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 4 - Underground Injection Control › Section 1724.10.3 - Maximum Allowable Surface Injection Pressure

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a) Injection pressure at surface shall not
					 exceed the maximum allowable surface injection pressure for an injection well,
					 as approved by the Division under this section and documented in the supporting
					 project data under Section
					 1724.7(a)(4).
					 Except as provided under subdivision (b), the maximum allowable surface
					 injection pressure for an injection well shall be the lower of following two
					 values:
(1) A calculated pressure value equal
					 to the true vertical depth of the shallowest portion of the well open to the
					 injection zone multiplied by the difference between the injection gradient and
					 the injection fluid gradient (MASIP = (IG - IFG) * TVD). The injection gradient
					 used for this calculation shall be the product of the fracture gradient as
					 determined under subdivision (b) or (c), multiplied by 0.95, or other
					 multiplier subject to Division approval on a well-specific basis that more
					 appropriately accounts for factors such as a conservative allowance for
					 friction loss. If the Division allows friction loss to be factored into the
					 calculation, then the friction factor shall be calculated based on the new
					 coated tubing of the largest diameter that will be used for injection. If a
					 single well is injecting through dual injection strings, then the friction
					 factor of the two strings shall be calculated separately.
(2) The initial test pressure used during the
					 most recent successful pressure test of the injection well under Section
					 1724.10.1(b). If
					 the pressure testing requirement for the injection well was satisfied under
					 Section 1724.10.1(c) or
					 (d), then the maximum allowable surface
					 injection pressure shall be the calculated pressure value as determined under
					 subdivision (a)(1).
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 1724.10.4 - Continuous Pressure Monitoring

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a) Operators shall comply with the following
					 requirements for well-specific injection pressure monitoring:
(1) Well-specific injection pressure shall be
					 continuously recorded at all times that a well is approved for injection by the
					 Division, regardless of whether injection is actually occurring. An operator
					 may satisfy this requirement by recording injection pressure from a header or
					 manifold if approved by the Division based on a showing that the operator is
					 able to calculate well-specific injection pressures from the recorded data. An
					 operator may suspend continuous injection pressure recording for a well while
					 the well is disconnected from all injection lines.
(2) Injection pressure records shall be
					 maintained by the operator as long as the well is approved for injection by the
					 Division, and for three years after that, and shall be provided to the Division
					 upon request.
(3) On or before the
					 last day of each month, operators shall report to the Division the highest
					 instantaneous injection pressure for each injection well in the last preceding
					 calendar month.
(4) Digital or
					 analog pressure recording devices may be used to meet the requirements of this
					 subdivision. A Division-approved supervisory control and data acquisition
					 (SCADA) or equivalent continuous real-time recording system, with automatic
					 computer alarm notification, is not required but may be used to meet the
					 requirements of this subdivision. Pressure recording devices shall be
					 maintained in good working order and be calibrated as recommended by the
					 manufacturer. Evidence of such calibration shall be available to the Division
					 upon request.
(5) The Division may
					 waive the requirements of this section for an injection well if the operator
					 demonstrates that the injection facilities are configured in a manner that
					 effectively prevents injection into the injection well above the maximum
					 allowable surface injection 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 1724.11 - Surface Expression Prevention and Response

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a) Underground injection projects shall not
					 result in any surface expression.
(b) The following requirements apply to all
					 underground injection projects that the Division determines have been known to
					 cause a surface expression, and to all underground injection projects that
					 involve the application of steam to a diatomaceous formation unless it has been
					 demonstrated to the Division's satisfaction on a project-specific basis that
					 surface expressions are not a concern for that project:
(1) The operator shall develop a surface
					 expression monitoring and prevention plan for review and approval by the
					 Division. At a minimum, the plan shall include the following:
(A) A subsurface injection-production mass
					 balancing surveillance system utilizing a continuous tilt meter array or other
					 ground monitoring system approved by the Division; or implementation of a
					 real-time pressure/flow monitoring system that will give adequate warning to
					 prevent surface expressions.
(B) A
					 map of the project area with all surface expressions, including cracks,
					 fissures, and sink holes related to underground injection, and containment
					 measures prominently marked. A current map of these features shall be provided
					 to the Division and shall be updated as these features are discovered,
					 installed, or changed.
(C)
					 Protocols for restriction of access to areas where there are surface
					 expressions or surface expression containment measures.
(D) Training, including safety measures and
					 identification of possible hazards, for field personnel working in areas where
					 there are surface expressions or where surface expressions may occur.
(E) If the Division's determination that an
					 underground injection project is subject to the requirements of this
					 subdivision does not occur until after the Division's approval of the
					 underground injection project, then the operator shall submit this plan to the
					 Division within six months of the Division's determination.
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 1724.12 - Surface Expression Containment

