reglab/statecodes huggingface dataset:
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 3 - Requirements › Section 1722.1.1 - Well and Operator Identification

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a) Each well location shall have posted in a
					 conspicuous place a clearly visible, legible, permanently affixed sign with the
					 name of the operator, name or number of the lease, and number of the well.
					 These signs shall be maintained on the premises from the time drilling
					 operations cease until the well is plugged and abandoned.
(b) The appropriate Division district deputy
					 may approve existing identification methods if they substantially comply with
					 the intent of this section.
1. New
						section filed 5-23-88; operative 6-22-88 (Register 88, No. 22). For prior
						history, see Register 84, No. 52.
2. Change without regulatory
						effect amending subsection (a) filed 9-3-96 pursuant to section
						100, title 1, California Code of
						Regulations (Register 96, No. 36).
3. Amendment of subsection (a)
						filed 7-11-2006; operative 8-10-2006 (Register 2006, No. 28).
4.
						Change without regulatory effect amending subsection (b) filed 12-26-2006
						pursuant to section
						100, title 1, California Code of
						Regulations (Register 2006, No. 52).
Note: Authority cited: Sections
						  3013
						  and
						  3106,
						  Public Resources Code. Reference: Sections
						  3106,
						  Public Resources Code.
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 3 - Requirements › Section 1722.2 - Casing Program

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
Each well shall have casing designed to provide anchorage
						for blowout prevention equipment and to seal off fluids and segregate them for
						the protection of all oil, gas, and freshwater zones. All casing strings shall
						be designed to withstand anticipated collapse, burst, and tension forces with
						the appropriate design factor provided to obtain a safe operation.
Casing setting depths shall be based upon geological and
						engineering factors, including but not limited to the presence or absence of
						hydrocarbons, formation pressures, fracture gradients, lost circulation
						intervals, and the degree of formation compaction or consolidation. All depths
						refer to true vertical depth (TVD) below ground level.
1. New
						section filed 2-17-78; effective thirtieth day thereafter (Register 78, No.
						7).
2. Amendment filed 12-28-84; effective thirtieth day thereafter
						(Register 84, No. 52).
Note: Authority cited: Sections
						  3013
						  and
						  3106,
						  Public Resources Code. Reference: Sections
						  3219
						  and
						  3220,
						  Public Resources Code.
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 3 - Requirements › Section 1722.4 - Cementing Casing

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
Surface casing shall be cemented with sufficient cement
						to fill the annular space from the shoe to the surface. Intermediate and
						production casings, if not cemented to the surface, shall be cemented with
						sufficient cement to fill the annular space to at least 500 feet above oil and
						gas zones, and anomalous pressure intervals. Sufficient cement shall also be
						used to fill the annular space to at least 100 feet above the base of the
						freshwater zone, either by lifting cement around the casing shoe or cementing
						through perforations or a cementing device placed at or below the base of the
						freshwater zone. All casing shall be cemented in a manner that ensures proper
						distribution and bonding of cement in the annular spaces. The appropriate
						Division district deputy may require a cement bond log, temperature survey, or
						other survey to determine cement fill behind casing. If it is determined that
						the casing is not cemented adequately by the primary cementing operation, the
						operator shall recement in such a manner as to comply with the above
						requirements. If supported by known geologic conditions, an exception to the
						cement placement requirements of this section may be allowed by the appropriate
						Division district deputy.
1. New
						section filed 2-17-78; effective thirtieth day thereafter (Register 78, No.
						7).
2. Editorial correction of NOTE filed 12-28-84; effective
						thirtieth day thereafter (Register 84, No. 52).
3. Amendment of
						section and NOTE filed 8-4-95; operative 9-3-95 (Register 95, No.
						31).
4. Change without regulatory effect amending section filed
						12-26-2006 pursuant to section
						100, title 1, California Code of
						Regulations (Register 2006, No. 52).
Note: Authority cited: Section
						  3013,
						  Public Resources Code. Reference: Sections
						  3106,
						  3220
						  and
						  3222-
						  3224,
						  Public Resources Code.
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 3 - Requirements › Section 1722.5 - Blowout Prevention and Related Well Control Equipment

