall not be discontinued without the consent of the
				Commission.
(2) All oil and any
				other liquid hydrocarbons as and when produced shall be adequately measured
				pursuant to paragraphs (3) and (4) of this subsection before the same leaves
				the lease from which they are produced, except for gas wells where the full
				well stream is moved to a plant or central separation facility in accordance
				with §
										RSA
				3.55 of this title (relating to Reports on
				Gas Wells Commingling Liquid Hydrocarbons before Metering) (Statewide Rule 55)
				and the full well stream is measured, with each completion being separately
				measured, before the gas leaves the lease. If an operator commingles production
				pursuant to subsection (b) of this section, the operator shall comply with
				paragraphs (3) and (4) of this subsection but the operator is not required to
				measure the production stream before it leaves the lease.
(3) Sufficient tankage and separator capacity
				shall be provided by the producer to adequately take daily gauges of all oil
				and any other liquid hydrocarbons unless LACT equipment, installed and operated
				in accordance with the latest revision of American Petroleum Institute (API)
				Manual of Petroleum Measurement Standards, Chapter 6.1 or another method
				approved by the Commission or its delegate, is being used to effect custody
				transfer.
(4) For Commission
				purposes, the measurement requirements of this section are satisfied by the use
				of coriolis or turbine meters or any other measurement device or technology
				that conforms to standards established, as of the time of installation, by the
				American Petroleum Institute (API) or the American Gas Association (AGA) for
				measuring oil or gas, as applicable, or approved by the Director of the Oil and
				Gas Division as an accurate measurement technology.
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.28 - Potential and Deliverability of Gas Wells to be Ascertained and Reported

Current through Reg. 49, No. 28; July 12, 2024
(a) The information
				necessary to determine the absolute daily open flow potential of each producing
				associated or nonassociated gas well shall be ascertained, and a report shall
				be filed as required with the Commission within 90 days of completion of the
				well. The test shall be performed in accordance with the Commission's
				publication, Back Pressure Test for Natural Gas Wells, State of Texas, or other
				test procedure approved in advance by the Commission and shall be reported on
				the Commission's prescribed form. An operator may determine absolute open flow
				potential from a stabilized one-point test. For a one-point test, the well
				shall be flowed on a single choke setting until a stabilized flow is achieved,
				but not less than 72 hours. The shut-in and flowing bottom hole pressures shall
				be calculated in the manner prescribed for a four-point test. The Commission
				may authorize a one-point test of shorter duration for a well which is not
				connected to a sales line, but a test which is in compliance with this section
				must be conducted and reported after the well is connected before an allowable
				will be assigned to the well. Back-dating of allowables will be performed in
				accordance with §
									RSA
				3.31 of this title (relating to Gas
				Reservoirs and Gas Well Allowable).
(b) After conducting the test required by
				subsection (a) of this section each operator of a gas well shall conduct an
				initial deliverability test and report the test results on the Commission's
				prescribed form not later than 90 days after completion of the well. If a
				72-hour one-point back pressure test on a well connected to a sales line was
				conducted as provided in subsection (a) of this section, the same test may be
				used to determine initial deliverability, provided the test was conducted in
				accordance with subsection (c) of this section.
(1) After the initial deliverability test has
				been conducted, the following schedule for well testing applies:
(A) Nonassociated gas wells shall be tested
				semiannually.
(B) Associated gas
				wells described in §
											RSA
				3.49<subdiv>(b)</subdiv> of this
				title (relating to Gas-Oil Ratio) shall be tested annually.
(C) Wells with current reported
				deliverability of 100 Mcf a day or less are not required to test as long as
				deliverability and production remain at or below 100 Mcf a day but are required
				to file Form G-10 according to the instructions on the form.
(D) Wells with a deliverability greater than
				100 Mcf a day and less than or equal to 250 Mcf a day in fields without special
				field rules are not required to be tested as long as deliverability and
				production remain equal to or less than 250 Mcf a day.
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.31 - Gas Reservoirs and Gas Well Allowable

