oil spill response plan - paramount pipeline llc · oil spill response plan pppm-osrp date:...

Oil Spill Response Plan PPPM-OSRP

Date: 10/30/2019 Rev. 0 Page: 1

Prepared by: Approved by:

J Ewart C Syre

NOTICE: The information contained herein Is the confidential property of Paramount Pipeline LLC Companies, unless another source is indicated. This material is subject to return on demand and must not be disclosed or reproduced without prior written consent by a duly authorized representative of Paramount Pipeline LLC.

OIL SPILL RESPONSE PLAN

Prepared for:

Paramount Pipeline, LLC 14700 Downey Avenue, Suite 100

Paramount, CA 90723 Phone: 562-531-2060

This Plan satisfied the following regulations:

• DOT/PHSMA 49 CFR Part 194 Cross Reference

• California Code of Regulations 22 CCR §66264.52 and §66264.53

• California Code of Regulations, Title 14, Division 1, Subdivision 4, Chapter 3, Subchapter 3, Paragraphs 815-819


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0 FOREWORD ................................................................................................................ 5

0.1 ACKNOWLEDGEMENT AND APPROVAL ..................................................................... 5 0.2 FACILITY EXECUTABILITY STATEMENT ..................................................................... 6 0.3 CALIFORNIA CERTIFICATE OF FINANICAL RESPONSIBILITY ............................... 7 0.4 OPERATOR’S STATEMENT – SIGNIFICANT & SUBSTANTIAL HARM &

CERTIFICATION OF RESPNOSE RESOURCES .......................................................................... 64 0.5 REVISION RECORD ........................................................................................................ 65 0.6 DISTRIBUTION LIST ........................................................................................................ 66

1 INTRODUCTION AND PLAN CONTENT ................................................................ 67

1.1 PLAN PURPOSE AND OBJECTIVES ............................................................................ 67 1.2 SCOPE OF PLAN .............................................................................................................. 67 1.3 PLAN DISTRIBUTION PROCEDURES ......................................................................... 67 1.4 PLAN REVIEW AND UPDATE PROCEDURES ........................................................... 68 1.5 REGULATORY COMPLIANCE ....................................................................................... 69

2 NOTIFICATION PROCEDURES ............................................................................... 79

2.1 INTERNAL NOTIFICATION ............................................................................................. 79 2.2 EXTERNAL NOTIFICATIONS ......................................................................................... 83

3 INITIAL RESPONSE ACTIONS ................................................................................ 92

3.1 INITIAL RESPONSE ACTIONS ...................................................................................... 92 3.2 DOCUMENTATION OF INITIAL RESPONSE ACTIONS .......................................... 127 3.3 ESTABLISHING COMMAND POSTS, COMMUNICATIONS POSTS, AND

STAGING AREAS CCR§817.02(F)(2)(A-C) ................................................................................... 127 3.4 OIL CONTAINMENT, RECOVERY AND DISPOSAL ................................................ 129 3.5 TEMPORARY STORAGE/DISPOSAL ......................................................................... 133 3.6 SAMPLING ....................................................................................................................... 134 3.7 SAFETY AWARENESS .................................................................................................. 134 3.8 EMERGENCY MEDICAL TREATMENT AND FIRST AID CCR §817.02(F)(4)(B) . 138 3.9 SITE SAFETY AND HEALTH PLAN(S) DEVELOPMENT ......................................... 139 3.10 DRUG AND ALCOHOL TESTING CCR §817.02(C)(5)(D) ........................................ 140

4 RESPONSE TEAMS ................................................................................................ 141

4.1 INTRODUCTION ............................................................................................................. 141 4.2 QUALIFIED INDIVIDUAL ............................................................................................... 141 4.3 LOCAL RESPONSE TEAM ........................................................................................... 142 4.4 SPILL MANAGEMENT TEAM ....................................................................................... 142 4.5 INCIDENT COMMAND SYSTEM .................................................................................. 143 4.6 UNIFIED COMMAND ...................................................................................................... 144 4.7 DISCHARGE CLASSIFICATION .................................................................................. 145 4.8 ICS ROLES AND RESPONSIBILITIES ........................................................................ 148

5 RESPONSE PLANNING ......................................................................................... 153


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5.1 INCIDENT ACTION PLAN.............................................................................................. 153 5.2 SITE SAFETY PLAN ....................................................................................................... 154 5.3 ICS FORMS ...................................................................................................................... 154

6 SPILL IMPACT CONSIDERATIONS ...................................................................... 155

6.1 CRITICAL AREAS TO PROTECT ................................................................................. 155 6.2 ENVIRONMENTAL / SOCIO-ECONOMIC SENSITIVITIES ..................................... 155 6.3 WILDLIFE PROTECTION AND REHABILITATION ................................................... 156 6.4 STAGING AREAS ........................................................................................................... 157 6.5 CONTAINMENT AND RECOVERY OF SPILLED PRODUCT ................................. 158 6.6 SHORELINE DESCRIPTORS AND RESPONSE CONSIDERATIONS .................. 165 6.7 RISK AND HAZARD ANALYSIS ................................................................................... 177 6.8 ALTERNATIVE RESONSE STRATEGIES .................................................................. 180 6.9 ENDANGERED/THREATENED SPECIES LISTING – CALIFORNIA ..................... 181 6.10 ACP FORMS (2019) .......................................................................................................... 181

7 APPENDIX A ............................................................................................................ 182

7.1 INTRODUCTION ............................................................................................................. 182 7.2 RESPONSE CAPABILITY SCENARIOS ..................................................................... 182

8 APPENDIX B ............................................................................................................ 186

8.1 RESPONSE TEAM TRAINING ...................................................................................... 186 8.2 RESPONSE TEAM EXERCISES .................................................................................. 188

9 APPENDIX C ............................................................................................................ 192

9.1 REVIEW OF OSRP IMPLEMENTATION AND ADEQUACY – 49 CFR 194 ........... 192 9.2 REVIEW OF OPERATIONAL RESPONSE – 49 CFR PART 195 ............................ 193 9.3 PURPOSE OF REVIEW AND EVALUATION .............................................................. 193

10 APPENDIX D ............................................................................................................ 197

10.1 QUALIFIED INDIVIDUAL (QI) NOTIFICATION EXERCISE – INTERNAL

EXERCISE DOCUMENTAITON ...................................................................................................... 198 10.2 RESPONSE TEAM TABLETOP EXERCISE – INTERNAL EXERCISE

DOCUMENTATION ........................................................................................................................... 199 10.3 INTERNAL EXERCISE DOCUMETATION FORM – EQUIPMENT DEPLOYMENT

EXERCISE .......................................................................................................................................... 201 10.4 INTERNAL EXERCISE DOCUMENTATION FORM – SPILL MANAGEMENT TEAM

TABLETOP EXERCISE ..................................................................................................................... 203

11 APPENDIX E ............................................................................................................ 205

11.1 FACILITY RESPONSE EQUIPMENT .......................................................................... 206 11.2 OTHER COMPANY RESOURCES .............................................................................. 206 11.3 CONTRACT RESOURCES ........................................................................................... 206 11.4 COOPERATIVE AND MUTUAL AID RESOURCES .................................................. 206