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
Blowout prevention and related well control equipment
						shall be installed, tested, used, and maintained in a manner necessary to
						prevent an uncontrolled flow of fluid from a well. Division of Oil, Gas, and
						Geothermal Resources publication No. MO 7, "Blowout Prevention in California,"
						shall be used by Division personnel as a guide in establishing the blowout
						prevention equipment requirements specified in the Division's approval of
						proposed operations.
1. New
						section filed 2-17-78; effective thirtieth day thereafter (Register 78, No.
						7).
2. Amendment filed 12-28-84; effective thirtieth day thereafter
						(Register 84, No. 52).
3. Change without regulatory effect amending
						section filed 9-3-96 pursuant to section
						100, title 1, California Code of
						Regulations (Register 96, No. 36).
4. Change without regulatory
						effect amending section filed 2-16-2000 pursuant to section
						100, title 1, California Code of
						Regulations (Register 2000, No. 7).
5. Change without regulatory
						effect amending section filed 12-26-2006 pursuant to section
						100, title 1, California Code of
						Regulations (Register 2006, No. 52).
Note: Authority cited: Sections
						  3013
						  and
						  3106,
						  Public Resources Code. Reference: Sections
						  3219
						  and
						  3220,
						  Public Resources Code.
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 3 - Requirements › Section 1722.6 - Drilling Fluid Program

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
The operational procedures and the properties, use, and
						testing of drilling fluid shall be such as are necessary to prevent the
						uncontrolled flow of fluids from any well. Drilling fluid additives in
						sufficient quantity to ensure well control shall be kept readily available for
						immediate use at all times. Fluid which does not exert more hydrostatic
						pressure than the known pressure of the formations exposed to the well bore
						shall not be used in a drilling operation without prior approval of the
						supervisor.
(a) Before removal of the
					 drill pipe or tubing from the hole is begun, the drilling fluid shall be
					 conditioned to provide adequate pressure overbalance to control any potential
					 source of fluid entry. Proper overbalance shall be confirmed by checking the
					 annulus to ensure that there is no fluid flow or loss when there is no fluid
					 movement in the drill pipe or tubing. The drilling fluid weight, the weight and
					 volume of any heavy slug or pill, and the fact that the annulus was checked for
					 fluid movement shall be noted on the driller's log. During removal of the drill
					 pipe or tubing from the hole, a hole-filling program shall be followed to
					 maintain a satisfactory pressure overbalance condition.
(b) Tests of the drilling fluid to determine
					 viscosity, water loss, weight, and gel strength shall be performed at least
					 once daily while circulating, and the results of such tests shall be recorded
					 on the driller's log. Equipment for measuring viscosity and fluid weight shall
					 be maintained at the drill site. Exceptions to the test requirements may be
					 granted for special cases, such as shallow development wells in low pressure
					 fields, through the field rule process.
(c) Disposal of drilling fluids shall be done
					 in accordance with Section
					 1775, Subchapter 2 of these
					 regulations.
1. New
						section filed 2-17-78; effective thirtieth day thereafter (Register 78, No.
						7).
2. Editorial correction of NOTE filed 12-28-84; effective
						thirtieth day thereafter (Register 84, No. 52).
Note: Authority cited: Sections
						  3013
						  and
						  3106,
						  Public Resources Code. Reference: Sections
						  3219
						  and
						  3220,
						  Public Resources Code.
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 3 - Requirements › Section 1722.7 - Directional Surveys

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
The Supervisor may order that a well be directionally
						surveyed.
1. New
						section filed 8-4-95; operative 9-3-95 (Register 95, No. 31).
2.
						Change without regulatory effect amending section filed 12-26-2006 pursuant to
						section 100, title 1, California Code of
						Regulations (Register 2006, No. 52).
Note: Authority cited: Section
						  3013,
						  Public Resources Code. Reference: Sections
						  3106
						  and
						  3224,
						  Public Resources Code.
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 3 - Requirements › Section 1722.8 - Life-of-Well and Life-of-Production Facility Bonding Requirements