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a) The following requirements apply to the
					 installation and use of surface expression containment measures, if any:
(1) The operator shall provide the Division
					 with notice of construction of a surface expression containment measure to
					 allow the Division to observe and document the installation.
(2) Surface expression containment measures
					 shall be designed and signed off by, and construction supervised and approved
					 by, a professional engineer licensed under Chapter 7 of Division 3 of the
					 California Business and Professions Code. All surface expression containment
					 measures shall be included in the operator's Spill Contingency Plan required
					 under Section
					 1722.9, shall meet all federal,
					 state, and local requirements, and shall ensure that surface expressions do not
					 threaten surface water or USDWs.
(3) Upon completion of a surface expression
					 containment measure, the licensed engineer shall provide a signed written
					 report to the Division indicating whether the surface expression containment
					 measure was constructed as designed and will safely and effectively contain and
					 collect the flow from the surface expression.
(4) The operator shall monitor and record the
					 rate of flow of the surface expression and monitor the containment measures at
					 least daily, unless the Division has approved less frequent monitoring. The
					 operator shall maintain records of the monitoring of the surface expression and
					 containment measures for as long as the surface expression persists and provide
					 them to the Division upon request. The operator shall immediately notify the
					 Division if the surface expression increases in flow or size, reactivates, or
					 moves, or if there is any indication that the effectiveness of the surface
					 expression containment measure has diminished.
(5) The operator shall map and prominently
					 mark in the field all surface expression containment measures, and shall
					 restrict access to such containment measures.
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 1724.13 - Universal Operating Restrictions and Incident Response

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a) The operator shall cease injection into
					 the affected injection well and immediately notify the Division if any of the
					 following occur:
(1) The operator has not
					 performed mechanical integrity testing on the well as required by Section
					 1724.10(i) or the
					 notification and results required under Section
					 1724.10(i) have
					 not been provided to the Division;
(2) The well failed a mechanical integrity
					 test required by Section
					 1724.10(i) or
					 there is any other indication that the well lacks mechanical integrity or is
					 otherwise incapable of performing as approved by the Division;
(3) There is any indication of a failure,
					 breach, or hole in the well tubing, packer, cement, or well casing, including
					 failures above a packer;
(4) There
					 is visible surface damage or erosion of the well location caused by
					 injection;
(5) There is any
					 indication that fluids being injected into the well are not confined to the
					 approved injection zone;
(6) There
					 is any indication that damage to life, health, property, or natural resources,
					 or loss of hydrocarbons is occurring by reason of the injection;
(7) The operator has not provided information
					 regarding the well as required under Public Resources Code section
					 3227;
(8) The well has become an idle well as
					 defined by Public Resources Code section
					 3008,
					 subdivision (d), unless the operator has requested and the Division has granted
					 an allowance for the well to remain approved for injection for a longer period
					 while the well is idle; or
(9) The
					 Division instructs the operator in writing to suspend
					 injection.
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 5 - Requirements for Underground Gas Storage Projects › Section 1726 - 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 gas storage projects and gas storage wells. This article
						applies to underground gas storage projects and gas storage wells in existence
						prior to the effective date of this article, as well as new underground gas
						storage projects and gas storage wells. Underground gas storage projects and
						gas storage wells are not subject to the requirements of Sections
						1724.6 through
						1724.10.
1. New
						article 4 (sections
						1726-1726.10) and section filed
						6-28-2018; operative 10-1-2018 (Register 2018, No. 26).
2.
						Renumbering of article 4 to article 5 filed 2-6-2019; operative 4-1-2019
						(Register 2019, No. 6).
Note: Authority cited: Sections
						  3013,
						  3106
						  and
						  3180,
						  Public Resources Code. Reference: Sections
						  3106,
						  3180,
						  3181,
						  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 5 - Requirements for Underground Gas Storage Projects › Section 1726.1 - Definitions