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11.5 EXPERTS AND CONSULTANTS ................................................................................. 206 11.6 VOLUNTEERS ................................................................................................................. 206 11.7 COMMUNICATIONS ...................................................................................................... 206

12 APPENDIX F ............................................................................................................ 213

12.1 CSFM NO. 1183 (CHEMOIL LINE) APRIL 26TH, 2007 ............................................... 213 12.2 CSFM NO. 1085 (PPC LINE 160) APRIL 16TH, 2010 ................................................. 213 12.3 OTHER PARAMOUNT LINES ....................................................................................... 213 12.4 LAKEWOOD TANK FARM ............................................................................................. 213

13 APPENDIX G............................................................................................................ 213 14 GLOSSARY .............................................................................................................. 214 15 REGULATORY CROSS REFERENCE .................................................................. 228


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0 FOREWORD

0.1 ACKNOWLEDGEMENT AND APPROVAL

ACKNOWLEDGEMENT AND PLAN APPROVAL

The information and procedures in this Plan must be treated as guidelines only. The user should determine to what extent it is practical and advisable to follow them. This decision may involve consideration not discussed in this Plan. The information and procedures contained herein are considered to be accurate as of this date and are consistent with National Contingency Plan (NCP) and applicable Area Contingency Plans (ACP) as detailed in Section 1.5.

CERTIFICATION OF QUALIFIED INDIVIDUAL AND ALTERNATE QUALIFIED INDIVIDUAL

Paramount Pipeline, LLC hereby certifies the individuals identified as Qualified Individual and Alternate Qualified Individual in this Plan have the full authority in accordance with the applicable federal and state regulations and as detailed in this Plan to:

1. Activate and engage in contracting with oil spill removal organization.

2. Act as a liaison with the pre-designated Federal On-Scene Coordinate (OSC), and

3. Obligate funds required to carry out response activities.

Plan Approved:

Date:

10/30/2019


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0.2 FACILITY EXECUTABILITY STATEMENT

Paramount Pipeline, LLC

The below statement, required by California Code of Regulations Title 14, Division 1, subdivision 4, Chapter 3, subchapter 3, §817.02(a)(1)(D), has been signed by an executive within the plan holder's

management. The undersigned has training, knowledge, and experience in the area of oil spill prevention and response, has the authority to fully implement the oil spill contingency plan written within this Facility Response Plan, and will review this Plan for accuracy, feasibility, and executability.

"I certify, to the best of my knowledge and belief, under penalty of perjury under the laws of the State of California, the information contained in this contingency plan is true and correct and the plan is both feasible and executable."

Jeffrey H. Ewart Date

Manager, Pipeline Compliance

Paramount Pipeline, LLC

10/30/2019


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0.3 CALIFORNIA CERTIFICATE OF FINANICAL RESPONSIBILITY


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0.4 OPERATOR’S STATEMENT – SIGNIFICANT & SUBSTANTIAL HARM &

CERTIFICATION OF RESPNOSE RESOURCES

OPERATOR'S STATEMENT - SIGNIFICANT AND SUBSTANTIAL HARM AND CERTIFICATION OF RESPONSE RESOURCES

Facility Name: Paramount Pipeline LLC

Facility Address: 14700 Downey Avenue

Paramount, CA 90723

Is the pipeline greater than 6 and 5/8 inches (168mm) in outside nominal diameter, greater than 10 miles (16 km) in length? And:

Yes X No

1. Has any line section experienced a release greater than 1,000 barrels (159 cu. Bbl) within the previous five years? Or

Yes No X

2. Has any line section experienced two or more reportable releases, as defined in Sec. 195.5, within the previous five years? Or

Yes No X

3. Does any line section contain any electric resistance welded pipe, manufactured prior to 1970 and operates at maximum operating pressure established under Sec. 195.406 that corresponds to stress level greater than 50 percent of the specified minimum yield strength of the pipe? or

Yes No X

4. Is any line located within 5-mile (8 km) radius of potentially affected public drinking water intakes and could reasonably be expected to reach public drinking water intakes? Or

Yes No X

5. Is any line located within a 5-mile (8km) radius of potentially affected environmentally sensitive areas and could reasonably be expected to reach these areas?

Yes X No

Paramount Pipeline LLC hereby certifies to the Pipeline and Hazardous Materials Safety Administration of the Department of Transportation that we have identified and ensured, by contract or by other means, the availability of personnel and equipment to respond, to the maximum extent practicable, to a worst-case discharge.

Signature

Jeffrey H. Ewart (Please Print) Date

Manager, Pipeline Compliance


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0.5 REVISION RECORD

Revision Record

Date Page Number(s) Description of Change(s)

August 2012 New Plan

August 2014 Personal contact information was updated

October 2016 Title, vi, vii, 1-5, 2-2, 2-3 QI information updated

March 21st, 2018 Title, vi, vii, 1-5, 2-2, 2-3 QI information updated

March 21st, 2018 All pages Updated ACP, change of ownership

August 29th, 2019 Title, Foreword, All pages Creation of new tables in foreword, formatting of Plan, update of ICS and ACP

October 30th, 2019 All pages Creation of new Plan ID and approval of new plan


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0.6 DISTRIBUTION LIST

Copy No. Name Role Location

1 (Master)

J. Ewart Incident Commander Paramount Pipeline, LLC 14700 Downey Avenue, Suite 100 Paramount, CA 90723

2 M. Vigliarolo Safety Officer Same as above

3 G. Grimes Public Information Officer Same as above 4 E. Donnette Liaison Officer Same as above 5 G. Dougherty Operations Section Chief Same as above 6 G. Clausen Operations Deputy Section Chief Same as above 7 M. Abrego Operations Same as above 8 K. Gleeson Planning Section Chief Same as above 9 D. Zanotti Deputy Planning Section Chief Same as above

10 G. Pradina Situation Unit Leader Same as above 11 V. Panwar Resource Unit Leader Same as above 12 J. Conrad Documentation Unit Leader Same as above 13 O. Ponce Environmental Unit Leader Same as above 14 G. Aldapa Logistics Section Chief Same as above 15 C. Galbez Service Branch Manager Same as above 16 J. Uriate Support Branch Manager Same as above 17 K. Carlfeldt Communication Leader Same as above 18 D. Papadakis Financial Section Chief Same as above

19 (Electronic)

Melanie Barber Response Plans Officer (PHMSA) U.S. DOT Office of Pipeline Safety 1200 New Jersey Avenue SE-E-22-321 Washington, DC 20590

20 California Department of Fish and Wildlife

Office of Spill Prevention & Response 1700 K Street, Suite 250 Sacramento, CA 95814

21 Spill Management Team

O’Brien’s Response Management Inc.

818 Town & Country Blvd, Suite 200 Houston, TX 77024

NOTE: The Distribution of this Plan is controlled by the Copy Number located on the front cover. The Plan Distribution Procedures provided in Section 1.3 and the Plan Review and Update Procedures provided in Section 1.4 should be followed when making any and all changes.