Current through Reg. 49, No. 28; July 12, 2024
(a) General.
(1) Allowables of gas wells not currently
				assigned an allowable will not be made effective:
(A) prior to the well's completion or
				reclassification date; or
(B) more
				than 15 days prior to the date all reports or information necessary to the
				assignment of an allowable are received in the appropriate commission
				office.
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.32 - Gas Well Gas and Casinghead Gas Shall Be Utilized for Legal Purposes

Current through Reg. 49, No. 28; July 12, 2024
(a) The
				following words and terms, when used in this section, shall have the following
				meanings, unless the context clearly indicates otherwise.
(1) Fugitive emissions--Releases of gas from
				lease production, gathering, compression, or gas plant equipment components,
				including emissions from valve stems, pressure relief valves, flanges and
				connections, gas-operated valves, compressor and pump seals, pumping well
				stuffing boxes, casing-to-casing bradenheads subject to the provisions of
				§
										RSA
				3.17 of this title (relating to Pressure on
				Bradenhead), pits, and sumps, that cannot reasonably be captured and sold or
				routed to a vent or flare.
(2)
				Gathering system--Facilities employed to collect, compress, and transport gas
				to another gas gathering system, a gas plant, compression facility, or
				transmission line.
(3) Lease
				production facilities--Production, separation, treating, compression,
				flowlines, storage, and other production handling equipment employed on a lease
				in the production of gas, condensate, and oil.
(4) Low pressure separator gas--Gas separated
				or liberated from a gas-liquid stream in a low pressure separation facility.
				Low pressure separation facilities include but are not limited to separators,
				treaters, free water knockouts, and other associated equipment.
(5) Tank vapors--Gas which evolves from oil,
				condensate, or water when placed in a gunbarrel or storage tank.
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.33 - Geothermal Resource Production Test Forms Required

Current through Reg. 49, No. 28; July 12, 2024
(a) A production test form, with all
				information requested thereon filled in, shall be filed in the district office
				not later than 10 days after the test is completed. Production operations shall
				not be commenced before the test form is filed and the commission grants
				authority to initiate operations.
(b) The initial production test form for any
				new completion or recompletion must be accompanied by the well
				record.
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.35 - Procedures for Identification and Control of Wellbores in Which Certain Logging Tools Have Been Abandoned

Current through Reg. 49, No. 28; July 12, 2024
(a)
				Abandonment of radioactive source.
(1)
				Immediate notice of the loss of a radioactive source shall be filed by the
				operator with the commission designating the location, by county, survey name
				and abstract number, lease name and well number, distances from survey
				boundaries and Lambert Coordinates.
(2) Procedures for recovery of the lost
				radioactive source will be furnished to the commission and such radioactive
				source shall not be declared abandoned until all reasonable effort has been
				expended to retrieve the tool.
(3)
				The operator shall erect, under supervision of the commission, a standardized
				permanent surface marker as a visual warning to any person who may reenter the
				hole for any reason, showing that it contains a radioactive source. This marker
				shall contain the following information: well name, commission number, surface
				location, name of the operator, name of the lease, the source or material
				abandoned in the well, the total depth of the well, the depth at which the
				source is abandoned, the plug back depth, the date of the abandonment of the
				source, the activity of the source, and a warning not to drill below the plug
				back depth.
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.36 - Oil, Gas, or Geothermal Resource Operation in Hydrogen Sulfide Areas

Current through Reg. 49, No. 28; July 12, 2024
(a) Applicability.
				Each operator who conducts operations as described in paragraph (1) of this
				subsection shall be subject to this section and shall provide safeguards to
				protect the general public from the harmful effects of hydrogen sulfide. This
				section applies to both intentional and accidental releases of hydrogen
				sulfide.
(1) Operations including drilling,
				working over, producing, injecting, gathering, processing, transporting, and
				storage of hydrocarbon fluids that are part of, or directly related to, field
				production, transportation, and handling of hydrocarbon fluids that contain gas
				in the system which has hydrogen sulfide as a constituent of the gas, to the
				extent as specified in subsection (c) of this section, general
				provisions.
(2) This section shall
				not apply to:
(A) operations involving
				processing oil, gas, or hydrocarbon fluids which are either an industrial
				modification or products from industrial modification, such as refining,
				petrochemical plants, or chemical plants;
(B) operations involving gathering, storing,
				and transporting stabilized liquid hydrocarbons;
(C) operations where the concentration of
				hydrogen sulfide in the system is less than 100 ppm.
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.38 - Well Densities