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a) The following
					 definitions are applicable to this article:
(1) "Area of review" means the
					 three-dimensional extent of the reservoir used for underground gas storage and
					 surrounding areas that may be subject to its influence. The area of review is
					 delineated by the geologic extent of the reservoir such as confining strata,
					 structural closure, decrease or loss of porosity and permeability, or
					 hydrodynamic forces in a three dimensional image.
(2) "Confining strata" means the rock layer
					 or layers at the boundaries of the storage reservoir acting as the primary
					 barriers preventing migration of fluids.
(3) "Fluid" means liquid or gas.
(4) "Gas storage well" means an active or
					 idle well used primarily to inject or withdraw gas from an underground gas
					 storage project.
(5) "Reservoir"
					 means the portion of the geologic stratum that is being used to store natural
					 gas in an underground gas storage project. The entire depth interval of a
					 reservoir from the shallowest to the deepest depth can be subdivided into one
					 or more depth intervals, which are referred to in this article as
					 "zones".
(6) "Underground gas
					 storage project" means a project for the injection and withdrawal of natural
					 gas into an underground reservoir for the purpose of storage. An underground
					 gas storage project includes the reservoir used for storage, the confining
					 strata, gas storage wells, observation wells, and any other wells approved for
					 use in the project. An underground gas storage project also includes the
					 wellheads and, to the extent that they are subject to regulation by the
					 Division, attendant facilities, and other appurtenances.
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 5 - Requirements for Underground Gas Storage Projects › Section 1726.2 - Approval of Underground Gas Storage Projects

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a) A Project Approval Letter shall be
					 obtained from the Division before any injection or withdrawal occurs as part of
					 an underground gas storage project. The Project Approval Letter shall specify
					 the location and nature of the underground gas storage project, as well as the
					 conditions of the Division's approval. Changes to the operational parameters of
					 an underground gas storage project as set forth in the Project Approval Letter
					 are subject to approval by the Division and shall be noted in either an
					 addendum to the Project Approval Letter or a revised Project Approval Letter.
					 Underground gas storage project operations shall not occur or continue unless
					 consistent with the terms and conditions of a current Project Approval
					 Letter.
(b) The Division will
					 review underground gas storage projects periodically, but not less than once
					 every three years, to verify adherence to the terms and conditions of the
					 Project Approval Letter, and will periodically review the terms and conditions
					 of the Project Approval Letter to ensure that they effectively prevent damage
					 to life, health, property, the environment, and natural resources. Project
					 Approval Letters are subject to suspension, modification, or rescission by the
					 Division.
(c) If the Division
					 determines that operation of an underground gas storage project is inconsistent
					 with the terms and conditions of a current Project Approval Letter, or
					 otherwise poses a threat to life, health, property, the environment, or natural
					 resources, then upon written notice from the Division specified operations
					 shall cease immediately, or as soon as it is safe to do so.
1. New
						section filed 6-28-2018; operative 10-1-2018 (Register 2018, No.
						26).
Note: Authority cited: Sections
						  3013,
						  3106
						  and
						  3180,
						  Public Resources Code. Reference: Sections
						  3106,
						  3180,
						  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 5 - Requirements for Underground Gas Storage Projects › Section 1726.3.1 - Emergency Response Plan