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1 INTRODUCTION AND PLAN CONTENT

1.1 PLAN PURPOSE AND OBJECTIVES

The purpose of this Oil Spill Response Plan (Plan) is to assist Paramount Pipeline

LLC personnel to prepare for and respond quickly and safely to a discharge

originating from the pipelines and associated facilities. The Plan provides

techniques and guidelines for achieving an efficient, coordinated, and effective

response to a discharge incident, which may occur at the Facility.

The specific objectives of the Plan are to:

• Establish Response Teams, assign individuals to fill the positions on the teams, and define the roles and responsibilities of team members.

• Define notification, activation, and mobilization procedures to be followed when a discharge occurs.

• Define organizational lines of responsibility to be adhered to during a response operation.

• Document equipment, manpower, and other resources available to assist with the response.

• Ensure compliance with the federal, state, and local oil pollution regulations.

• Ensure consistency with the National Contingency Plan and Area Contingency Plan(s) for the area of operation.

1.2 SCOPE OF PLAN

This Plan has been developed in accordance with the regulation published in 49

CFR part 194 and CCR Title 14.

This Plan contains prioritized procedures for Company personnel to mitigate or

prevent any discharge resulting from the operation of the pipeline. A description of

the pipeline's details is presented in Figure 1.1 with additional information provided

in the sections and the appendices.

1.3 PLAN DISTRIBUTION PROCEDURES

The Compliance Coordinator is responsible for maintenance and distribution of the

Plan. Distribution will be handled in the following manner:

• Distribution of the Plan is controlled by the number on the cover page. A distribution list is included in the Foreword to facilitate control.

• Company personnel who may be called upon to provide assistance during discharge response activities will have access to a copy of the plan for their use and training.

• Any person holding a copy of the Plan shall ensure that the copy is transferred to their replacement in the event of reassignment or change in responsibility.


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• Various regulatory agencies will also receive a copy of the Plan. The list of agencies is detailed in the Distribution List located In the Foreword.

1.4 PLAN REVIEW AND UPDATE PROCEDURES

1.4.1 Internal Review and Update

Pipeline Operations will coordinate the following plan review and update

procedures:

• At least once each year, review and make appropriate revisions as required by operational or organizational changes.

• At least once each year, review and make appropriate revisions as required by changes in the names and telephone numbers detailed in Section 2.0.

• Review and make appropriate revisions as required by improved procedures or deficiencies identified during response team tabletop exercises or actual emergency responses.

• Coordinate the word processing, publication, and distribution efforts to complete the revisions and maintain the Plan.

1.4.2 Incorporation of Plan Revisions

Upon receipt of any revisions, the Plan Holder shall:

• Review and insert the revised pages into the Plan.

• Discard the obsolete pages.

• Record this action on the “Revision Record” page in the Foreword.

1.4.3 Federal Agency Review and Revision Requirements

TABLE 1.1

AGENCY TIMING REQUIREMENTS

DOT PHMSA CA OSPR

Timing for Plan Review

For substantial harm facilities, the facilities will review the Plan at least every five years of the most recent date of submission and resubmit changes portions of the Plan.

At least every five (5) years from date of approval.

Timing for submission of significant Plan revisions as detailed in the table below.

Within 30 days of each change that would substantially affect the implementation of the response plan.

Within 24 hours for significant changes (i.e., change in ownership and Financial Responsibility coverage).


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1.4.3.1 DOT/PHMSA — The Facility shall revise and resubmit changes to the

Pipeline Response Plans Officer within days. For substantial harm

facilities, the facilities will review the Plan at least every five years

from the most recent date of submission and resubmit changed

portions of the Plan. For significant and substantial harm facilities, the

facilities will review the Plan at least every five years from the date of

Plan approval and resubmit changed portions of the Plan. If the Plan

is still current, the Agency will accept a letter which serves as the

resubmitted plan for PHMSA to review for completeness.

1.4.3.2 OSPR — Requires notification of significant changes as soon as

possible but at least within 24 hours. A significant change is one that

could affect the timely and adequate oil spilt response, including

changes in financial responsibility coverage.

1.4.3.3 The Facility shall revise and resubmit revised portions of the Plan

for each change that may materially affect the response to a Worst-

Case Discharge, including:

TABLE 1.2

1.5 REGULATORY COMPLIANCE

The development, maintenance, and use of this Plan implements company policy and addresses the following regulatory requirements and guidelines:

• Federal Oil Pollution Act of 1990: U.S. DOT Final Rule for Transportation Related On-shore Facilities (49 CFR part 194).

CONDITIONS REQUIRING CHANGES USCG CA OSPR

A change in ownership and Financial Responsibility coverage. X

A change in regulations. X

Significant changes to the marine facility. X

Deficiencies in oil spill response capability identified during an oil spill or drill. X

A change in the listings of economically important or environmentally sensitive area identified in the applicable ACP in effect six (6) months prior to the plan review.

X

Change in the Facility’s configuration that materially alters the information included in the Plan.

X

Change in the type of oil handled, stored, or transferred that materially alters the required response resources.

X

A change in the name of the Oil Spill Removal Organization (OSRO). X

Material change in capabilities of the Oil Spill Removal Organizations(s) (OSROs) that provide equipment and personnel.

X

Material change in the Facility’s spill prevention and emergency response procedures.

X

Any other changes that materially affect the implementation of the Plan. X


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• California Code of Regulations, Title 14, Division 1, Subdivision 4 Chapter 3. Subchapter 3, paragraphs 815-819.

The response zone has been reviewed for consistency with the following plans:

• National Contingency Plan (NCP)

• U.S. Environmental Protection Agency (Region JX), Regional Contingency Plan.

• USCG/OSPR Los Angeles/Long Beach Area Contingency Plan.


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TABLE 1.3: INFORMATION SUMMARY

GENERAL INFORMATION

Pipeline Name: Paramount Pipeline LLC

OPS Sequence Number: TBD

Operator ID Number: 39837

OSPR FRP:

Owner Name: Physical Address: Mailing Address:

Paramount Pipeline, LLC Paramount Pipeline, LLC

14700 Downey Avenue Suite 100

14700 Downey Avenue Suite 100

Paramount, CA 90723 Paramount, CA 90723

(562) 531-2060 (562) 531-2060

(562) 748-4751 (562) 748-4751

24 Hour Emergency Contact Numbers:

Qualified Individual: Jeffrey Ewart, Manager, Pipeline Compliance

(562) 531-2060 ext. 2751 (Office)

(562) 788-0555 (Mobile) Alternate Qualified Individual: Mohsen Ahmadi, Plant Manager

(562) 531-2060 ext. 2681 (Office)

(562) 577-1413 (Mobile) Alternate Qualified Individual: Reagan Williams

(562) 531-2060 ext. 2851 (Office)

(562) 577-1403 (Mobile)

Telephone and Fax: Additional telephone references, including 24hr numbers for the Facility Owner/Operator are provided in Figure 2.2

Agent for Service of Process:

Jon Benjamin, Esq, Farella Braun + Martel LLP

235 Montgomery Street, 17th Floor

San Francisco, CA 94104

(415) 954-4400

(415) 954-4480

A Certificate of Financial Responsibility (COFR) according to the provisions of Title 14, California Code of Regulations, Section 790-797 has been issued by the State of California Office of Spill Prevention ("OSPR). A copy of the most current COFR is provided in the Foreword.