Current through Reg. 49, No. 28; July 12, 2024
(a)
				Definitions. The following words and terms, when used in this section, shall
				have the following meanings, unless the context clearly indicates otherwise.
(1) Commission designee--Director of the Oil
				and Gas Division or any Commission employee designated in writing by the
				director or the Commission.
(2)
				Drilling unit--The acreage assigned to a well for drilling purposes.
(3) Proration unit--The acreage assigned to a
				well for the purpose of assigning allowables and allocating allowable
				production to the well.
(4)
				Substandard acreage--Less acreage than the smallest amount established for
				standard or optional drilling units.
(5) Surplus acreage--Substandard acreage
				within a lease, pooled unit, or unitized tract that remains unassigned after
				the assignment of acreage to each applied for, permitted, or completed well in
				a field, in an amount equaling or exceeding the amount established for standard
				or optional drilling units. Surplus acreage is distinguished from the term
				"tolerance acreage,"in that tolerance acreage is defined in context with
				proration regulation, while surplus acreage is defined by this rule only in
				context with well density regulation.
(6) Tolerance acreage--Acreage within a
				lease, pooled unit, or unitized tract that may be assigned to a well for
				proration purposes pursuant to special field rules in addition to the amount
				established for a prescribed or optional proration unit.
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.39 - Proration and Drilling Units: Contiguity of Acreage and Exception Thereto

Current through Reg. 49, No. 28; July 12, 2024
(a) Proration and
				drilling units established for individual wells drilled or to be drilled shall
				consist of acreage which is contiguous.
(b) An exception to the contiguous acreage
				provision may be granted at the operator's request if acreage that is to be
				included in the proration or drilling unit is separated by a long, narrow
				right-of-way tract.
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.41 - Application for New Oil or Gas Field Designation and/or Allowable

Current through Reg. 49, No. 28; July 12, 2024
(a) The commission
				shall assign a new field designation and/or discovery allowable after an
				operator furnishes to the commission's Austin office proper evidence, other
				than horizontal distance, proving that a well is a new discovery. An operator
				shall include the following in the application:
(1) a legible area map, drawn to scale,
				preferably on white paper, which shows the following:
(A) all oil, gas, and abandoned wells within
				at least a 2 1/2-mile radius of the well claimed to be a discovery
				well;
(B) the producing intervals
				of all pertinent oil and gas wells identified in subparagraph (A) of this
				paragraph;
(C) all
				commission-recognized fields within a 2 1/2-mile radius of the well claimed to
				be a discovery well, that are presently active or were active in the past,
				identified by commission-assigned field names, names of the producing
				formations, and approximate average depth of the producing interval;
(D) the total depth of all wells identified
				in subparagraph (A) of this paragraph that penetrated the subject
				zone;
(E) scale, legend, and name
				of person who prepared the map;
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.42 - Oil Discovery Allowable

Current through Reg. 49, No. 28; July 12, 2024
(a)
				The commission shall determine the discovery allowable rate for oil wells
				proven to be completed in a new and separate reservoir from the following
				discovery allowable schedule.
Attached
				  Graphic
(b)
				Duration and exemption from market demand limitation.
(1) Onshore. Each oil well completed in an
				oil reservoir determined by the commission to be a new onshore oil field
				onshore may receive, as a maximum daily, its discovery allowable, exempt from
				market demand limitation, for a period of 24 months (36 months for depth
				intervals deeper than 10,000 feet) from the date of assignment of the oil
				allowable to such discovery well or until the 11th oil well has been completed
				therein, whichever occurs first.
(2) Offshore. Each oil well completed in an
				oil reservoir determined by the commission to be a new offshore oil field may
				receive, as a maximum daily allowable, its discovery oil allowable, exempt from
				market demand limitation, for a period of 24 months (36 months for depth
				intervals deeper than 10,000 feet) from the date of assignment of the oil
				allowable to such discovery well or until the sixth oil well has been completed
				therein, whichever occurs first.
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.43 - Application for Temporary Field Rules