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a) The operator of an underground gas
					 storage project shall have an emergency response plan approved by the Division
					 and ready for immediate implementation. The emergency response plan shall
					 specify a schedule for carrying out drills to validate the plan. The drills
					 shall address the readiness of operator personnel with respect to their ability
					 to interact with equipment and their ability to contact required third party
					 service providers for the equipment.
The emergency response plan shall identify and consider
						onsite personnel, outside emergency responders, and potentially affected
						communities. The operators shall provide local emergency response entities at
						least 30 days to review and provide input on the emergency response
						plan.
(b) The emergency
					 response plan shall at a minimum address the following scenarios:
(1) Collisions involving well
					 heads;
(2) Well fires and
					 blowouts;
(3) Hazardous material
					 spills;
(4) Equipment
					 failures;
(5) Natural
					 disasters/emergencies;
(6) Leaks
					 and well failures;
(7) Medical
					 emergencies; and
(8)
					 Explosions.
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 5 - Requirements for Underground Gas Storage Projects › Section 1726.4.1 - Casing Diagrams

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a)
					 Casing diagrams submitted under Section
					 1726.4, subdivision (a)(5)(F),
					 shall adhere to the following requirements:
(1) Casing diagrams shall at a minimum
					 include all of the following data:
(A)
					 Operator, lease name, well number, and API number of the well;
(B) Date the well was spudded;
(C) Ground elevation from sea
					 level;
(D) Reference elevation
					 (i.e., rig floor or Kelly Bushing);
(E) Base of groundwater that has 3,000 or
					 less milligrams per liter of total dissolved solids content;
(F) Base of groundwater that has 10,000 or
					 less milligrams per liter of total dissolved solids content;
(G) Sizes, weights, grades, and connection
					 types of casing and tubing;
(H)
					 Details on associated equipment such as subsurface safety valves, packers, and
					 gas lift mandrels;
(I) Depths of
					 casing shoes, stubs, and liner tops;
(J) Depths of perforation intervals, water
					 shutoff perforations, cement port, cavity shots, cuts, patches, casing damage,
					 top of junk or fish left in well, and any feature that influences flow in the
					 well or may compromise the mechanical integrity of the well;
(K) Hole size diameter and depth of drilled
					 hole;
(L) Cement plugs inside
					 casings, including top and bottom of cement plug and the date(s) the plug(s)
					 was emplaced, with method of determination;
(M) All cement fill behind casings, including
					 top and bottom of cemented interval, with method of determination;
(N) Type and density of fluid between cement
					 plugs;
(O) Depths and names of the
					 formation(s), zone(s), and geologic markers penetrated by the well, including
					 the top and bottom of the gas storage zone(s) and the top and bottom of the
					 confining strata;
(P) All
					 information used to calculate the cement slurry (e.g., volume, density, yield)
					 including, but not limited to, cement type and additives, for each cement
					 job;
(Q) All of the information
					 listed in this section for all previously drilled or sidetracked well bores;
					 and
(R) Identification of wellhead
					 and wellhead valve assembly equipment by model and pressure
					 rating.
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 5 - Requirements for Underground Gas Storage Projects › Section 1726.4.2 - Evaluation of Wells Within the Area of Review

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a) The following requirements apply, at
					 minimum and subject to augmentation by the Division as the Division deems
					 appropriate on a project-specific basis, to ensure that wells within the area
					 of review will not be a potential conduit for fluid migration outside the
					 approved gas storage zone:
(1) All wells
					 within the area of review and that are in the same or a deeper zone as the gas
					 storage reservoir, including directionally drilled wells that intersect the
					 area of review in the same or deeper zone, shall be evaluated for the potential
					 to allow fluid to migrate outside of the approved zone of gas storage. The
					 operator should identify, and the Division confirm, wells which may require
					 integrity testing or well logging in order to provide the requisite assurances
					 that such wells will not act as conduits for fluid migration.
(2) Plugged and abandoned wells within the
					 area of review shall have cement across all perforations and extending at least
					 100 feet above the highest of the top of a landed liner, the uppermost
					 perforations, the casing cementing point, the water shutoff holes, or the
					 approved gas storage zone. The Division may select plugged and abandoned wells
					 to be re-entered, examined, re-plugged and abandoned, or monitored to manage
					 identified containment assurance issues.
(3) If a plugged and abandoned well within
					 the area of review does not meet the cement specifications of subdivision
					 (a)(2), the Division may approve an alternative demonstration that the well
					 will not be a potential conduit for fluid migration outside the approved gas
					 storage zone. The Division's approval of such an alternative demonstration
					 shall be supported by written findings by the Division that identify each
					 plugged and abandoned well in the area of review that does not meet the cement
					 specifications of subdivision (a)(2), specify how the well does not meet the
					 requirements of subdivision (a)(2), and identify the basis for the Division's
					 approval of the alternative demonstration.
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 5 - Requirements for Underground Gas Storage Projects › Section 1726.4.3 - Records Management