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PIPELINE LOCATION

States Traversed: California

Counties Traversed: Los Angeles County

PHYSICAL DESCRIPTION - PIPELINES AND LAKEWOOD TANK FARM

General:

All pipelines operated by Paramount Pipeline, LLC in Los Angeles County and the

Lakewood Tank Farm are located within an area 20 miles south end southwest of the

Paramount refinery. All sections of Paramount’s pipelines and, for the purpose of this

Plan, are considered to be within a single Response Zone. The volume of each section

of each pipeline is presented in Appendix B (Worst Case Discharge). Pipeline normal

operating procedures for transferring product to or from a storage tank or pipeline are

in the Paramount Pipeline Operations and Maintenance Manual.

Paramount operates and is responsible for:

• CSFM No. 0051 (Line No.2) – This is a 4inch diameter line located at the Lakewood Tank Farm used to receive JP8 from Line No. 121. This line is 800 feet long. This line is used to receive Jet Fuel from Paramount Refinery.

• CSFM No. 0121 (PP Line 35) - A combination 4-inch, 6-inch, and 8-inch line

connecting the Alt Air Refinery to the Marathon East Hynes facility. This pipeline is also connected to Line No. 2 in a valve vault at Alley and South Street. The pipeline is used primarily for shipping clean products. The pipeline is approximately 4.25 miles long and traverses the cities of Paramount, Lakewood, and Long Beach.

• CSFM No. 1382 (PP Line 4) - This line was purchased from CENCO Refining

Company in August 2002. The active portion of Line 4 starts at the ICTF Junction manifold, through the Long Beach Refinery and ends at a valve box at Downey and Artesia. It is used to transport Crude and Gas Oil between Paramount and Long Beach. The active portion traverses Bellflower, Carson, Long Beach, Port of Long Beach, Los Angeles County, and Port of Los Angeles.

• CSFM No. 0222 (PP Line 3B) - This pipeline consists of 6-inch and 8-inch

pipeline, approximately 2,575 feet long, runs from the ICTF Junction manifold with PP Lines 3 and 4 located to Lease Tankage at KMEP Carson Terminal. The line traverses Los Angeles County and the city of Carson.

• CSFM No. 244 (PP 12” Crude Line) - This is a 12-inch line that extends 3.3 miles

between a valve box near the Lakewood Tank Farm to the Alt Air Refinery. This

line is dedicated for moving crude oil. The pipeline traverses Paramount, Long

Beach, and Lakewood.

• CSFM No. 1150 (PP 12” Crude Line) - This is a 12-inch line that runs from

Marathon East Hynes to a valve box at Alley Street and South Street and then to

the Lakewood Tank Farm. The pipeline is approximately 2,536 ft. long and is used

to transport crude oil to the Alt Air Refinery using the 12” CSFM 244 pipeline.

• CSFM No. 0164 (PP Line GX150) - The active portion of this 8-inch and 12-inch

pipeline runs from the La Paloma Manifold, GX130 connection, to the Avalon

Manifold, GX140 connection. It’s used primarily to transport dark products

between various customers around the Long Beach/Los Angeles Harbors.

• CSFM No. 0165 (PP Line GX140) – The active portion of this 3.93 mile 10-inch

pipeline runs from the Avalon West Valve box to KMEP Carson. It is primary used


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to transport dark products between various customers around the Long Beach/Los

Angeles Harbors. This line also has a 10” and 8” branch line off the GX 140 line

that connects to the Valero Olympic Tank Farm. The line is currently inactive.

• CSFM No. 1166 (PP Line 140) - Line 140 is primarily an 8-inch and 10-inch lateral

off GX140 running 1.026 Miles from the Mauret box to LADWP. It was previously

in black oil but is currently inactive.

• CSFM No. 0166 (PP Line 145) - This is a pipeline consisting of 6-inch, 8-inch, and

10-inch pipelines, approximately 8.64 miles long, which runs from Madison Street

in Carson and terminates at the south side of Alt Air Refinery along Somerset Blvd.

in Paramount. The pipeline traverses Carson, Rancho Dominguez, North Long

Beach, Compton, East Rancho Dominguez, and Paramount. The pipeline is

currently active and handles gasoline, diesel, Jet A, and Naphtha.

• CSFM No. 169 (PP Line GX130) - The active portion of this 5,239 foot 8-inch

pipeline runs from the La Paloma Valve box in the Long Beach Harbor area to the

Neptune Valve box along Harry Bridges. The pipeline is used primarily for

transporting dark products to various customers on the Black Oil System.

• CSFM No. 1085 (PP Line 160) - A combination of 6-inch, 8-inch and 10-inch lines,

approximately 7.02 miles long, traversing Long Beach, Los Angeles County, and

Lakewood, from the Willow valve Manifold to Paramount Pipeline Lakewood Tank

Farm. This line is used for Gas Oil and Crude.

• CSFN No. 0163 (PP Line GX160) – This pipeline runs from the Long Beach

Harbor Area and Avalon Manifold to the Willow Manifold.

• CSFM No. 0534 (PP Line 1) - This is a 6-inch line located at the Lakewood Tank

Farm primarily used for shipping jet fuel to the Marathon East Hynes facility in

Long Beach. It joins Line No. 35 at South Street Valve Box. The line is 800 feet

long.

• CSFM No. 0558 (PP Christian Line) - A short 12-inch pipeline approximately

1,433 feet long laterally connected to the 12-inh crude line at the valve box located

south-east of the East Hynes main entrance gate. This line is located in Long

Beach and is currently inactive.

• CSFM No. 0221 (PP Line 14) - A short 8-inch pipeline approximately 2650 feet

long which connects to PP Line 3 in the Thums vault. This line is located in Long

Beach and is currently inactive.

The Lakewood Tank Farm is located 3.1 miles south of the refinery, The Tank Farm

contains five (5) above ground storage tanks. The Tank Farm is situated between

Downey Avenue to the east, Paramount Boulevard to the west and is approximately

one-quarter mile south of South Street in the City of Lakewood. The area of the Tank

Farm is approximately 4.2 acres with a Maximum Tank Storage capacity of 110,000

barrels. General PPE required at all facilities including: FRC, steel toe boots, hard hat,

and goggles or shatter shields.

As an intrastate common carrier, conforms with the oil pipeline regulations of the

Department of Transportation (49 CFR parts 192, 194, & 195).


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The Facility operates 24/7.

This Plan is written in English and understood by personnel responsible for carrying

out the plan.

Pipelines are inspected and tested in accordance with 49 CFR part 195 and CAL

GOV Code §551010-51019, as applicable.

Pipeline Specifications: The basic specifications of the pipeline are as follows:

Product Type: Gasoline and diesel fuels

Pipe Detail: 6’, 8”, 10” and 12” with various wall thickness

Response Resources: Facility spill mitigation procedures and response guidelines are provided in Section

3.0

for discharges that could result from any of the following scenarios:

o Pipeline rupture/leak;

o Explosion and/or fire;

o Failure of facility piping; and

o Equipment failure (e.g. pumping system failure, relief valve failure,

etc.).

