A.
Notification of Work. The
owner or operator shall notify the Department of substantial modifications,
rehabilitation, and new construction including, but not limited to, the
installation of new tanks and tank floors, tank repairs, the construction of
new secondary containment, new dikes, and new dike floor liners prior to
implementation, and excavations within 10 feet of underground piping. The
designs must be signed and sealed by a State of Maine licensed professional
engineer or an engineer otherwise working in compliance with Maine's
professional regulation statutes.
B.
Aboveground Oil Storage
Tanks.
(1) New Tanks. Any new
aboveground oil storage tank added to an existing terminal must meet the rules
and construction standards of Section (7)(B) of this Chapter. A new tank may
vary from the spacing requirements if an alternate fire plan is approved by the
State Fire Marshal's Office and the local fire suppression agency.
(2) Reuse of Tanks. Existing aboveground oil
storage tanks that have been closed may be reused only if the following
conditions are met:
(a) The existing tank must
have an ASME code stamp, API nameplate, or UL label; and
(b) Satisfactory documentation must be
provided to the Department that the tank has been inspected by a qualified
State of Maine licensed professional engineer or an engineer otherwise working
in compliance with Maine's professional regulation statutes and found to meet
the specifications of API 650. The documentation must be signed and sealed by
the professional engineer that conducted the inspection.
(3) Corrosion Protection. All existing
aboveground oil storage tanks must have a cathodic protection system for any
portion of the tank in contact with soil or backfill, in accordance with API RP
651, API 650, and API 653 or NACE SP0169, unless a cathodic protection
assessment as described in Section (2) of this Chapter indicates that the
corrosion rate will not reduce the floor thickness below the minimum allowed in
API 653 before the next required internal inspection date. The cathodic
protection system must be installed when a release prevention barrier is
installed. The owner or operator may propose alternate corrosion protection
measures addressed in API 651 other than cathodic protection for review and
approval by the Department, provided the methods are based on good engineering
principles and current industry practice.
Note: Impressed current cathodic protection systems are
recommended for double bottom tanks.
(4) Painting. The exterior tank shell on
existing aboveground oil storage tanks must be painted and maintained in good
condition to prevent excessive rusting and or corrosion to the exterior of the
tank. Tank painting must be in accordance with nationally recognized industry
standards, such as the SSPC publication Painting Manual, Volume 1, Good
Painting Practice. Insulated tanks are exempt from this
requirement.
(5) Upgrade and Repair
of Tanks. If an aboveground oil storage tank inspection reveals a discharge,
excessive corrosion, excessive tank settlement, or any other deficiency which
could result in a discharge, the tank must be repaired to standards equal to or
better than the standards of original construction.
(a) Unacceptable levels of corrosion and tank
settlement are as defined in API RP 651, API 650, and API
653.
(b) All riveted and
bolted tanks must have all seams sealed, including rivets and bolts on the
bottom and first course of shell plates. Heated oil tanks storing #6 oil or
asphalt are exempt from this requirement.
(i)
An oil terminal owner or operator shall notify the Department within 3 days of
discovery of a weep. A weep is defined as a film or stain that travels down the
tank one complete ring from the rivets, bolts, or seams of a riveted or bolted
aboveground oil storage tank. The notification must identify the tank and the
location of the weep as it appears on the tank. Within 14 days of discovery of
the weep, the oil terminal facility owner or operator shall either drain the
tank below the level of the weep or propose an alternate method for controlling
the weep acceptable to the Department prior to the weep being properly
repaired.
(ii) A weep which comes
in contact with the ground surface must be reported to the Department within
two hours of its discovery. The oil terminal owner or operator shall drain the
tank below the level of the weep within 14 days of discovery. The tank may not
be filled above the level of the weep until the Department has received a
report from the terminal owner or operator demonstrating that the weep has been
properly repaired.
(c)
Tank liners are not an acceptable form of tank bottom repair unless provisions
are made for leak detection between the liner and the repaired steel
bottom.
(6) Release
Prevention for Tank Bottoms. Release Prevention Barriers (RPB) with leak
detection must be provided for all active field constructed tank bottoms. Tanks
used for asphalt and #6 fuel oil are exempt from the requirement for an RPB.
(a) An RPB may include a steel double bottom,
a synthetic liner, a geosynthetic clay liner, a clay liner or existing soils
under the tank provided they meet the standard in Section (8)(B)(6)(b) below,
or such system as the Commissioner may determine provides the same protection
from oil migration due to leakage and equivalent leak detection.