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a) The operator of an underground gas
					 storage project shall establish a Records Management Program to ensure
					 documentation of essential information is created, maintained, protected, and
					 retrievable when needed. The operator shall submit its Records Management Plan
					 to the Division.
(b) The Records
					 Management Program shall identify all records related to evidence of conformity
					 to the requirements in this article as essential, and these records shall be
					 maintained for the lifetime of the project.
(c) The Records Management Program shall
					 establish a filing and storage strategy that ensures records are accessible and
					 protected against environmental damage. Records may exist in many different
					 formats and shall be managed according to the format in which they are
					 maintained. Records may be protected following a graded approach, commensurate
					 with the value of the record and the cost to reproduce the
					 information.
(d) The Records
					 Management Program shall establish a process for tracking records throughout
					 their entire information life cycle so that it is clear at all times where a
					 record exists, which is the most current version of the record, and the history
					 of change or modification of the record.
(e) The Records Management Program shall
					 allow for prompt retrieval and production of records upon request from the
					 Division.
1. New
						section filed 6-28-2018; operative 10-1-2018 (Register 2018, No.
						26).
Note: Authority cited: Sections
						  3013,
						  3106
						  and
						  3180,
						  Public Resources Code. Reference: Sections
						  3106,
						  3181,
						  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 5 - Requirements for Underground Gas Storage Projects › Section 1726.5 - Well Construction Requirements

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a) Operators shall design, construct,
					 modify, and maintain gas storage wells and every other well that penetrates the
					 gas storage reservoir of the operator's underground gas storage project to
					 effectively ensure mechanical integrity under anticipated operating conditions
					 for the underground gas storage project. The operator shall ensure that a
					 single point of failure does not pose an immediate threat of loss of control of
					 fluids and make certain that integrity concerns with a gas storage well are
					 identified and addressed before they can become a threat to life, health,
					 property, the environment, or natural resources. This section does not apply to
					 wells that have been plugged and abandoned in accordance with Public Resources
					 Code section
					 3208.
(b) Operators can demonstrate that a gas
					 storage well adheres to the performance standard in subdivision (a) by
					 demonstrating all of the following:
(1) The
					 well has been constructed with both primary and secondary mechanical well
					 barriers to isolate the storage gas within the storage reservoir and transfer
					 storage gas from the surface into and out of the storage reservoir.
(A) The primary mechanical barrier is the
					 barrier that is exposed to the withdrawal or injection flow stream. The primary
					 mechanical barrier shall be able to withstand full operating pressure as
					 demonstrated by the pressure testing required under Section
					 1726.6, subdivision (a)(3), and
					 through annular pressure monitoring as required under Section
					 1726.7, subdivision (a). An
					 example of a well configuration that meets the minimum requirements for a
					 primary mechanical barrier is a well configuration that includes:
(i) A wellhead master valve;
(ii) Tubing hanger with seals;
(iii) Production tubing; and
(iv) A production packer.
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 5 - Requirements for Underground Gas Storage Projects › Section 1726.6.1 - Pressure Testing Parameters