These scenarios could result in the following discharge volume:

RESPONSE ZONE DISCHARGE SCENARIO POTENTIAL OIL

GROUP

DOT/PHMSA

PLANNING

VOLUME

Los Angeles County 3070 3 3070

This worst-case discharge volume is utilized in calculating the planning volume for

response resources. The planning volume is used to determine the necessary on-

water recovery capacity to respond within the three-tiered response times. The

identified oil spill recovery devices should be capable of arriving at the scene of a

discharge within the time specified for the applicable response tier. The tier

requirements for high volume areas are for response in 6 hours (Tier 1), 30 hours (Tier

2), and 54 hours (Tier 3). High volume areas are listed in 49 CFR 194. The tier

requirements for all other areas are for response in 12 hours (Tier 1), 36 hours (Tier

2), and 60 hours (Tier 3). Appendix C of this Plan demonstrates a series of calculations

and planning volume determinations based on guidance provided by the U. S.

Environmental Protection Agency (EPA) in 40 CFR part 112 Final Rule dated July 1,

1994 and the Department of Transportation (DOT) PHMSA regulations in 49 CFR

194.105 dated January 5, 1993. The inclusion of these calculations is for

demonstration of the response planning volumes and response capability necessary

for on-water and on-shore recovery requirements as the result of the discharge

scenarios outlined in the table above.


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Weather Pattern: o Typically, mild temperatures, winter in the upper 60s with lows in the

40s, and summer highs in the 70s and 80s with lows in the 50s with

infrequent heat waves. There frequently are daily low clouds and late

night/early morning fog, and prevailing winds from the northwest.

o Wind speed averages 5-10 knots from a westerly component in the

afternoon and early evening hours, with winds of 17 knots or greater

occurring less than 2% of the time. Santa Ana winds are an

infrequent condition occurring during the fall and winter months.

These are from the northeast and are usually gusty and can attain

speeds of 52 knots.

o Seasonal rains occur during the winter months (December -

February),

o with the summer months being very dry.

Currents in the channels and the harbor increase during periods of higher rainfall due

to runoff from storm water channels.

Look to www.Weather.com for local weather updates including tide and temperature

changes.

Prevention Measures: The pipelines owned, operated or leased by Paramount Pipeline LLC are regularly

hydro tested on a schedule dictated by the California State Fire Marshal. All active

pipelines are hydro tested every 5 years per California Requirements. Testing records

are maintained at the Alt Air Refinery.

The procedures followed during oil transfers in the pipeline system are detailed in

Paramount's Pipeline Operating Manual. Briefly, the pipelines are monitored at both

the sending and receiving ends. Communications during transfers are via telephone

and radio. Pipeline operators at each end of the pipeline are in contact at least once

every 2 hours during transfer operations.

Paramount's pipelines are equipped with both high- and low-pressure sensors that

will automatically shut down the pipeline flow when triggered. Indication of these

alarms is received at the refinery.

Paramount personnel all participate in a drug and alcohol testing program. All new

employees are tested at the time of hiring and all employees are subjected to random

testing at any time following hiring.

Pipeline security is accomplished by fencing all above ground facilities. Most of the

lengths of Paramount's pipelines are underground. Where pipelines cross drainage

ways, the pipeline crossings are fenced or are inaccessible by their placement (i.e.

under bridges). Facilities employ daily perimeter security checks.

http://www.weather.com/


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RESPONSE ZONE INFORMAITON

CALIFORNIA RESPONSE ZONE

Pipeline ID Type of Oil Starting Mile

Post Ending Mile

Post Counties State

CSFM 0121 (1) Jet fuel/diesel/gas oil Los Angeles CA








CSFM 0164 (1) Water with inhibitor Los Angeles CA






















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Pipeline ID Type of Oil Starting Mile

Post Ending Mile

Post Counties State

CSFM 0793 (1) Water with inhibitor














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FIGURE 1.1


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2 NOTIFICATION PROCEDURES This section is a guide for notification procedures that should be implemented immediately

after discovering a discharge incident and if possible, securing the source. Internal and

external notifications are described separately for clarification purposes only. All

notifications are of extreme importance and must be completed in a timely manner.

Internal Notification References are included in Figure 2.2.

2.1 INTERNAL NOTIFICATION

The following internal notifications should be made for each emergency incident to

the extent that the incident demands (telephone reference is provided in Figure 2.2).

In no event shall notification be delayed because the immediate supervisor is

inaccessible. Authorization is given to bypass management levels if necessary to

provide timely notification to appropriate management. The typical internal

notification responsibilities for each person potentially involved in the initial response

are as follows:

• Person discovering the discharge o Immediately notify the Paramount Pipeline, LLC Operations Control

Center in Paramount, CA. o Notify Manager, Pipeline Compliance or Refinery Shift Supervisor

(after hours).

• Manager, Pipeline Compliance or Refinery Shift Supervisor o Notify Manager of Operations (if call taken by Shift Supervisor) o Notify Director of Planning o Notify Spill Management Team

FIGURE 2.1 INTERNAL NOTIFICATION SEQUENCE

PERSON DISCOVERING THE

DISCHARGE

PUBLIC

24HR

Emergency

Number

PIPELINE

PERSONNEL

Manager of Pipeline Operations or Refinery Shift Supervisor (HOIC)

Director of

Logistics

Spill

Management

Team


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FIGURE 2.2

INTERNAL NOTIFICATION REFERENCES

POSITION NAME LOCATION OFFICE MOBILE

Qualified Individual/ Manager, Pipeline Compliance

Jeffrey Ewart Paramount, CA (562) 748-4751 (562) 577-0555

Alternate Qualified Individual Mohsen Ahmadi Paramount, CA (562) 748-4681 (562) 577-1413

PSM Compliance Engineer & Safety

Michael Vigliarolo Paramount, CA (562) 748-4852 (562) 618-7398

Alternate Qualified Individual Reagan Williams Paramount, CA (562) 748-4851 (562) 577-1403

Paramount Refinery Shift Supervisor (HOIC)

Paramount, CA (562) 748-4640 (562) 244-4508

Environmental Manager Kathy Gleeson Paramount, CA (562) 748-4613 (562) 577-3107


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FIGURE 2.3

Paramount Pipeline, LLC – Agency Notification Form

Incident Date Time

Notification made by: Date:

Agency Contacted Phone Number Time Called Spoke To Notification Number

Qualified Individual* 562-748-0555 (See page 80 for Alternates)

MSRC (OSRO) 1-800-645-7745

OES (800) 852-7550

NRC (800) 424-8802

Coast Guard (562) 980-4450 or (562) 980-4451

Oiled Wildlife Care Network

(877) 823-6926

Information Required

Name & Address of Operator: (See below for Pipeline Release) PPC DOT Pipeline Operator Id: 39837

Paramount Pipeline LLC 14700 Downey Avenue Paramount, CA 90723 AQMD Facility Id 800183

Location of Failure or Release (refinery equipment or off-site pipeline, if applicable):

Type of Incident (circle applicable)

Fire Explosion Release Other Breakdown Variance Condition (see below)

Permit Deviation (Env use only)

(Circle applicable) Injuries Fatalities Community Evacuation or Shelter In Place (circle one)

Number of People affected Number Of Injuries:

Number of Fatalities:

Est. Number Evacuated:

Do not include clearing of job site unless whole refinery is evacuated

(*Do not include quantity of water or other nonhazardous materials in the quantity released*)

Hazardous Material Released: Quantity* bbls gal lbs

Release is (circle applicable) Stopped Continuing On Site In Containment Off Site Moving Off Site

If Release is Off Site or Moving Off Site, where is release going?