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a) Life-of-well
					 and life-of-production facility bonds may be required by the Supervisor in
					 addition to bond coverage specified in the Public Resources Code Sections
					 3202,
					 3204,
					 3205,
					 3205.2
					 and
					 3206.
(b) The Supervisor may order a life-of-well
					 and/or a life-of-production facility bond for an operator with a history of
					 violating Public Resources Code, Division 3, Chapter 1 and the regulations
					 promulgated thereunder, or that has outstanding liabilities to the state
					 associated with a well or production facility. When determining whether to
					 order a life-of-well and/or a life-of-production facility bond the Supervisor
					 shall consider each of the following:
(1) The
					 severity of the cited violations or civil penalties that the operator has
					 received, and the potential for serious damage to health, safety, or natural
					 resources caused by the violations.
(2) Any ongoing failure to address a cited
					 violation and any pattern of recurring or repeated violations by the
					 operator.
(3) Any evidence that the
					 operator's facility maintenance practices are not in compliance with Public
					 Resources Code, Division 3, Chapter 1 and the regulations promulgated
					 thereunder.
(4) Any failure to
					 comply an order of the Supervisor.
(5) The severity of the spills or leaks that
					 have occurred that the operator is responsible for, and the potential for
					 serious damage to health, safety, or natural resources caused by the spills or
					 leaks.
(6) The extent to which any
					 spills or leaks that the operator is responsible for were the result of a
					 violation of any statute or regulation.
(7) The extent to which any spills or leaks
					 that the operator is responsible for were the result of a lack of training or
					 supervision of the operator's employees or contractors.
(8) The extent to which any spills or leaks
					 that the operator is responsible for were the result of a failure to exercise
					 good oilfield practices.
(9) If the
					 operator has any outstanding liability to the state associated with a well or
					 production facility, whether the liability is the result of a violation of a
					 statute or regulations, and whether the operator is making a good faith effort
					 to repay the liability.
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 3 - Requirements › Section 1722.8.1 - Bonding Language

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
The conditions of a bond required under Public Resources
						Code Section
						3270.4
						shall be stated in substantially the following language: "If the __________,
						the above bounden principal, shall well and truly comply with all the
						provisions of Division 3 (commencing with Section
						3000) of the Public Resources Code
						and shall obey all lawful orders of the State Oil and Gas Supervisor or the
						district deputy or deputies, subject to subsequent appeal as provided in that
						division, and shall pay all charges, costs, and expenses incurred by the
						supervisor or the district deputy or deputies in respect of the well,
						production facility, or the property or properties of the principal, or
						assessed against the well, production facility, or the property or properties
						of the principal, in pursuance of the provisions of that division, then this
						obligation shall be void; otherwise, it shall remain in full force and
						effect."
1. New
						section filed 12-30-2010; operative 1-29-2011 (Register 2010, No.
						53).
Note: Authority cited: Sections
						  3013
						  and
						  3270.4,
						  Public Resources Code. Reference: Section
						  3270.4,
						  Public Resources Code.
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 3 - Requirements › Section 1722.9 - Spill Contingency Plan Requirements

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
A spill contingency plan shall be designed to prevent and
						respond to unauthorized releases and contain the following:
(a) A list of the operator's 24-hour
					 emergency contact telephone numbers. The operator's emergency contact shall be
					 prepared to provide Division staff complete information about the production
					 facility emergency shutdown procedures, including a list of safety shutdown
					 devices including, but not limited to, kill switches, emergency shut-down
					 devices, or master valves.
(b) A
					 list of available personal safety equipment, including location and maintenance
					 frequency.
(c) A one page
					 quick-action checklist for use during initial stages of a spill
					 response.
(d) A list of required
					 local, state and federal agency notifications with telephone numbers,
					 including, but not limited to, the phone number for the appropriate Division
					 district office and the phone number for reporting spills to the California
					 Emergency Management Agency.
(e) A
					 list of control and/or cleanup equipment available onsite or locally, with
					 contact procedures.
(f) A map of
					 the production facilities covered by the plan, including:
(1) Labeling of all permanent tanks,
					 equipment, and pipelines. If locations are not known, the most probable
					 location shall be shown and identified as a probable location.
(2) Identification of access roads for
					 emergency response.
(3) Labeling of
					 all out-of-service equipment.
(4)
					 Labeling of all sumps and catch basins.
(5) Volume of all tanks and storage
					 containers covered by the plan, listing the type of fluid stored.
(6) All designated waterways within
					 one-quarter mile of the facility.
(7) Location of secondary containment with
					 access routes.
(8) Topography or
					 drainage flow direction.
(9) All
					 storm drains within one-quarter mile of the site.
(10) A fluid flow
					 schematic.
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 3 - Requirements › Section 1723.1 - Plugging of Oil or Gas Zones