(b) Engineered clay or an existing soil liner
under a tank may serve as an RPB if the engineered clay is at least 12 inches
thick or the existing soil layer is at least 24 inches thick and meets the
following water permeability standards:
Gasoline, ethanol
|
1 x 10-6
cm/sec
|
Mid Distillates
|
1 x 10-5
cm/sec
|
Crude Oil
|
1 x 10-5
cm/sec
|
#4, #5 Fuel Oils
|
1 x 10-4
cm/sec
|
Permeability of clay or existing soil RPB's must be
determined by a Maine licensed professional engineer or licensed geologist
using a method capable of testing both horizontal and vertical permeabilities.
A soil survey plan, test method, testing location and test protocol must be
submitted to the Department for approval.
(c) All tanks except those storing asphalt
and #6 fuel oil must be fitted with leak detection upon installation of an RPB.
Acceptable methods of leak detection are shown in API 650.
Tanks using existing soil liners must have leak detection comprised of
permeable sand or gravel of adequate thickness with collection pipes so that a
leak can be detected before passing through the existing soil liner, or such
other system as the Department may find acceptable. The Department considers
criteria such as speed of detection and reliability for both the system and the
leak detection method, as well as service life in evaluating and approving an
alternate method.
C.
Piping, Valves and Pumps.
(1) All new piping runs added to, or
replacing, existing runs at an existing facility must be constructed in
accordance with the requirements of Sections (7)(C)(1) and (7)(C)(4) of this
Chapter. For purposes of this Section, "replacing" means removal and
installation of 25 or more feet of the new piping run.
(2) Underground Piping. All existing
underground piping must be surveyed and shown on a site plan. The plan must
clearly show the location, material, size and estimated burial depth of all
underground piping.
(3)
Identification. All aboveground piping at facilities that handle multiple types
of products must be marked or labeled to clearly identify the oil product
contained in the piping. All fill ports (into tanks or trucks) must be color
coded or labeled as specified in API 1637.
(4) Pipe Supports. Aboveground piping must be
adequately supported and protected from physical damage caused by freezing,
frost heaving, vehicular traffic, and any other reasonably foreseeable
potential cause of damage.
(5)
Pressure Relief. Pressure relief valves or an alternate pressure venting
procedure must be provided on piping that could be blocked in and filled with
oil.
(6) Corrosion Protection.
Aboveground piping must be painted or coated to prevent corrosion. Underground
piping must be cathodically protected in accordance with NACE
SP0285.
(7) Tank Valves.
Each connection to an aboveground oil storage tank through which liquid can
normally flow must be provided with an NFPA 30 approved valve located as close
as practical to the shell of the tank. The tank shell valve must be kept in the
closed position when not in use, except at a staffed facility equipped with a
functional continuous tank level monitoring system. In addition, a normally
closed automatic valve must be installed immediately downstream of the shell
valve on tanks serving a loading rack at unstaffed facilities. Tanks used
exclusively for storing asphalt are exempt from this requirement.
(8) Impact Protection. Piping must have
adequate protective guards where vehicular impact or other physical impact is
possible.
(9) Pump Leaks. Pumps
must be equipped with secondary containment to catch leaks from bearings,
packings and seals.
D.
Tank Secondary Containment.
(1)
All new, reconstructed, or relocated tanks installed in a new diked area at an
existing facility must meet the requirements of Section (7)(D) of this
Chapter.
(2) A new tank in an
existing diked area must have secondary containment with leak detection for the
tank bottom. This may be accomplished through use of a double bottom tank or by
providing a new tank base pad that meets the permeability standards of Section
(7)(D)(3) of this Chapter. The remainder of the diked area must meet the
requirements of Section (8)(D)(5) below.
(3) Capacity of Spill Containment Dikes. All
existing oil terminal facilities must meet the requirements of Section
(7)(D)(1) of this Chapter.
(4) Dike
Configuration. The standards of the NFPA 30 govern dike
configuration for existing facilities as far as practical.
(5) Dike Impermeability. The base and walls
of a diked area surrounding an aboveground storage tank must be designed,
constructed, and maintained in a condition that prevents any release of oil
within the diked area from reaching a surface water body within 72 hours, or
ground water within 72 hours as specified below in (a)(iii).