Mechanical cause of failure, if known?

Weather (Circle applicable) Clear Cloudy Rainy Windy Temp oF Wind Dir (From)

Permitting Agency: State Fire Marshall None AQMD LACSD LARWQCB

(if asked) pipeline small chemical spills refinery equipment wastewater Storm water

Additional Calls

Check if Emergency Response is required. Go to Emergency Response Plan for additional callout requirements and forms

Check if Pipeline Incident Command System is required. Go to Pipeline Spill Response Plan for additional callout requirements and forms

Current Variance Conditions (check applicable) Permit Deviation Description

Reformer Bypass Stacks open (to 6/15/10)

Reformer startup in the next 24 hours

Put any additional notes, including agency call backs, on the back of the form


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FIGURE 2.4

EXTERNAL NOTIFICATION FLOWCHART

QUALIFIED INDIVIDUAL

JEFFREY H. EWART

562-748-4751(OFFICE)

562-577-0555 (MOBILE)

MSRC 1-800-645-7745


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2.2 EXTERNAL NOTIFICATIONS

External notifications are those made to entities outside of the Company including

federal, state and local regulatory agencies, as well as, railroad and utility

companies. These notifications will be made as follows:

• Manager of Pipeline Operations

• Environmental On-Call Person o National Response Center (NRC) o Appropriate state agency o Local agencies o All releases reported to any agency due to special agreement; and o USCG (as necessary).

The Agency Notification Form (see Figure 2.3) should be used to begin the external

notification process, keeping in mind that there are some strict time limits for making

certain calls.

The following are guidelines to be considered when initiating external notifications:

• Receive faxed copy of Agency Notification Form from Company employee or, at a minimum, gather pertinent incident information from the third party reporting the release.

• Do not report information that has not been verified or confirmed, usually by field personnel.

• Do not speculate as to the cause on an incident or make any statements about liability.

• Do not delay notifications because of incomplete information.

• When making notifications, document: o Agency notified, including telephone number o Date and time of notification o Person notified o Content of message o Incident number, if applicable

External required agency notifications contact numbers are provided in Figure 2.4.

Periodic follow-up notification must be made within the Company as well as to

federal, state, and local agencies, State OES requires updates every 12 hours for

first 48 hrs. Responsibility for periodic follow-up notifications remains with each

individual as initially assigned within the notification process flowcharts provided in

Figure 2.1, unless that responsibility has been transferred based on the magnitude

of the response.


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FIGURE 2.5

REQUIRED NOTIFICATIONS

NATIONAL RESPONSE CENTER (NRC)

c/o United States Coast Guard (CG-3RPF-2) 2100 2nd Street Southwest - Room 2111-B Washington, D.C. 20593-0001

(800) 424-8802 (24 Hours) (202) 267-2675 (Direct) (202) 267-1322 (Fax)

REPORTING REQUIREMENTS Discharges of Oil to Navigable Waters For all facilities, immediately report all discharges of oil or refined petroleum product into, or likely to reach, navigable waters of the United States (including streams, lakes, rivers, and reservoirs). NOTE: Notification of the regional Coast Guard Captain of the Port is also recommended if release

has affected or might affect a navigable waterway. Discharges of Hazardous Liquids or CO2 From Pipeline CFR §195.50; 195.52; 195.54; 195.402(c)(2) Advisory Bulletin (ADB-02-04) For a DOT pipeline or facility, immediately report (within 2 hours of discovery) any release of a hazardous liquid or carbon dioxide that:

• Results in an unintentional fire or explosion;

• Causes a death or personal injury requiring hospitalization;

• Causes property damage, including clean-up costs exceeding $50,000;

• Is significant in other respects; or

• Is 5 gallons or more.

NOTE: However, the First Notification Form is required for internal reporting of all releases of 3 gallons or more to land.

NOTE: If the operator does not provide a spill amount, the NRC will assume that a major spill of 1,000 barrels has occurred.

Prompt follow-up reports during the emergency phase of a response are required for the following significant changes:

• An increase or decrease in the number of previously reported injuries or fatalities;

• A revised estimate of the product release amount that is at least 10 times greater than the amount reported; and

• A revised estimate of the property damage that is at least 10 times greater than the reported property damage estimate.


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NATIONAL RESPONSE CENTER (NRC)

REPORTING REQUIREMENTS (Cont’d) NOTE: An operator should tell the NRC representative if a previous report was filed for the

incident and provide the NRC Report Number of the original telephonic. For DOT pipelines or facilities, a written report (DOT Form 7000-1) must be filed with the DOT within 30 days after discovery of the accident (fire or explosion, death or personal injury requiring hospitalization and estimated property damage including clean up costs exceeding $50,000). This form must also be filed within 30 days for any spill that results in a loss of 5 or more gallons of hazardous liquid, carbon dioxide, or highly volatile liquids (HVL), except for releases of less than 5 barrels (0.8 cubic meters) resulting from a pipeline maintenance activity if the release is:

• Not otherwise reportable;

• Does not impact a body of water;

• Confined to company property or ROW; and

• Cleaned up promptly. NOTE: To determine if a hazardous liquid pipeline is subject to DOT regulation (Refer to Figure 2.4) NOTE: Be sure to review incident for possible employee drug and alcohol testing. CERCLA Reporting

Immediately report any release of a CERCLA hazardous substance exceeding the reportable quantity (RQ). 40 CFR 302.4 lists the CERCLA hazardous substances with RQ's. MSDS's may also be used to determine if a spilled substance is reportable under CERCLA. NOTE: Under the CERCLA petroleum exclusion, refined petroleum product and crude oil spills do not have to be reported even though these products may contain hazardous substances.

http://www.access.gpo.gov/nara/cfr/waisidx_01/40cfr302_01.html


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CALIFORNIA EMERGENCY MANAGEMENT AGENCY (CAL OES)

OES Division 3650 Schriever Avenue Mather, CA 95655

(800) 852-7550 (24 Hrs.) (916) 845-8911 (24 Hrs.)

OFFICE OF SPILL PREVENTION AND RESPONSE (OSPR) DISPATCH (Department of Fish and Game)

(916) 445-0045 or 911 (Report spills near coastal waters)

REPORTING REQUIREMENTS TYPE: Notification is required if any of the following occurred:

• Any amount into or threatening state waters – inland, marine, or groundwater;

• Any amount into a storm drain;

• Any amount onto city and county streets;

• Any amount onto state highways and freeways;

• Any amount onto land (except for certain San Joaquin Valley oil fields);

• 5 barrels or more uncontained in certain San Joaquin Valley oil fields;

• 10 barrels or more contained in certain San Joaquin Valley oil fields;

• Crude oil release of more than five barrels from a pipeline or flow line in a rural area -if no threat to state waters;

• Fire or explosion; or

• Bodily injury or death to any person. VERBAL: Immediately. WRITTEN: As may be requested by the agency.