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a) Plugging in an Open Hole. A cement plug
					 shall be placed to extend from the total depth of the well or from at least 100
					 feet below the bottom of each oil or gas zone, to at least 100 feet above the
					 top of each oil or gas zone.
(b)
					 Plugging in a Cased Hole. All perforations shall be plugged with cement, and
					 the plug shall extend at least 100 feet above the top of a landed liner, the
					 uppermost perforations, the casing cementing point, the water shut-off holes,
					 or the oil or gas zone, whichever is highest.
(c) Special Requirements. Special
					 requirements may be made for particular types of hydrocarbon zones, such as:
(1) Fractured shale or schist;
(2) Massive sand intervals, particularly
					 those with good vertical permeability;
(3) Any depleted productive interval more
					 than 100 feet thick; or
(4)
					 Multiple zones completed in a well.
As a minimum for an open-hole plugging and abandonment,
						the special requirement shall include a cement plug extending from at least 100
						feet below the top of the oil or gas zone to at least 100 feet above the top of
						the zone.
As a minimum for a cased-hole plugging and abandonment,
						the special requirement shall include a cement plug extending from at least 25
						feet below the top of the uppermost perforated interval to at least 100 feet
						above the top of the perforations, the top of the landed liner, the casing
						cementing point, the water shutoff holes, or the zone, whichever is
						highest.
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 3 - Requirements › Section 1723.2 - Plugging for Freshwater Protection

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a) Plugging in Open Hole.
(1) A minimum 200-foot cement plug shall be
					 placed across all fresh-saltwater interfaces.
(2) An interface plug may be placed wholly
					 within a thick shale if such shale separates the freshwater sands from the
					 brackish or saltwater sands.
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 3 - Requirements › Section 1723.3 - Plugging at a Casing Shoe

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
If the hole is open below a shoe, a cement plug shall
						extend from at least 50 feet below to at least 50 feet above the shoe. If the
						hole cannot be cleaned out to 50 feet below the shoe, a 100-foot cement plug
						shall be placed as deep as possible.
1.
						Amendment filed 9-21-76; effective thirtieth day thereafter (Register 76, No.
						39).
2. Amendment filed 12-28-84; effective thirtieth day thereafter
						(Register 84, No. 52).
Note: Authority cited: Sections
						  3013
						  and
						  3106,
						  Public Resources Code. Reference: Sections
						  3106
						  and
						  3228,
						  Public Resources Code.
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 3 - Requirements › Section 1723.4 - Plugging at the Casing Stub. [Repealed]

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
1.
						Amendment filed 9-21-76; effective thirtieth day thereafter (Register 76, No.
						39).
2. Amendment of section heading and new NOTE filed 12-28-84;
						effective thirtieth day thereafter (Register 84, No. 52).
3.
						Repealer filed 7-11-2006; operative 8-10-2006 (Register 2006, No.
						28).
Note: Authority cited: Sections
						  3013
						  and
						  3106,
						  Public Resources Code. Reference: Sections
						  3106
						  and
						  3228,
						  Public Resources Code.
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 3 - Requirements › Section 1723.5 - Surface Plugging

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
The hole and all annuli shall be plugged at the surface
						with at least a 25-foot cement plug. The district deputy may require that inner
						strings of uncemented casing be removed to at least the base of the surface
						plug prior to placement of the plug.
All well casing shall be cut off at least 5 feet but no
						more than 10 feet below the surface of the ground. The district deputy may
						approve a different cut-off depth, as conditions warrant, including but not
						limited to excavation or grading operations for construction purposes. As
						defined in Section
						1760(j), a steel
						plate at least as thick as the outer well casing shall be welded around the
						circumference of the casing at the top of the casing, after Division approval
						of the surface plug. The steel plate shall show the well's identification,
						indicated by the last five digits of the API well number.
1.
						Amendment filed 9-21-76; effective thirtieth day thereafter (Register 76, No.
						39).
2. Amendment filed 6-30-80; effective thirtieth day thereafter
						(Register 80, No. 27).
3. Amendment filed 12-28-84; effective
						thirtieth day thereafter (Register 84, No. 52).
4. Amendment of
						second paragraph filed 7-22-98; operative 8-21-98 (Register 98, No.
						30).
5. Amendment filed 7-11-2006; operative 8-10-2006 (Register
						2006, No. 28).
6. Change without regulatory effect amending last
						paragraph filed 12-26-2006 pursuant to section
						100, title 1, California Code of
						Regulations (Register 2006, No. 52).
Note: Authority cited: Sections
						  3013
						  and
						  3106,
						  Public Resources Code. Reference: Section
						  3106,
						  Public Resources Code.
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 3 - Requirements › Section 1723.6 - Recovery of Casing