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a) Pressure testing required under Section
					 1726.6 shall be conducted
					 according to the following parameters:
(1)
					 Pressure testing shall be conducted with a liquid unless the Division approves
					 pressure testing with gas.
(2) If
					 pressure testing will be conducted with a liquid that contains additive other
					 than brine, corrosion inhibitors, or biocides, then the operator shall consult
					 with the Division regarding the contents of the liquid prior to commencing
					 testing.
(2) The wellbore shall be
					 filled with a stable column of fluid that is free of excess gasses.
(3) Pressure tests shall be recorded and a
					 calibrated gauge shall be used that can record a pressure with an accuracy
					 within one percent of the maximum allowable injection pressure.
(4) Pressure tests shall be conducted at an
					 initial test pressure of at least 115 percent of the maximum allowable
					 injection pressure at the wellhead.
(5) The pressure test shall be continuous for
					 one hour. A pressure test is successful if the pressure gauge does not show
					 more than a 10 percent decline from the initial test pressure in the first 30
					 minutes, and does not show more than a 2 percent decline from the pressure
					 after the first 30 minutes in the second 30 minutes.
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 5 - Requirements for Underground Gas Storage Projects › Section 1726.7 - Monitoring Requirements

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a) The operator shall monitor for the
					 presence of gas in all annuli by measuring and recording annular and tubing
					 pressure at least once a day. The operator shall evaluate any anomalous annular
					 gas occurrence and immediately report it to the Division. This requirement may
					 be met by employment of a real-time data gathering system, such as Supervisory
					 Control and Data Acquisition.
(b)
					 The operator shall monitor the material balance of an underground gas storage
					 project's storage reservoir relative to the original design and expected
					 reservoir behavior. The operator shall evaluate and correct unexpected
					 conditions detected during monitoring in order to avoid an incident or loss.
					 Monitoring frequency shall be based on factors such as reservoir and well fluid
					 loss potential and flow potential, as outlined in the Risk Management Plan.
(1) The operator shall submit material
					 balance support data to the Division at least once a year, or upon request by
					 the Division.
(2) Acceptable
					 reservoir integrity monitoring and analysis methods include, but are not
					 limited to, the following four methods:
(A)
					 Monitoring average reservoir pressure versus inventory and comparing that to
					 expected conditions in order to allow for the discovery and correction of any
					 anomalies or unexpected conditions. Liquid level shall be taken into account
					 when utilizing observation wells. Semiannual field shut-in tests, usually
					 conducted at the point of seasonally high and low inventories, shall be
					 conducted for inventory verification.
(B) Installation and monitoring of
					 strategically located observation wells in the vicinity of spill points, within
					 an aquifer, and above the confining strata. Observation wells shall be in
					 potential collector formations to detect the presence or movement of
					 gas.
(C) Monitoring offset
					 hydrocarbon production or disposal operations for unexplained flow or pressure
					 changes. The monitoring shall include operations in zones above and below the
					 storage reservoir as well as laterally offset locations.
(D) Conducting subsurface correlation and gas
					 identification logs such as gamma ray-neutron logs to confirm the location of
					 gas being injected into the intended storage reservoir, as
					 needed.
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 5 - Requirements for Underground Gas Storage Projects › Section 1726.8 - Inspection, Testing, and Maintenance of Wellheads and Valves

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a) Where
					 installed, the operator of an underground gas storage project shall test all
					 surface safety valves on the wellhead and all subsurface safety valve systems
					 at least every six months. The tests shall be conducted in accordance with
					 American Petroleum Institute Recommended Practice 14B (6th Edition, September
					 2015), hereby incorporated by reference, or a Division approved equivalent, to
					 confirm operational integrity. The appropriate district office shall be
					 notified at least 48 hours before performing testing so that Division staff may
					 witness the operations, and documentation of the testing shall be maintained
					 and available for Division review. A closed storage well safety valve system
					 shall be re-opened with operator staff at the site of the valve to ensure the
					 absence of any unforeseen issues. Within 90 days of finding that a surface or
					 subsurface safety valve is inoperable, the operator shall either repair the
					 safety valve or temporarily plug the well. An appropriate alternative timeframe
					 for testing a valve or addressing an inoperable surface or subsurface safety
					 valve may be required by the Division.
(b) At least annually, the operator of an
					 underground gas storage project shall test all valves on the wellhead,
					 including the master valve and wellhead pipeline isolation valve for proper
					 function and verify ability to isolate the well.
(c) The operator shall equip gas storage
					 wells with valves to provide isolation of the wells from the pipeline system
					 and to allow for entry into the wells.
(d) The operator shall equip all ports on the
					 wellhead assembly above the casing bowl of gas storage wells with valves, blind
					 flanges, or similar equipment that are rated to withstand the maximum
					 operational pressures.
1. New
						section filed 6-28-2018; operative 10-1-2018 (Register 2018, No.
						26).
Note: Authority cited: Sections
						  3013,
						  3106
						  and
						  3180,
						  Public Resources Code. Reference: Sections
						  3106,
						  3180,
						  3181,
						  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 5 - Requirements for Underground Gas Storage Projects › Section 1726.9 - Well Leak Reporting