Current through Reg. 49, No. 28; July 12, 2024
(a)
				The commission will accept applications for temporary field rule hearings for
				oil, gas, or geothermal resource fields after the first well has been
				completed.
(b) When requesting such
				hearings, the applicant must furnish the commission a list of the names and
				addresses of all operators holding leases on land touching the tract on which
				the discovery well is located. The applicant must list the names and addresses
				of the owners of the abutting unleased land.
(c) Temporary field rules will apply until
				permanent field rules are adopted.
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.45 - Oil Allowables

Current through Reg. 49, No. 28; July 12, 2024
(a) Oil
				allowable yardsticks.
(1) 1947 allowable
				yardstick. The following schedule allowable shall be assigned all wells
				according to depth of the reservoir and proration unit size authorized by the
				commission upon expiration of the discovery allowable, if discovery of the
				field occurred prior to January 1, 1965, provided that paragraph (3) of this
				subsection does not apply.
Attached
				  Graphic
(2) 1965
				allowable yardstick. The following schedule allowable shall be assigned all
				wells according to depth of the reservoir and proration unit size authorized by
				the commission upon expiration of the discovery allowable, if discovery of the
				field occurred on or after January 1, 1965.
Attached
				  Graphic
(3)
				Exception. Wells in fields discovered prior to January 1, 1965, whose discovery
				allowables either have expired or will expire subsequent to July 1, 1964, upon
				expiration of the discovery allowable, may be assigned allowable pursuant to
				the 1965 yardstick, if such allowables exceed those which would be assigned
				pursuant to the 1947 yardstick, or if the proration unit size authorized by the
				commission is not provided for in the 1947 yardstick. It is provided that any
				adjustment made in allowable assignment pursuant to this paragraph shall not be
				made prior to the effective date of this order. Retroactive adjustment shall
				not be allowed.
(4) Texas offshore
				allowable yardstick.
Attached
				  Graphic
(5) The
				maximum daily allowable for a horizontal drainhole oil well or an oil well in a
				designated unconventional fracture treated (UFT) field is set forth in §
										RSA
				3.86<subdiv>(d)(4) and
				(5)</subdiv> of this title (relating to
				Horizontal Drainhole Wells).
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.46 - Fluid Injection into Productive Reservoirs

Current through Reg. 49, No. 28; July 12, 2024
(a) Permit required. Any person who engages
				in fluid injection operations in reservoirs productive of oil, gas, or
				geothermal resources must obtain a permit from the commission. Permits may be
				issued when the injection will not endanger oil, gas, or geothermal resources
				or cause the pollution of freshwater strata unproductive of oil, gas, or
				geothermal resources. Permits from the commission issued before the effective
				date of this section shall continue in effect until revoked, modified, or
				suspended by the commission.
(b)
				Filing of application.
(1) Application.
(A) An application to conduct fluid injection
				operations in a reservoir productive of oil, gas, or geothermal resources shall
				be filed in Austin on the form prescribed by the commission accompanied by the
				prescribed fee. On the same date, one copy shall be filed with the appropriate
				district office. The form shall be executed by a party having knowledge of the
				facts entered on the form.
(B) The
				applicant shall file the freshwater injection data form if fresh water is to be
				injected.
(C) The applicant for a
				disposal well permit under this section shall include with the permit
				application a printed copy or screenshot showing the results of a survey of
				information from the United States Geological Survey (USGS) regarding the
				locations of any historical seismic events within a circular area of 100 square
				miles (a circle with a radius of 9.08 kilometers) centered around the proposed
				disposal well location.
(D) The
				commission may require an applicant for a disposal well permit under this
				section to provide the commission with additional information such as logs,
				geologic cross-sections, pressure front boundary calculations, and/or structure
				maps, to demonstrate that fluids will be confined if the well is to be located
				in an area where conditions exist that may increase the risk that fluids will
				not be confined to the injection interval. Such conditions may include, but are
				not limited to, complex geology, proximity of the basement rock to the
				injection interval, transmissive faults, and/or a history of seismic events in
				the area as demonstrated by information available from the USGS.
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.47 - Allowable Transfers for Saltwater Injection Wells