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a)
					 Approval to recover all casing possible will be given in the plugging and
					 abandonment of wells where subsurface plugging can be done to the satisfaction
					 of the district deputy.
(b) The
					 hole shall be full of fluid prior to the detonation of any explosives in the
					 hole. Such explosives shall be utilized only by a licensed handler with the
					 required permits.
1.
						Amendment filed 9-21-76; effective thirtieth day thereafter (Register 76, No.
						39).
2. New NOTE filed 12-28-84; effective thirtieth day thereafter
						(Register 84, No. 52).
3. Change without regulatory effect amending
						subsection (a) filed 9-3-96 pursuant to section
						100, title 1, California Code of
						Regulations (Register 96, No. 36).
Note: Authority cited: Sections
						  3013
						  and
						  3106,
						  Public Resources Code. Reference: Sections
						  3106
						  and
						  3228,
						  Public Resources Code.
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 3 - Requirements › Section 1723.7 - Inspection of Plugging and Abandonment Operations

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
Plugging and abandonment operations that require
						witnessing by the Division shall be witnessed and approved by a Division
						employee. When discretion is indicated by these regulations, the district
						deputy shall determine which operations are to be witnessed.
(a) Blowout prevention equipment--may inspect
					 and witness testing of equipment and installation.
(b) Oil and gas zone plug--may witness
					 placing and shall witness location and hardness.
(c) Mudding of hole--may witness mudding
					 operations and determine that specified physical characteristics of mud fluid
					 are met.
(d) Freshwater protection:
(1) Plug in open hole--may witness placing
					 and shall witness location and hardness. Plug in cased hole--shall witness
					 placing or location and hardness.
(2) Cementing through perforations--may
					 witness perforating and shall witness cementing operation.
(3) Cavity shot--may witness shooting and
					 shall witness placing or location and hardness of required
					 plug.
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 3 - Requirements › Section 1723.8 - Special Requirements

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
The Supervisor, in special cases, may set forth other
						plugging and abandonment requirements or may establish field rules for the
						plugging and abandonment of wells. Such cases include, but are not limited
						to:
(a) The plugging of a
					 high-pressure saltwater zone.
(b)
					 Perforating and squeeze-cementing previously uncemented casing within and above
					 a hydrocarbon zone.
(c) The
					 plugging of particular zones or specifying cleanout intervals within a
					 wellbore.
1.
						Amendment filed 9-21-76; effective thirtieth day thereafter (Register 76, No.
						39).
2. New NOTE filed 12-28-84; effective thirtieth day thereafter
						(Register 84, No. 52).
3. New subsection (c) filed 7-11-2006;
						operative 8-10-2006 (Register 2006, No. 28).
4. Change without
						regulatory effect amending first paragraph filed 12-26-2006 pursuant to section
						100, title 1, California Code of
						Regulations (Register 2006, No. 52).
Note: Authority cited: Sections
						  3013
						  and
						  3106,
						  Public Resources Code. Reference: Section
						  3106,
						  Public Resources Code.
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 3 - Requirements › Section 1723.9 - Testing of Idle Wells

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
Operators shall comply with all of the requirements in
						Section 1772.1 for the testing of idle
						wells.
1. New
						section filed 8-4-95; operative 9-3-95 (Register 95, No. 31).
2.
						Change without regulatory effect amending section filed 12-26-2006 pursuant to
						section 100, title 1, California Code of
						Regulations (Register 2006, No. 52).
3. Repealer and new section and
						amendment of NOTE filed 3-20-2019; operative 4-1-2019 pursuant to Government
						Code section
						11343.4(b)(3)
						(Register 2019, No. 12).
Note: Authority cited: Section
						  3013,
						  Public Resources Code. Reference: Sections
						  3106
						  and
						  3206.1,
						  Public Resources Code.
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 3 - Requirements › Section 1724 - Required Well Records