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a) For the purposes of this section, and for
					 the purposes of Public Resources Code sections
					 3183
					 and
					 3184,
					 "reportable leak" means:
(1) A leak from a
					 gas storage well that is above 50,000 parts per million by volume total
					 hydrocarbons, as measured using methodology that the operator has demonstrated
					 will provide consistent and reliable measurements, such as US EPA Reference
					 Method 21;
(2) A leak from a gas
					 storage well that is above 10,000 parts per million by volume total
					 hydrocarbons, as measured using methodology that the operator has demonstrated
					 will provide consistent and reliable measurements, such as US EPA Reference
					 Method 21, for more than five days; or
(3) Any leak that poses a significant present
					 or potential hazard to public health and safety, property, or to the
					 environment.
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 5 - Requirements for Underground Gas Storage Projects › Section 1726.10 - Requirements for Decommissioning

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a) If an operator intends to discontinue an
					 underground gas storage project, then the operator shall submit a
					 Decommissioning Plan to the Division. The Decommissioning Plan is subject to
					 the Division's review and approval and shall ensure that stored gas will
					 continue be confined to the approved zone(s) of injection and that the
					 underground gas storage project will not cause damage to life, health,
					 property, the environment, or natural resources. At a minimum, the
					 Decommissioning Plan shall address all of the following:
(1) Identification of the intended use of the
					 wells and facilities after decommissioning, including a plan for obtaining
					 requisite approvals for the use.
(2) A plan for managing remaining gas in the
					 underground gas storage reservoir.
(3) A plan for repurposing or decommissioning
					 all wells and facilities associated with the underground gas storage
					 project.
(4) Consultation with the
					 California Public Utilities Commission.
(5) Any other information requested by the
					 Division on a project-specific basis.
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 1.1 - Offshore Well Regulations › Article 1 - General › Section 1740 - Purpose

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
It is the purpose of this subchapter to set forth the
						rules and regulations governing the drilling, redrilling, production,
						maintenance, and plugging and abandonment of offshore oil and gas wells in
						accordance with the provisions of Division 3 of the Public Resources
						Code.
1. New
						Subchapter 1.1 ( §§
												1740,
						1740.1-1740.5,
						1741-1744,
						1744.1-1744.6,
						1745,
						1745.1-1745.10,
						1746,
						1747,
						1747.1-1747.10,
						1748,
						1748.1-1748.3,
						1749) filed 4-22-74; effective
						thirtieth day thereafter (Register 74, No. 17).
2. Change without
						regulatory effect amending section filed 9-3-96 pursuant to section
						100, title 1, California Code of
						Regulations (Register 96, No. 36).
Note: Authority cited: Sections
						  3000-
						  3013
						  and
						  3106,
						  Public Resources Code. Reference: Sections
						  3203-
						  3220
						  and
						  3227-
						  3237,
						  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 1.1 - Offshore Well Regulations › Article 1 - General › Section 1740.1 - Policy

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
Section
						3106 of Division 3 of the Public
						Resources Code will be administered with the objective of furthering declared
						legislative policy; namely, that the Supervisor shall supervise drilling,
						operation, maintenance, and plugging and abandonment of wells to prevent as far
						as possible, damage to life, health, property, and natural resources, damage to
						underground oil and gas deposits from infiltrating water and other causes, loss
						of oil, gas, or reservoir energy and damage to underground and surface waters
						suitable for irrigation or domestic purposes by the infiltration of, or the
						addition of detrimental substances by reason of the drilling, operation,
						maintenance, or plugging and abandonment of wells.
1. Change
						without regulatory effect amending section filed 9-3-96 pursuant to section
						100, title 1, California Code of
						Regulations (Register 96, No. 36).
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).
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 1.1 - Offshore Well Regulations › Article 1 - General › Section 1740.2 - Scope of Regulations