Current through Reg. 49, No. 28; July 12, 2024
An allowable transfer will not be authorized for a well
				  converted from oil production to saltwater disposal; however, an operator may
				  make application to use the well for dual-purpose waterflood and saltwater
				  disposal if injection is into an oil productive zone, and it is shown that the
				  water injection will not injure the reservoir but will probably be of benefit
				  to the reservoir as a secondary recovery program even though the beneficial
				  effect of the water injection cannot be readily determined.
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.48 - Capacity Oil Allowables for Secondary or Tertiary Recovery Projects

Current through Reg. 49, No. 28; July 12, 2024
(a) Definitions.
				The following words and terms, when used in this section, shall have the
				following meanings, unless the context clearly indicates otherwise.
(1) Capacity oil allowable--The allowable
				assigned from time to time by the director of the Oil and Gas Division or the
				director's delegate to an oil lease or unit engaged in a secondary or tertiary
				recovery program, that is consistent with the ability of the lease or unit to
				produce and that will prevent the occurrence of overproduced status for the
				lease or unit. Capacity oil allowables encompass and supercede what the
				Railroad Commission formerly designated as waterflood allowables.
(2) Offsetting operators and unleased mineral
				interest owners affected by the application--All offsetting operators and
				unleased mineral interest owners to the lease or unit except for those
				offsetting operators and unleased mineral owners the director of the Oil and
				Gas Division or the director's delegate determines to be unaffected by the
				application.
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.49 - Gas-Oil Ratio

Current through Reg. 49, No. 28; July 12, 2024
(a) Any oil well
				producing with a gas-oil ratio in excess of 2,000 cubic feet of gas per barrel
				of oil produced shall be allowed to produce daily only that volume of gas
				obtained by multiplying its maximum daily oil allowable, as determined by the
				allocation formula applicable to the well, by 2,000. The gas volume thus
				obtained shall be known as the daily gas limit of the well. The daily oil
				allowable of the well shall then be determined by dividing its daily gas limit,
				obtained as provided in this section, by its producing gas-oil ratio in cubic
				feet per barrel of oil produced.
(b) Any gas well producing from the same
				reservoir in which oil wells are completed and producing shall be allowed to
				produce daily only that amount of gas which is the volumetric equivalent in
				reservoir displacement of the gas and oil produced from the oil well in the
				reservoir that withdraws the maximum amount of gas in the production of its
				daily oil allowable.
(1) The following
				formula shall be used in the determination of the allowable of a gas well
				producing with a gas-oil ratio of 100,000 or more.
Attached
				  Graphic
(2) The
				following formula shall be used in the determination of the allowable of a gas
				well producing with a gas-oil ratio of less than 100,000 under the provisions
				of the rule stated.
Attached
				  Graphic
(3) The
				allowable for an associated gas well as determined by this subsection shall be
				limited to the lesser of:
(A) the gas well
				allowable as calculated by paragraph (1) or (2) of this subsection;
(B) the well's capability as determined by
				§
											RSA
				3.31<subdiv>(e)</subdiv> of this
				title (relating to Gas Reservoirs and Gas Well Allowable) (Statewide Rule 31);
				or
(C) the highest monthly
				production during those months averaged to a daily amount for wells that
				reported production during any of the three most recently reported production
				months.
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.50 - Enhanced Oil Recovery Projects - Approval and Certification for Tax Incentive

Current through Reg. 49, No. 28; July 12, 2024
(a) Purpose.
				The purpose of this section is to provide a procedure by which an operator can
				obtain Railroad Commission approval and certification of enhanced oil recovery
				(EOR) projects pursuant to Texas Tax Code, §
									RSA 202.052, §
									RSA
				202.054, and §
									RSA
				202.0545.
(b) Applicability.
(1) This section applies to:
(A) new EOR projects and the change from
				secondary EOR projects to tertiary projects which qualify as new EOR projects,
				and which begin active operation on or after September 1, 1989; and
(B) expansions of existing EOR
				projects.
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.51 - Oil Potential Test Forms Required