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
The operator of any well drilled, redrilled, deepened, or
						reworked shall keep, or cause to be kept, an accurate record of each operation
						on each well including, but not limited to, the following, when
						applicable:
(a) Log and history
					 showing chronologically the following data:
(1) Character and depth of all formations,
					 water-bearing strata, oil- and gas-bearing zones, lost circulation zones, and
					 abnormal pressure zones encountered.
(2) Casing size, weight, grade, type,
					 condition (new or used), top, bottom, and perforations; and any equipment
					 attached to the casing.
(3) Tubing
					 size and depth, type and location of packers, safety devices, and other tubing
					 equipment.
(4) Casing pressure
					 tests and pressure tests of the casing-tubing annulus, including date,
					 duration, pressure, and percent bleed-off.
(5) Hole sizes.
(6) Cementing and plugging operations,
					 including date, depth, slurry volume and composition, fluid displacement,
					 pressures, calculated or actual fill, and downhole equipment.
(7) Drill-stem, leak-off, or other formation
					 tests, including date, duration, depth, pressures, and recovery (volume and
					 description).
(8) BOPE
					 installation, inspections, and pressure tests.
(9) Water shutoff and lap tests of casing,
					 including date, duration, depth, and results.
(10) Sidetracked casing, tools or other
					 material, collapsed or bad casing, holes in casing, and stuck drill pipe,
					 tubing, or other junk in casing or open hole.
(11) Depth and type of all electrical,
					 physical, or chemical logs, tests, or surveys made.
(12) Production or injection method and
					 equipment.
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 3 - Requirements › Section 1724.1 - Records to be Filed with the Division

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
Two true and reproducible copies of the well summary,
						core record, and history, and all electrical, physical and chemical logs, tests
						and surveys run, including mud logs shall be filed with the Division within 60
						days after the completion, plugging and abandonment, or suspension of
						operations of a well. Dipmeter surveys shall be submitted in a form indicating
						the computed direction and amount of dip.
1. New
						section filed 2-17-78; effective thirtieth day thereafter (Register 78, No.
						7).
2. Amendment filed 12-28-84; effective thirtieth day thereafter
						(Register 84, No. 52).
3. Change without regulatory effect amending
						section filed 9-3-96 pursuant to section
						100, title 1, California Code of
						Regulations (Register 96, No. 36).
4. Change without regulatory
						effect amending section filed 12-26-2006 pursuant to section
						100, title 1, California Code of
						Regulations (Register 2006, No. 52).
Note: Authority cited: Sections
						  3013,
						  3106
						  and
						  3107,
						  Public Resources Code. Reference: Sections
						  3107,
						  3215
						  and
						  3216,
						  Public Resources Code.
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 3 - Requirements › Section 1724.2 - Maintenance of Production Facilities, Safety Systems, and Equipment. [Repealed]

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
1. New
						section filed 2-17-78; effective thirtieth day thereafter (Register 78, No.
						7).
2. Amendment filed 12-28-84; effective thirtieth day thereafter
						(Register 84, No. 52).
3. Amendment of section heading, section and
						NOTE filed 8-4-95; operative 9-3-95 (Register 95, No. 31).
4.
						Repealer filed 12-30-2010; operative 1-29-2011 (Register 2010, No.
						53).
Note: Authority cited: Section
						  3013,
						  Public Resources Code. Reference: Sections
						  3106,
						  3219,
						  3220
						  and
						  3222-
						  3224,
						  Public Resources Code.
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 3 - Requirements › Section 1724.3 - Well Safety Devices for Critical Wells

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
Certain wells designated by the Supervisor, that meet the
						definition of "critical" pursuant to Section
						1720(a) and have
						sufficient pressure to allow fluid-flow to the surface, shall have safety
						devices as specified by the Supervisor, installed and maintained in operating
						condition. A description of such safety devices follows:
(a) Surface safety devices.
(1) Fail-close, well shut-in or shut-down
					 devices. Wellhead assemblies shall be equipped with an automatic fail-close
					 valve.
(2) High-low pressure
					 sensors in all flowlines, set to actuate shut in or shut down of the well(s) in
					 the event of abnormal pressures in the flowlines.
(3) Check valves in all headers, except for
					 gas storage wells, to prevent backflow in the event of flowline failure. All
					 flowlines and valves shall be capable of withstanding shut-in wellhead
					 pressure, unless protected by a relief valve with connections to bypass the
					 header.
(4) Fire detection devices,
					 such as fusible plugs, at strategic points in pneumatic, hydraulic, and other
					 shut-in control lines in fire hazard areas.
(5) Remote, manually operated, quick
					 operating shut-in controls at strategic points.
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 3 - Requirements › Section 1724.4 - Testing and Inspection of Safety Devices

