Section 3111F — ELECTRICAL SYSTEMS

This section provides minimum standards for electrical systems at marine oil terminals.

Electrical systems include the incoming electrical service and components, the electrical distribution system, branch circuit cables and the connections, including, but not limited to: 1. Lighting, for operations, security and navigation 2. Controls for mechanical and electrical equipment 3. Supervision and instrumentation systems for mechanical and electrical equipment 4. Grounding and bonding 5. Corrosion protection through cathodic protection 6. Communications and data handling systems 7. Fire detection systems 8. Fire alarm systems 9. Emergency shutdown systems (ESD)

All electrical systems shall conform to API RP 540 [11.1] and the California Electrical Code [11.2].

See Section 3101F.3 for definitions of “new” (N) and “existing” (E).

Area classifications shall be determined in accordance with API RP 500 [11.3], API RP 540 [11.1] and Articles 500, 501, 504, 505 and 515 of the California Electrical Code [11.2]. A marine oil terminal shall have a current set of scaled plan drawings, with clearly designated areas showing the hazard class, division and group. The plan view shall be supple- mented with sections, elevations and details to clearly delineate the area classification at all elevations starting from low water level. The drawings shall be certified by a professional electrical engineer. The plans shall be reviewed and revised when modifications to the structure, product or equipment change hazardous area identifications or boundaries.

All electrical equipment, cables and conductors shall be clearly identified by means of tags, plates, color coding or other effective means to facilitate troubleshooting and improve safety, and shall conform to the identification carried out for the adjacent on-shore facilities (N). Topics for such identification are found in Articles 110, 200, 210, 230, 384, 480 and 504 of the Cali- fornia Electrical Code [11.2]. Existing electrical equipment (E) shall be tagged.

Where identification is necessary for the proper and safe operation of the equipment, the marking shall be clearly visible and illumi- nated (N/E). A coded identification system shall apply to all circuits, carrying low or high voltage power, control, supervisory or communication (N).

Purged or pressurized enclosures shall be capable of preventing the entry of combustible gases into such spaces, in accordance with NFPA 496 [11.4]. Special emphasis shall be placed on reliability and ease of operation. The pressurizing equipment shall be electrically monitored and alarms shall be provided to indicate failure of the pressurizing or purging systems.

Pressurized control rooms shall conform to Chapter 7 of NFPA 496 [11.4].

Where critical circuits are used for spill prevention, fire control or life safety, an alternative service derived from a separate source and conduit system, shall be located at a safe distance from the main power service. A separate feeder from a double-ended substation or other source backed up by emergency generators will meet this requirement. A stored energy emergency power system (SEEPS) shall be provided for control and supervisory circuits associated with ESD systems (N), see Section 3111F.5.1. 1. Electrical, instrument and control systems used to activate equipment needed to control a fire or mitigate its consequences shall be protected from fire and remain operable for 15 minutes in a 2000°F fire, unless designed to fail-safe during fire expo- sure. The temperature around these critical components shall not exceed 200°F during 15 minutes of fire exposure (N). 2. Wiring in fireproofed conduits shall be derated 15 percent to account for heat buildup during normal operation. Type MI (mineral insulated, metal sheathed per the California Electrical Code [11.2]) cables may be used in lieu of fireproofing of wiring (N). 3. Emergency cables and conductors shall be located where they are protected from damage caused by traffic, corrosion or other sources (N). 4. Allowance shall be made for electrical faults, overvoltages and other abnormalities (N).

Where solid state motor controls are used for starting and speed control, corrective measures shall be incorporated for mitigating the possible generation of harmonic currents that may affect the ESD or other critical systems (N).

3111F.5.1 Emergency power systems. Emergency power systems shall be installed (N) and maintained (N/E) per NFPA 110 [11.5]. This does not include stored energy systems. Stored energy emergency power systems (SEEPS) shall be installed (N) when necessary to maintain continuous uninterruptable power to critical systems. SEEPS shall be installed (N) and maintained (N/E) per NFPA 111

[11.6].

1. All electrical equipment shall be effectively grounded as per Article 250 of the California Electrical Code [11.2]. All noncurrent carrying metallic equipment, structures, piping and other elements shall also be effectively grounded.

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2. Grounding shall be considered in any active corrosion protection system for on-shore piping, submerged support structures or other systems. Insulation barriers, including flanges or nonconducting hoses shall be used to isolate cathodic protection systems from other electrical/static sources. None of these systems shall be compromised by grounding or bonding arrange- ments that may interconnect the corrosion protection systems or interfere with them in any way that would reduce their effectiveness.

3. Bonding of vessels to the MOT structure is not permitted. 4. Whenever flanges of pipelines with cathodic protection are to be opened for repair or other work, the flanges shall be bonded prior to separation. 5. Direct wiring to ground shall be provided from all towers, loading arms or other high structures that are susceptible to lightning surges or strikes.

All electrical systems and components shall conform to National Electrical Manufacturers Asso- ciation (NEMA) standards or be certified by a Nationally Recognized Testing Laboratory (NRTL).

3111F.8.1 Illumination Locations. At a minimum, MOTs shall provide fixed lighting (or luminaires) that illuminates the following

areas:

1. Transfer connection points on the MOT 2. Transfer connection points on any barge moored at the MOT that may transfer oil 3. Transfer operations work areas on the MOT 4. Transfer operations work areas on any barge moored at the MOT that may transfer oil 5. Areas defined in Sections 17.4 and 24.6.4 of ISGOTT [11.7], as appropriate

Lighting shall be located or shielded so as not to mislead or otherwise interfere with off-site areas as governed by federal, state and local agency requirements.