Current through Reg. 49, No. 28; July 12, 2024
(a) A completed potential test form shall be
				filed with the Commission not later than the deadline for filing completion
				reports under §
									RSA
				3.16 of this title (relating to Log and
				Completion or Plugging Report). If the operator fails to file a potential test
				in an acceptable form prior to the deadline for filing completion reports as
				specified under §
									RSA
				3.16 of this title, then the effective date
				of the allowable resulting from the test shall not extend back more than 30
				days prior to the date that the test form, properly completed, is filed with
				the Commission. This 30-day provision shall govern regardless of whether the
				potential test is taken during the month in which it is received by the
				Commission or any prior month.
(b)
				The initial potential test form for any new completion or recompletion must be
				accompanied by the well record.
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.53 - Annual Well Tests and Well Status Reports Required

Current through Reg. 49, No. 28; July 12, 2024
(a) Oil wells.
(1) Unless otherwise provided for in this
				section, each operator of producing oil wells shall annually test each
				producing oil well for a 24-hour period during the test period specified on the
				well status report form and shall record all oil, gas and water volumes
				resulting from the test on the form.
(2) For any oil well capable of producing no
				more than five barrels of oil per 24-hour period, the operator of such well may
				report the required oil, gas and water volumes based on an allocation of that
				well's production on a prorated daily basis, rather than an actual well test.
				This option of using production allocation instead of actual well tests does
				not apply to surface-commingled wells, swabbed wells, the East Texas Field or
				the following Panhandle fields: Panhandle Carson County Field (Field Number
				68845-001); Panhandle Collingsworth County Field (Field Number 68859-001);
				Panhandle Gray County Field (Field Number 68873-001); Panhandle Hutchison
				County Field (Field Number 68887-001); Panhandle Moore County field (Field
				Number 68901-001); Panhandle Potter County Field (Field Number 68915-001); and
				Panhandle Wheeler County Field (Field Number 68929-001).
(3) Each operator of a well or wells listed
				in the oil proration schedule shall file with the commission an oil well status
				report form in accordance with instructions on the form. All wells on a lease,
				and injection and disposal wells, must be reported.
(4) Changes in oil well status filed between
				regularly scheduled oil well status surveys shall be submitted on oil well
				status report forms in accordance with instructions thereon.
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.54 - Gas Reports Required

Current through Reg. 49, No. 28; July 12, 2024
(a)
				Gas processing plant report. As soon after the first day of each calendar month
				as practicable, and never later than the 25th day of each calendar month, the
				operator of each plant manufacturing or extracting liquid hydrocarbons,
				including gasoline, butane, propane, condensate, kerosene, or other derivatives
				from natural gas, or refinery or storage vapors, shall file, in duplicate, in
				the Austin office, a report concerning the operation of the plant during the
				immediately preceding month, which must contain the data and information
				required on the form.
(b) Pressure
				maintenance and repressuring plant report.
(1) As soon after the first day of each month
				as practicable, but never later than the 15th day of each calendar month, the
				operator of each plant that returns natural gas to oil or gas producing
				reservoirs, or both, for the purpose of maintaining pressure or repressuring an
				oil or gas reservoir, but is not reporting such gas on any other commission
				approved form, shall file in duplicate in the district office a report
				concerning the operation of the plant during the immediately preceding month,
				which must contain the data and information required on the form.
(2) Pressure maintenance.
(A) The operator of each pressure-maintenance
				or repressuring plant shall file the report although no liquid hydrocarbons are
				recovered.
(B) The term
				"pressure-maintenance plant" or "repressuring plant" as used herein means any
				equipment or device, mechanical or otherwise, used for the purpose of returning
				any natural gas, residue gas from a gas processing plant, including plant and
				storage vapors, to an underground oil reservoir if the plant is operated as a
				separate unit. If pressure maintenance or repressuring operations are conducted
				as an integral part of a gas processing plant extracting, manufacturing, or
				recovering liquid hydrocarbons from natural gas or vapors, or both, the
				operations shall be reported by the operator of the processing plant.
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.55 - Reports on Gas Wells Commingling Liquid Hydrocarbons before Metering