(a) A site assessment is required under the
following conditions:
(i) When any previous
release within a diked area has reached surface water within 72 hours of the
release; or
(ii) When the
documented dike base and walls soil type, permeability, and the distance from
the diked area to the nearest downgradient surface water body is less than
indicated in the table below:
Soil Type
|
Permeability in centimeters per
second
|
Distance (feet)
|
Clay, silt, silt and clay
|
<5 x 10-4
|
N/A
|
Silty sand
|
<4 x 10-3
|
13
|
Clean find sand
|
<1 x 10-2
|
28
|
Clean medium sand
|
<5 x 10-2
|
45
|
Clean course sand
|
<2 x 10-1
|
72
|
Sand and gravel
|
<3 x 10-1
|
101
|
Clean medium gravel
|
<1.4
|
246
|
Shale
|
<5 x 10-6
|
6
|
Sandstone
|
<2 x 10-3
|
11
|
Fractured rock sites require a site assessment;
and
(iii) When any release
within a diked area has reached ground water more than 30 feet horizontally
outside of the diked area within 72 hours.
(b) If the site assessment indicates that a
release of the specific oil within the diked area will not be prevented from
reaching surface water, or ground water as specified in Section
(8)(D)(5)(a)(iii), within 72 hours, the diked area must be improved to meet
this requirement within one year of the site assessment.
(c) The detailed design of new or modified
secondary containment dikes must be signed and sealed by a State of Maine
licensed professional engineer or an engineer otherwise working in compliance
with Maine's professional regulation statutes.
(6) Valve Access. Tank shut-off valves must
be accessible and operable during a 24-hour storm, 100-year precipitation event
and all operating conditions.
(7)
Dike Stairways. Permanent fixed stairways must be provided for access to diked
areas to prevent degradation of dike walls.
E.
Leak Monitoring and
Detection.
(1) The Department may
require monitoring wells and leak detection devices at existing facilities
known or reasonably suspected to be a source of contamination.
(2) Existing monitoring wells must be checked
for free phase product and depth to ground water annually or as directed by the
Department as a licensing requirement of oil terminal facilities.
(3) Monitoring wells must be designed and
constructed as described in Appendix A. New monitoring wells must be located to
avoid penetrations in any diked area liner. Any ground water monitoring well in
the floor of a diked area containing active tanks and piping must be designed
and constructed in such a way that the well does not become a conduit for
contaminants to move to ground water or surface water in the event of a
discharge.
F.
Existing Tank Truck and Tank Car Loading and Unloading Spill
Containment.
(1) Except for facilities
handling only asphalt, tank truck loading and unloading areas must be provided
with impervious secondary containment that is designed, constructed, and
maintained to contain spills in amounts up to the volume of the largest
compartment of any tank truck loaded or unloaded at the facility. These
secondary containment systems must be designed and constructed to prevent the
collection of storm water runoff and must be connected to either a slop tank
for removal and disposal or to an oil water separator.
(2) Except for facilities handling only
asphalt and #6 oil, tank car loading and unloading areas must be equipped with
a device that automatically stops the flow of the liquid into the tank car when
the liquid level in the tank car reaches 95% of capacity. The loading and
unloading areas must also be provided with impervious secondary containment
designed, constructed and maintained to prevent a discharge from coming in
contact with soils and ballast associated with the rail line. The secondary
containment must be designed to prevent the collection of storm water runoff
and must be connected to either a slop tank for removal and disposal or to an
oil water separator. Storm water drainage from facilities handling only #6 oil
and asphalt must be connected to a slop tank for removal and disposal or an oil
water separator.
G.
Reopening a Closed Facility. An oil terminal facility that closed
or underwent facility closure must meet the standards for existing facilities
if reopening within 10 years of the closure date. Closure date is the date when
the facility last operated as a licensed oil terminal facility. Any facility
reopening after a closure of more than 10 years must meet the standards for a
new facility, including the siting standards in Section (6) of this
Chapter.
H.
Other
Requirements. All existing oil terminal facilities must meet the
requirements of Sections (7)(E), (7)(F) (1)-(4), (7)(G), (7)(H), (7)(I) and
(7)(K) of this Chapter.
I.
Shop-Fabricated Tanks.
(1) New
shop-fabricated tanks must meet the requirements of Section (7)(J) below. New
tanks may vary from the spacing requirements if an alternate fire plan is
approved by the State Fire Marshal's Office and local fire suppression
agency.