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a) All installed well safety devices,
					 required pursuant to Section
					 1724.3 of this article, shall be
					 tested at least every six (6) months, as follows:
(1) Flow line pressure sensors shall be
					 tested for proper pressure settings.
(2) Automatic wellhead safety valves shall be
					 tested for reliable operation and holding pressure.
(3) Subsurface safety devices shall be tested
					 for reliable operation.
(4) Tubing
					 plugs or packers shall be tested for holding pressure.
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 4 - Underground Injection Control › Section 1724.5 - Purpose, Scope, and Applicability

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
The purpose of this article is to set forth regulations
						governing underground injection projects and injection wells. This article
						applies to underground injection projects and injection wells in existence
						prior to the effective date of this article, as well as new underground
						injection projects and injection wells. Underground injection projects and
						injection wells are not subject to the requirements of Article 5, Sections
						1726 through
						1726.10.
1. New
						article 4 (sections
						1724.5-1724.13) and section filed
						2-6-2019; operative 4-1-2019 (Register 2019, No. 6). For prior history, see
						Register 84, No. 52.
Note: Authority cited: Sections
						  3013
						  and
						  3106,
						  Public Resources Code. Reference: Section
						  3106,
						  Public Resources Code.
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 4 - Underground Injection Control › Section 1724.7.1 - Casing Diagrams

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a)
					 Casing diagrams submitted under the requirements of this article shall include
					 all of the following data:
(1) Operator name,
					 lease name, well number, and API number of the well;
(2) Date the well was spudded;
(3) Ground elevation from sea
					 level;
(4) Reference elevation
					 (i.e., rig floor or Kelly bushing);
(5) Base of freshwater;
(6) Base of the lowermost USDW penetrated by
					 the well;
(7) Sizes, grades,
					 connection type, and weights of casing;
(8) Depths of shoes, stubs, and liner
					 tops;
(9) Depths of perforations
					 and perforation intervals, open-hole completions, water shutoff holes, cement
					 ports, cavity shots, cuts, type and extent of casing damage, type and extent of
					 junk or fish, and any other feature that influences flow in the well or may
					 compromise the mechanical integrity of the well;
(10) Information regarding equipment in the
					 well such as subsurface safety valves, packers, and gas lift
					 mandrels;
(11) Diameter and depth
					 of hole for all drilled intervals;
(12) Identification of cement plugs inside
					 casings, including locations of the top and bottom of cement plugs;
(13) Identification of cement fill behind
					 casings, including locations of the top and bottom of cement fill;
(14) Type and weight (density) of fluid
					 between cement plugs; and
(15)
					 Depths and names of the formations, zones, and markers penetrated by the well,
					 including the top and bottom of both the injection zone and confining layer(s)
					 for the underground injection project(s).
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 4 - Underground Injection Control › Section 1724.7.2 - Liquid Analysis

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a)
					 Liquid analysis required under this article shall include testing for all of
					 the following: total dissolved solids; total petroleum hydrocarbon as crude
					 oil; major cations (Ca, Mg, Na, K, Fe, Mn, Sr, B); major anions (CI,
					 SO4, HCO3,
					 CO3, Br, I); total alkalinity and hydroxide; electrical
					 conductance; pH; and temperature.
(b) The Division may require testing for
					 additional constituents on a project-specific basis. Any additional
					 constituents shall be listed in the Project Approval Letter for the
					 project.
(c) To ensure the liquid
					 analysis required under Section
					 1724.7(a)(2)(B)
					 is representative of the reservoir liquid in its native condition, if feasible
					 the liquid analyzed shall be either sampled from the injection zone itself
					 prior to commencement of any injection into the reservoir or sampled from an
					 analogous reservoir that has not already received injection fluid. The
					 representative sample shall be recovered after all completion and drilling
					 fluid has been circulated from the wellbore.
(d) To ensure the liquid analysis required
					 under Sections
					 1724.7(a)(3)(H)
					 and 1724.10(d) is
					 representative of the liquid actually injected, the liquid to be analyzed shall
					 be sampled after all additives (if any) are added to the liquid, and after all
					 treatment or separation processes (if any).
(e) Liquid analysis required under this
					 article shall be performed by a laboratory that is certified by the State Water
					 Resources Control Board environmental laboratory accreditation program. The
					 performing laboratory shall submit the data and analysis to the Division
					 directly, using a digital format.
1. New
						section filed 2-6-2019; operative 4-1-2019 (Register 2019, No.
						6).
Note: Authority cited: Sections
						  3013
						  and
						  3106,
						  Public Resources Code. Reference: Section
						  3106,
						  Public Resources Code.
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 4 - Underground Injection Control › Section 1724.9 - Underground Gas Storage Projects. [Repealed]