Current through Reg. 49, No. 28; July 12, 2024
(a) When the full
				well stream from a gas well is moved to a plant or central separation
				facilities, and the liquid hydrocarbons produced by two or more wells are
				commingled without being measured or metered from each gas well, the operator
				of each well so producing shall periodically file with the commission, as
				provided for in this section, a report showing the following information for
				each well:
(1) the specific gravity of the
				gas at 60 degrees Fahrenheit, after the removal of the liquid
				hydrocarbons;
(2) the API gravity
				corrected to 60 degrees Fahrenheit of the liquid hydrocarbons
				removed;
(3) the number of stock
				tank barrels of liquid hydrocarbons (corrected to 60 degrees Fahrenheit)
				recovered per 1,000 standard cubic feet of gas.
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.56 - Scrubber Oil and Skim Hydrocarbons

Current through Reg. 49, No. 28; July 12, 2024
(a)
				Definitions. The following words and terms, when used in this section, shall
				have the following meanings unless the context clearly indicates otherwise:
(1) Identifiable liquid hydrocarbons--Volume
				of scrubber oil/skim hydrocarbons that is received at a gas plant/produced
				water disposal facility where the origin of such liquid hydrocarbons can be
				clearly identified.
(2) Producing
				property--A location from which hydrocarbons are being produced that has been
				assigned a lease identification number by the Commission and which is used in
				reporting production.
(3) Scrubber
				oil--Liquid hydrocarbons which accumulate in lines that are transporting
				casinghead gas and which are captured at the inlet to a gas processing
				plant.
(4) Skim hydrocarbons--Oil
				and condensate which accumulate during produced water disposal
				operations.
(5) Tolerance--The
				amount of skim hydrocarbons that may be recovered before the produced water
				disposal system operator must allocate to the producing property.
(6) Unidentifiable liquid
				hydrocarbons--Scrubber oil/skim hydrocarbons received at a gas plant/produced
				water disposal facility where the origin of such liquid hydrocarbons cannot be
				identified.
Texas Administrative Code › Title 16 - ECONOMIC REGULATION › Part 1 - RAILROAD COMMISSION OF TEXAS › Chapter 3 - OIL AND GAS DIVISION › Section 3.57 - Reclaiming Tank Bottoms, Other Hydrocarbon Wastes, and Other Waste Materials

Current through Reg. 49, No. 28; July 12, 2024
(a) Applicability.
				This section is applicable to reclamation of tank bottoms and other hydrocarbon
				wastes generated through activities associated with the exploration,
				development, and production (including transportation) of crude oil and other
				waste materials containing oil, as those activities are defined in §
									RSA
				3.8<subdiv>(a)(30)</subdiv> of
				this title (relating to Water Protection). The provisions of this section shall
				not apply where tank bottoms or other hydrocarbon-bearing materials are
				recycled or processed on-site by the owner/custodian and are returned to a tank
				or vessel at the same lease or facility. This section is not applicable to the
				practice of recycling or reusing drilling mud, except as to those hydrocarbons
				recovered from such mud recycling and sent to a permitted reclamation
				plant.
(b) Definitions. The
				following words and terms, when used in this section, shall have the following
				meanings, unless the context clearly indicates otherwise.
(1) Tank bottoms--A mixture of crude oil or
				lease condensate, water, and other substances that is concentrated at the
				bottom of producing lease tanks and pipeline storage tanks (commonly referred
				to as basic sediment and water or BS&W).
(2) Other hydrocarbon wastes--Oily waste
				materials, other than tank bottoms, which have been generated in connection
				with activities associated with the exploration, development, and production of
				oil or gas or geothermal resources, as those activities are defined in §
										RSA
				3.8<subdiv>(a)(30)</subdiv> of
				this title (relating to Water Protection). The term "other hydrocarbon wastes"
				includes, but is not limited to, pit hydrocarbons, skim oil, spillage, and
				leakage of crude oil or condensate from producing lease or pipeline storage
				tanks, and crude oil or condensate associated with pipeline ruptures and other
				spills.
(3) Authorized person--A
				tank bottoms cleaner or transporter that is under contract for disposition of
				untreated tank bottoms or other hydrocarbon wastes to a person who has obtained
				a permit to operate a reclamation plant.
(4) Affected person--A person who has
				suffered or will suffer actual injury or economic damage other than as a member
				of the general public and includes surface owners of property on which a
				reclamation plant is located and surface owners of adjoining
				properties.
(5) Director--The
				director of the Oil and Gas Division or a staff delegate designated in writing
				by the director of the Oil and Gas Division or the commission.