3111F.8.2 Illumination Levels. The minimum illumination levels shall be as follows:

1. 5.0 footcandles (54 lux) at transfer connection points 2. 1.0 footcandle (11 lux) in transfer operations work and other areas

Where the illumination appears to the Division to be inadequate, the Division may require verification by instrument of the levels of illumination. The illumination levels shall be verified by measurement at the locations defined in Section 3111F.8.1, if required. All measurements shall be taken on a horizontal plane, 3 feet above the MOT and barge deck or walking surface (33 CFR 154.570 (b) [11.8]).

3111F.8.3 Emergency Power for Illumination (N). In the event of power supply failure, the emergency power system (Section 3111F.5.1) shall automatically illuminate all of the areas defined in Section 3111F.8.1, and fire pump, hydrant, monitor, foam and hose connection points on the MOT. The emergency power system shall provide power for a duration of not less than 60 minutes at a level of not less than an average of 0.5 footcandle (5.5 lux).

3111F.9.1 Communication systems (N/E). Communications systems shall comply with 2 CCR 2370 [11.7] and Section 6 of OCIMF “Guide on Marine Terminal Fire Protection and Emergency Evacuation” [11.9].

3111F.9.2 Overfill monitoring and controls (N/E). Overfill protection systems shall conform to Appendix C of API Standard 2350

[11.10]. These systems shall be tested before each transfer operation or monthly, whichever is less frequent. Where vessel or barge overfill sensors and alarms are provided, they shall comply with 33 CFR 154.2102 [11.11].

All sumps shall be provided with level sensing devices to initiate an alarm to alert the operator at the approach of a high level condition. A second alarm shall be initiated at a high-high level to alert the operator. Unless gravity drainage is provided, sumps must have an automatic pump, programmed to start at a predetermined safe level.

3111F.9.3 Monitoring systems (N/E). All monitoring systems and instrumentation such as, but not limited to: velocity monitoring systems, tension monitoring systems, anemometers and current meters, shall be installed, maintained and calibrated per the manu- facturer’s recommendations. Specifications shall be retained. The latest records shall be readily accessible to the Division.

CPS operating, testing and maintenance criteria for underwater structures shall conform to UFC 3-570-01 [11.12]. Structure-to-electrolyte potential measurements shall be taken at least annually. CPS operating, test- ing and maintenance criteria for buried and submerged pipelines shall conform to API 570 [11.13].

All electrical insulating and isolating devices for protection against static, stray and impressed currents shall be tested in accordance with 2 CCR 2341 and 2380 [11.7].

CPS design criteria and location of anodes, electrical leads and rectifiers shall be documented and retained. Periodic CPS measure- ments, test data and inspection findings shall be retained.

Electrical systems shall have a seismic assessment per Section 3104F.5. For strength evaluation of supports and attachments, see Section 3107F.7.

[11.1] American Petroleum Institute (API), 1999, API Recommended Practice 540 (R2004) (API RP 540), “Electrical Installations in Petroleum Processing Plants,” 4th ed., Washington, D.C.

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[11.2] California Code of Regulations (CCR), Title 24, Part 3, California Electrical Code.

[11.3] American Petroleum Institute (API), 2012 (Errata January 2014), API Recommended Practice 500 (API RP 500), “Recom- mended Practice for Classification of Locations for Electrical Installations at Petroleum Facilities Classified as Class I, Division 1 and Division 2,” 3rd ed., Washington, D.C.

[11.4] National Fire Protection Association (NFPA), 2012, NFPA 496, “Standard for Purged and Pressurized Enclosures for Electrical Equipment,” 2013 ed., Quincy, MA.

[11.5] National Fire Protection Association (NFPA), NFPA 110, “Standard for Emergency and Standby Power Systems,” Quincy, MA. For edition, see California Code of Regulations (CCR), Title 24, Part 2, Chapter 35 – Referenced Standards.

[11.6] National Fire Protection Association (NFPA), NFPA 111, “Standard on Stored Electrical Energy Emergency and Standby Power Systems,” Quincy, MA. For edition, see California Code of Regulations (CCR), Title 24, Part 2, Chapter 35 – Referenced Standards.

[11.7] International Chamber of Shipping (ICS), Oil Companies International Marine Forum (OCIMF), International Association of Ports and Harbors (IAPH), 2006, “International Safety Guide for Oil Tankers and Terminals (ISGOTT),” 5th ed., Witherby, London.

[11.8] Code of Federal Regulations (CFR), Title 33, Section 154.570 – Lighting (33 CFR 154.570)

[11.9] Oil Companies International Marine Forum (OCIMF), 1987, “Guide on Marine Terminal Fire Protection and Emergency Evacu- ation,” 1st ed., Witherby, London.

[11.10] American Petroleum Institute (API), 2012, API Standard 2350, “Overfill Protection for Storage Tanks in Petroleum Facilities,” 4th ed., Washington, D.C.

[11.11] Code of Federal Regulations (CFR), Title 33, Section 154.2102 – Facility Requirements for Vessel Liquid Overfill Protection (33 CFR 154.2102)

[11.12] Department of Defense, 28 November 2016, Unified Facilities Criteria (UFC) 3-570-01, “Cathodic Protection,” Washington, D.C.

[11.13] American Petroleum Institute (API), 2009, API 570, “Piping Inspection Code: In-service Inspection, Repair, and Alteration of Piping Systems,” 3rd ed., Washington, D.C.

Authority: Sections 8750 through 8760, Public Resources Code.

Reference: Sections 8750, 8751, 8755 and 8757, Public Resources Code.

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Division 12