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
1. New
						section filed 2-17-78; effective thirtieth day thereafter (Register 78, No.
						7).
2. Editorial correction of NOTE filed 12-28-84; effective
						thirtieth day thereafter (Register 84, No. 52).
3. Change without
						regulatory effect amending first paragraph filed 12-26-2006 pursuant to section
						100, title 1, California Code of
						Regulations (Register 2006, No. 52).
4. Amendment of section
						heading, section and NOTE filed 2-5-2016 as an emergency; operative 2-5-2016
						(Register 2016, No. 6). A Certificate of Compliance must be transmitted to OAL
						by 8-3-2016 or emergency language will be repealed by operation of law on the
						following day.
5. Amendment of section heading, section and NOTE
						refiled 8-1-2016 as an emergency; operative 8-1-2016 (Register 2016, No. 32). A
						Certificate of Compliance must be transmitted to OAL by 10-31-2016 or emergency
						language will be repealed by operation of law on the following
						day.
6. Amendment of section heading, section and NOTE refiled
						10-31-2016 as an emergency; operative 10-31-2016 (Register 2016, No. 45). A
						Certificate of Compliance must be transmitted to OAL by 1-30-2017 or emergency
						language will be repealed by operation of law on the following
						day.
7. Change without regulatory effect amending NOTE filed
						1-3-2017 pursuant to section
						100, title 1, California Code of
						Regulations (Register 2017, No. 1). Pursuant to Senate Bill 887 (Stats. 2016,
						Ch. 673, Sec.
						6), which shall remain in effect
						only until January 1, 2019, this section shall remain in effect until the
						adoption, amendment, or repeal of the regulations is promulgated by the
						Division of Oil, Gas, and Geothermal Resources in the Department of
						Conservation pursuant to Chapter 3.5 of Part 1 of Division 3 of Title 2 of the
						Government Code.
8. Certificate of Compliance as to 10-31-2016
						order, as extended by Senate Bill 887 (Stats. 2016, Ch. 673, Sec.
						6), effectively repealing section,
						section heading, and NOTE, transmitted to OAL 5-16-2018 and filed 6-28-2018;
						operative 10-1-2018 (Register 2018, No. 26).
Note: Authority cited: Sections
						  3013
						  and
						  3106,
						  Public Resources Code; and Statutes of 2016, Chapter 673, Section
						  6. Reference: Sections
						  3106,
						  3220
						  and
						  3403.5,
						  Public Resources Code.
California Code of Regulations › Title 14 - Natural Resources › Division 2 - Department of Conservation › Chapter 4 - Development, Regulation, and Conservation of Oil and Gas Resources › Subchapter 1 - Onshore Well Regulations › Article 4 - Underground Injection Control › Section 1724.10.2 - Mechanical Integrity Testing Part Two - Fluid Migration Behind Casing, Tubing, or Packer

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a) In
					 addition to testing under Section
					 1724.10.1, operators shall
					 periodically test injection wells to demonstrate that there is no fluid
					 migration behind the casing, tubing, or packer. This testing may be
					 accomplished by any of the methods set forth in subdivisions (d) through (f),
					 or other method approved by the Division (including modifications of the
					 methods below when approved by the Division in writing). Operators shall obtain
					 written approval from the Division regarding the testing method prior to
					 performing the tests.
(b) Testing
					 under this section is required within three months after injection has
					 commenced for the first time after a well is approved or reapproved by the
					 Division for injection. Commencing April 1, 2019, subsequent testing under this
					 section is required at least once every two years, with the following
					 exceptions:
(1) Disposal injection wells shall
					 be tested at least once a year;
(2)
					 Low-use cyclic steam injection wells are required to be tested at least once
					 every five years;
(3) If a well
					 that previously met the definition of a low-use cyclic steam injection well has
					 not been tested in over one year, then testing is required within one year of
					 the time that the well stopped being a low-use cyclic steam injection
					 well.
(4) Steamflood injection
					 wells equipped with tubing and packer are required to be tested at least once
					 every five years;
(5) Testing is
					 required following an unplanned variance in injection pressure of more than 25
					 percent within a 48-hour period, unless the operator demonstrates to the
					 Division that the variance was the result of an issue that does not relate to
					 well integrity; and
(6) Testing is
					 required when requested by the Division, including as may be specified in the
					 Project Approval Letter.