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
They shall apply to any and all oil or gas well
						operations conducted from locations within the offshore territorial boundaries
						and inland bays of the State of California, and where in conflict, the existing
						regulations shall supersede any and all previous rules, regulations, and
						requirements pertaining to the operations previously stated.
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 1.1 - Offshore Well Regulations › Article 1 - General › Section 1740.3 - Revision of Regulations

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
The Supervisor at appropriate intervals, or as the need
						arises, may review and issue special regulations or change present regulations,
						and such special regulations or changes shall prevail against general
						regulations if in conflict therewith. Public hearings on such special issues or
						changes will be held if required.
1. Change
						without regulatory effect amending section filed 12-26-2006 pursuant to section
						100, title 1, California Code of
						Regulations (Register 2006, No. 52).
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 1.1 - Offshore Well Regulations › Article 1 - General › Section 1740.4 - Incorporation by Reference

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
Any documents or part therein incorporated by reference
						herein are a part of this regulation as though set out in
						full.
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 1.1 - Offshore Well Regulations › Article 1 - General › Section 1740.5 - Approval

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
Written approval of the Supervisor is required prior to
						commencing drilling, reworking, injection, plugging, or abandonment operations.
						Temporary approval to commence such operations, however, may be granted by the
						Supervisor or his or her representative when such operations are necessary to
						avert a threat to life, health, property, or natural resources, or when
						approved operations are in progress and newly discovered well condition are
						such that immediate corrective or abandonment operations are desirable. Such
						temporary approval shall be granted only after the operator has provided the
						Division with all information pertaining to the condition of the well,
						including but not limited to, geological, mechanical, and the results of tests
						and surveys. Notwithstanding any such temporary approval, the operator shall
						immediately file a written notice of intention to carry out a program
						temporarily approved.
An operator shall act immediately to correct a condition
						which creates a clear and present danger to life, health, property, or natural
						resources and shall immediately notify the Division of the condition and the
						action taken to correct it.
1.
						Amendment filed 4-1-76; effective thirtieth day thereafter (Register 76, No.
						14).
2. Change without regulatory effect amending section filed
						9-3-96 pursuant to section
						100, title 1, California Code of
						Regulations (Register 96, No. 36).
3. Change without regulatory
						effect amending section filed 12-26-2006 pursuant to section
						100, title 1, California Code of
						Regulations (Register 2006, No. 52).
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 1.1 - Offshore Well Regulations › Article 3 - Regulations › Section 1742 - Well Identification

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
(a) The number or designation, which includes
					 the lease name when used, by which a well shall be known is subject to the
					 approval of the Supervisor and shall not be changed without the written consent
					 of the Supervisor.
(b)
					 Identification of wells. The well designation shall be affixed to the wellhead
					 or guard rail of each completed well. Wells completed from two or more zones
					 shall have the zones individually identified at the wellhead. The Supervisor
					 may approve existing well identification methods if they substantially comply
					 with the intent of this section. Identifying signs shall be maintained in a
					 legible condition.
(c) Platforms,
					 islands, or other fixed structures shall be identified at two diagonal corners
					 of the platform or structure by a sign with letters and figures not less than
					 12 inches in height with the following information: the platform or structure
					 designation, the name of lease operator, and the lease designation. The
					 Supervisor may approve abbreviations.
(d) Non-fixed platforms or structures shall
					 be identified by two (2) signs with letters and figures not less than 12 inches
					 in height affixed to opposite sides of the derrick to be visible from off the
					 vessel with the following information: the name of the operator and the lease
					 designation.
1. Change
						without regulatory effect amending section filed 12-26-2006 pursuant to section
						100, title 1, California Code of
						Regulations (Register 2006, No. 52).