HAZARDOUS MATERIALS ADMINISTERING AGENCIES

Los Angeles County (323) 890-4045

REPORTING REQUIREMENTS TYPE: Any spill requiring notification to Federal or State agencies must be reported. VERBAL: Immediately. WRITTEN: As may be requested by the agency.


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CALIFORNIA STATE FIRE MARSHAL

1131 S Street Sacramento, CA 95811

(916) 445-8200

REPORTING REQUIREMENTS TYPE: Any unintentional rupture of 5 barrels or more, explosion or fire involving a pipeline. (OES is official call.) VERBAL: Immediately. WRITTEN: As may be requested by the agency.

CALIFORNIA DEPARTMENT OF FISH AND WILDLIFE - OSPR

Fish and Wildlife are notified through CAL OES

REPORTING REQUIREMENTS TYPE: Any non-marine spills involving known endangered plants or animals VERBAL: Immediately. WRITTEN: As may be requested by the agency.

REGIONAL WATER QUALITY CONTROL BOARD

Los Angeles Region 4 (213) 576-6600

REPORTING REQUIREMENTS TYPE: Any spill affecting groundwater or leaks from tankage. NOTE: CAL OES handles all reportable spills for the Regional Board. VERBAL: Immediately. WRITTEN: As may be requested by the agency.

CALIFORNIA STATE LANDS COMMISSION

100 Howe Avenue, Suite 100 South Sacramento, CA 95825-8202

(916) 574-1900 (Sacramento) (562) 590-5201 (Long Beach)

REPORTING REQUIREMENTS TYPE: Any spill on state lands VERBAL: Immediately. WRITTEN: As may be requested by the agency.

AIR POLLUTION CONTROL DISTRICTS

South Coast AQMD (800) 288-7664

REPORTING REQUIREMENTS TYPE: Any air pollution breakdown. VERBAL: Immediately. WRITTEN: As may be requested by the agency.

LOCAL EMERGENCY PLANNING COMMITTEES (LEPC)

Los Angeles County (323) 890-4045


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REPORTING REQUIREMENTS TYPE: Immediately for spills that impact or threaten navigable water or adjoining shoreline. VERBAL: Immediately. WRITTEN: As may be requested by the agency.

OTHER POTENTIAL REQUIRED NOTIFICATIONS

OCCUPATIONAL SAFETY AND HEALTH ADMINISTRATION (OSHA)

200 Constitution Avenue Washington, D.C. 20210

(800) 321-6742

REPORTING REQUIREMENTS TYPE: Fatality from a work related incident or the inpatient hospitalization of three (3) or more

employees as a result of a work related incident VERBAL: Immediately. WRITTEN: As requested by the Agency.

U.S. COAST GUARD – SECTORS

Sector Los Angeles (800) 221-8724

REPORTING REQUIREMENTS TYPE: Immediately for all spills that impact or threaten navigable water or adjoining shoreline. VERBAL: Notification to the USCG is typically accomplished by the call to the NRC. WRITTEN: As the agency may request depending on circumstances.

U.S. ENVIRONMENTAL PROTECTION AGENCY REGION

75 Hawthorne Street San Francisco, CA 94105

(415) 947-4400 (24 Hrs.) (800) 300-2193 (Emergency No.)

REPORTING REQUIREMENTS TYPE: Immediately for spills that impact or threaten navigable water or adjoining shoreline. VERBAL: Notification to the EPA is typically accomplished by the call to the NRC. WRITTEN: Per SPCC requirements, a written report must be submitted within 60 days for a spill in excess of 1,000 gallons (approximately 24 Bbls) in a single event or two spill events within a twelve month period into or upon navigable waters of the United States or adjoining shorelines. The written report should contain all of the elements listed in 40 CFR 112.4(a). As per RCRA regulations, a written report on the incident must be submitted to the Regional Administrator within 15 days from the date of the incident. The report must include: 1. Name, address, and telephone number of the owner or operator; 2. Name, address, and telephone number of the Facility; 3. Date, time, and type of incident (e.g., fire, explosion); 4. Name and quantity of material(s) involved; 5. The extent of injuries, if any; 6. An assessment of actual or potential hazards to human health or the environment, where this is

applicable; and 7. Estimated quantity and disposition of recovered material that resulted from the incident.

U.S. FISH AND WILDLIFE SERVICE


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1849 C Street NW Washington, D.C. 20240-0002

(202) 208-3100

REPORTING REQUIREMENTS – COVERED UNDER OES

TYPE: Wildlife Protection / Rehabilitation.

VERBAL: Immediately.

WRITTEN: As the agency may request depending on circumstances.

ASSISTANCE/ADVISORY NOTIFICATIONS

AGENCY LOCATION TELEPHONE

California Coastal Commission Oil Spill

Program

San Francisco Central, CA (415) 904-5247

(415) 990-5701 Cell

(415) 904-5205

Department of Toxic Substance Control

(Contact before moving waste to temporary storage)

Sacramento Headquarters 1001 I Street

Sacramento, CA 95814

Mailing Address:

P.O. Box 806

Sacramento, CA 95812

(916) 324-1826

California OSHA Los Angeles, CA (213) 576-7451

California State Highway Patrol Torrance, CA

(South Los Angeles)

911

(310) 516-3355

Los Angeles County Public Works Los Angeles, CA (626) 458-5100

(800) 675-4357

(Emergency)

California Department of Public Health (CDPH) Sacramento, CA (916) 449-5661

Office of Environmental Health Hazard

Assessment (OEHHA)

Sacramento, CA (800) 852-7550

Federal Emergency Management Agency

Region IX (FEMA)

Sacramento, CA (516) 627-7250(24 Hrs.)

Agency for Toxic Substances and Disease

Registry (Department of Health & Human

Services)

(404) 498-0120 (24 Hrs.)

(415) 947-4316 (San

Francisco)

(888) 422-8737 (Message

Center)

Cal Trans – CA Dept. of Transportation (562) 867-7643 or

(562) 692-0823

National Weather Service - Los Angeles

Oxnard Weather Forecast Office

Oxnard, CA (805) 988-6610


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Chemical Transportation Emergency Center

(CHEMTREC)

(800) 876-4766 (24 Hrs.)

