| (iii) designed for the permitted maximum allowable
operating pressure on the hydrocarbon side of the well; and has an
internal diameter of less than or equal to two inches; and an attendant
is posted at the well site to provide immediate manual shut-in when
in use.
(D) Fresh water piping designed for the permitted maximum
allowable operating pressure on the hydrocarbon side of the well and
with an internal diameter of less than or equal to two inches is exempt
from the requirement that an emergency shutdown valve be located on
the wellhead or separated from the wellhead by a spool no longer than
six feet.
(4) Overfill detection and automatic shut-in methods.
(A) The requirements of this paragraph shall not apply
to an underground hydrocarbon storage facility storing only crude
oil.
(B) The requirements of this paragraph shall not apply
to a storage well that is out of service and disconnected from surface
piping until the well is reconnected for hydrocarbon storage.
(C) Within one year of the effective date of this section,
each storage cavern shall have at least two of the following redundant
devices or methods in operation:
(i) a safety casing or annular tubing string filled
with a non-volatile fluid and equipped with a pressure sensor switch
set to automatically close all emergency shutdown valves in response
to a preset pressure;
(ii) a preset pressure sensor switch or transducer
on the brine piping that is set to automatically close all emergency
shutdown valves in response to a preset pressure. This pressure sensor
or transducer may be used in conjunction with weep hole(s) on a safety
string that is concentric with the brine string, or in conjunction
with weep hole(s) on the brine string;
(iii) a device on the brine string or brine piping
that detects hydrocarbon in the brine by physical or chemical characteristics
and that is set to automatically close all emergency shutdown valves
in response to hydrocarbon detection;
(iv) an instrument that detects a rapid increase in
the brine flow rate indicative of hydrocarbon in the brine and that
is set to automatically close all emergency shutdown valves in response
to a preset flow rate or differential flow rate; or
(v) an alternate device or method approved by the Commission
or its designee.
(5) Leak detectors.
(A) The provisions of subparagraphs (B) - (D) of this
paragraph shall not apply to underground hydrocarbon storage facilities
storing only crude oil.
(B) A leak detector shall be installed and in operation
at the wellhead of each hydrocarbon storage well and at each process
and transfer area and each surface vessel area that contains liquid
or liquefied hydrocarbons. These leak detectors shall be integrated
with the warning system required in paragraph (13)(A) of this subsection.
(C) Leak detectors shall be installed and in operation
at four locations that are evenly spaced around the perimeter of the
brine pit(s).
(D) Leak detectors shall be tested twice each calendar
year at intervals not to exceed 7 1/2 months and, when defective,
repaired or replaced within 10 days.
(6) Brine system gas vapor control.
(A) The provisions of this paragraph shall not apply
to underground hydrocarbon storage facilities storing only crude oil.
(B) Gas vapor control devices shall be installed and
in operation at each brine pit system to ignite or capture hydrocarbon
vapors that are heavier than air. Control devices shall consist of
at least one of the following:
(i) a flare on the brine system upstream from the brine
discharge point;
(ii) a hydrocarbon liquid knockout vessel and degasifier;
(iii) pilot lights on the berm of each brine pit; or
(iv) an alternative method designed to provide a reliable,
localized point of ignition to prevent the formation of a vapor cloud.
(C) Brine system gas vapor control systems shall be
inspected twice each calendar year at intervals not to exceed 7 1/2
months.
(7) Fire detection devices or methods and fire control
systems.
(A) Fire detection devices or methods shall be installed
and in operation at all process and transfer areas. Fire detection
devices or methods specified in this paragraph shall be integrated
with the warning system required in paragraph (13)(A) of this subsection.
Fire detection shall consist of at least one of the following:
(i) fire detectors;
(ii) heat sensors, including meltdown and fused devices;
or
(iii) camera surveillance at facilities that are attended
at an on-site control room 24 hours per day.
(B) Fire detectors shall be tested twice each calendar
year at intervals not to exceed 7 1/2 months and, when defective,
repaired or replaced within 10 days.
(C) Within three years of the effective date of this
section, each storage wellhead in active storage service shall have
fire suppression capability designed to aid in personnel rescue and
for equipment protection and cooling. Within one year of the effective
date of this section, the operator may request an exception to the
schedule or fire suppression requirement of this subparagraph and
propose an alternative schedule or means of protection from wellhead
fire for approval of the Commission or its designee.
(8) Emergency response plan. Each storage facility
shall submit to the Commission a written emergency response plan.
The plan shall address spills and releases, fires, fire suppression
capability, explosions, loss of electricity, and loss of telecommunication
services. The plan shall describe the storage facility's emergency
response communication system, procedures for coordination of emergency
communication and response activities with local emergency planning
committees and other local authorities, use of warning systems, procedures
for citizen and employee emergency notification and evacuation, and
employee training. The initial plan must be designed based upon the
existing safety measures at the facility. The plan shall be updated
as changes in safety features at the facility occur, or as the Commission
or its designee requires. The plan shall include a plat of the facility
that shows the location of wells, processing areas, loading racks,
brine pits, and other significant features at the site. A copy of
the plan shall be provided to the local emergency response planning
committee and to any other local governmental entity that submits
a written request for a copy of the plan to the operator. Copies of
the plan shall also be available at the storage facility and at the
company headquarters.
(9) Notification of emergency or uncontrolled release.
(A) Emergency response personnel. Each operator shall
notify the county sheriff's office, the county emergency management
coordinator, and any other appropriate public officials, which are
identified in the emergency response plan, of any emergency that could
endanger nearby residents or property. Such emergencies include, but
are not limited to, an uncontrolled release of hydrocarbons from a
storage well, or a leak or fire at any area of the storage facility.
The operator shall give notice as soon as practicable following the
discovery of the emergency. At the time of the notice, the operator
shall report an assessment of the potential threat to the public.
(B) Commission. The operator shall report to the appropriate
Commission district office as soon as practicable any emergency, significant
loss of fluids, significant mechanical failure, or other problem that
increases the potential for an uncontrolled release. The operator
shall file with the Commission within 30 days of the incident a written
report on the root cause of the incident. The operator shall file
with the Commission within 90 days of the incident a written report
that describes the operational changes, if any, that have been or
will be implemented to reduce the likelihood of a recurrence of a
similar incident. An operator may request that the Commission grant,
for good cause, a reasonable amount of additional time to file a written
report on the root cause of the incident.
(10) Public education. Each facility operator shall
establish a continuing educational program to inform residents within
a one-mile radius of a hydrocarbon storage facility of emergency notification
and evacuation procedures.
(11) Annual emergency drill. Annually, each operator
shall conduct a drill that tests response to a simulated emergency.
Written notice of the drill shall be provided to the appropriate Commission
district office, the county emergency management coordinator, and
the county sheriff's office at least seven days prior to the drill.
Local emergency response authorities shall be invited to participate
in all such drills. The operator shall file a written evaluation of
the drill and plans for improvements with the appropriate district
office and the county emergency management coordinator within 30 days
after the date of the drill.
Cont'd... |