LOCAL EMERGENCY SERVICES

DIAL 911 for All Police, Fire, and Ambulance Emergencies

AMBULANCE/HOSPITALS

CITY NAME/ADDRESS TELEPHONE

Long Beach Long Beach Memorial Hospital 2801 Atlantic Avenue

(562) 933-1335

Los Angeles County of Los Angeles USC Medical Center 1100 N. State Street

(323) 226-2345

MEDIA NOTIFICATIONS


TV – CBS 2 Los Angeles, CA (323) 575-2345

TV – KVCR 24 San Bernardino, CA (909) 384-4444

TV – KUSI 9 NEWS San Diego, CA (858) 571-5151

USCG CLASSIFIED OIL SPILL REMOVAL ORGANIZATIONS (OSRO)

COMPANY RESPONSE

TIME LOCATION TELEPHONE

West Coast Environmental Solutions

60 minutes (maximum)

Various Locations* (562) 448-9510

MSRC 60 minutes (maximum)

Various Locations* (562) 981-7600 (562) 981-7610

NRC Environmental Services

60 minutes (maximum)

Various Locations* (800) 899-4672


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LOCAL ASSISTANCE/REPORTING LOS ANGELES COUNTY, CA


City of Los Angeles Emergency Management Los Angeles, CA (213) 978-2222

LA County Office of Emergency Management Los Angeles, CA (323) 980-2260

Railroad - Union Pacific Los Angeles County (888) 870-8777 (800) 877-5123

Electric Company - SoCalEdison Los Angeles, CA (800) 611-1911 (In-State Only) (Emergency) (800) 342-5397 Los Angeles Water & Power Contact Center

Gas Company – Southern California Gas Company

Los Angeles, CA (800) 233-7537 (Distribution Dispatcher (7am – 4:30pm) (800) 427-2200 (Emergency Response Number)

City of Los Angeles Stormwater Hot Line Van Nuys, CA (800) 974-9794

Sewage Treatment Plant El Segundo, CA (310) 648-5407

Cal-CUPA

Los Angeles County Fire Department Manager Health Hazmat Division

5825 Rickenbacker Road Commerce, CA 90040-3027

(323) 890-4045 (323) 890-4046 Fax

City of Los Angeles Fire Department Millage Peaks, Chief

200 N Main Street City Hall E., Rm 970 Los Angeles, CA 90012

(213) 978-3800 911

City of Bellflower 16600 Civic Center Dr Bellflower, CA 90706

(562) 804-1424 (562) 755-8367 (after hrs)

Los Angeles County Sanitation District (562) 437-6520 (562) 437-1881

CA DTSC (800) 852-7550

Oiled Wildlife Care Network (877) 823-6926

City of Paramount 16400 Colorado Ave. Paramount, CA 90723

(562) 220-2000

Paramount Fire Dept. – HAZMAT 7521 E Somerset Blvd., Paramount, CA 90723

(562) 634-6559


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3 INITIAL RESPONSE ACTIONS

3.1 INITIAL RESPONSE ACTIONS

Initial response actions are those taken by local personnel immediately upon

becoming aware of a discharge or emergency incident, before the Local Response

Team (described in Section 4.0) is formed and functioning. Timely implementation

of these initial steps is of the utmost importance because they can greatly affect the

overall response operation.

It is important to note that these actions are intended only as guidelines. The

appropriate response to a particular incident may vary depending on the nature and

severity of the incident and on other factors that are not readily addressed. Note

that, without exception, personnel and public safety is first priority.

The first Company person on scene will function as the person-in-charge until

relieved by an authorized supervisor who will assume the position of Incident

Commander (IC). Transfer of command will take place as more senior management

respond to the incident. For response operations within the control of the Local

Response Team, the role of IC will typically be assumed by first Company person

on scene.

The person functioning as Incident Commander during the initial response period

has the authority to take the steps necessary to control the situation and must

not be constrained by these general guidelines.

TABLE 3.0

INITIAL RESPONSE ACTIONS - SUMMARY

• Personnel and public safety is first priority.

• Eliminate sources of ignition.

• Isolate the source of the discharge, minimize further flow.

• Make internal notifications.

• Make external notifications.

• Activate the Local Response Team as necessary.

• Activate response contractors and other external resources as necessary.

• Monitor and control the containment and clean-up effort.


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In addition to the potential emergency events outlined in this section, the Company

has identified several “abnormal operations” that could be expected in the pipeline

facilities. The pipeline has defined the events and established procedures to

identify, eliminate or mitigate the threat of a worst case discharge due to these

events. In compliance with 49 CFR 195.402(d), these procedures are defined in the

Paramount Pipeline LLC O&M Plan.

EMERGENCY RESPONSE FLOWCHARTS CCR §817.02(f)(3)

GENERAL OIL SPILL RESPONSE


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No

Yes

Yes

Yes

Yes

Yes

Spill

Shut down ignition sources

Notify facilities personnel

Secure the area

Can spill be contained & recovered with onsite resources?

Initiate appropriate emergency response procedures

Make required external notifications

Is spill likely to affect adjacent businesses/operations?

Notify adjacent businesses/operations

Is spill threatening water?

Is slick approaching shoreline?

See shoreline protection decision tree

Is anyone injured or is site unsafe?

Can spill source be controlled?

Initiate source control operations

No

Activate additional resources

No

No

Continue emergency response

procedures

No

No

Call 911 & evacuate nonessential personnel


SHORELINE PROTECTION DECISION TREE

No

Has spill already contacted shore?

Determine resource s at risk & consult agencies for protection

priorities

Determine applicable protection techniques

See Shoreline Response Decision

Tree

Yes


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SHORELINE PROTECTION DECISION TREE

Identify shoreline type

Evaluate sensitivity of shoreline versus oil persistence

Select cleanup procedures

Shoreline contacted by oil


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FIRST RESPONDER AWARENESS LEVEL CCR §817.02(f)(4)(D-E)

The following guidelines should be observed by the first person(s) on scene at a

release who would be classified as First Responder Awareness Level.

• Approach the release site safely and cautiously. Remain calm. (Your goal is release verification and personal and public safety.)


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o Observe wind direction in case of evacuation. o Approach from upwind direction. o Do not enter an area with heavy fumes or vapors. o Get only close enough to visually assess the area. o Attempt to locate the leading edge of the release. Without coming in

contact with the product or vapor cloud, take steps to reduce the spread of the release if possible.

• If possible, eliminate source of release (keeping in mind that your goal is release verification and personal and public safety).

• Call your supervisor and get help.

• The senior Paramount Pipeline LLC representative on site is to assume the role of Incident Commander and utilize the Incident Command System.

• Secure the area for safety reasons.

• Use local authorities to protect life and property. Divert or stop all traffic in the immediate area if necessary and assess the need for evacuation.

• Keep ignition sources away. DO NOT start vehicles in the vicinity of the vapors.

• If the chemical is on fire, remain at a safe distance on site. DO NOT attempt to extinguish the fire.

• For Highly Volatile Liquids (HVL): o DO NOT ENTER the vapor cloud area, and o Observe the wind conditions and determine the most likely direction of

the vapor cloud movement.

FIRST RESPONDER OPERATIONS LEVEL

In addition to following all guidelines pertaining to First Responder Awareness Level,

the first person(s) on scene at a release who would be classified as First Responder

Operations Level may additionally attempt to contain the release from a safe

distance, keep it from spreading, and prevent exposures.

FIRST RESPONDER HAZMAT TECHNICIAN LEVEL

The following guidelines should be observed by the first person(s) on scene at a

release who would be classified as First Responder HAZMAT Technician Level and

• Do not enter the “Hot Zone” unless personal protective equipment is used along with the “Buddy System” and the responders are enrolled in the respiratory protection program.

• Minimum Personal Protective Equipment (PPE) required (however additional levels may be required depending upon the exposure potential):

o Self-contained breathing apparatus; o Chemical resistant jacket (hip length, with hood); o Chemical pants and chemical resistant boots (or boot

covers); o Chemical resistant gloves (taped); and


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o Hard hat.

• Required monitoring equipment: o Gas monitor(s) for measuring LEL, O2, and if necessitated

by release type H2S; o Manual sampling pump with benzene tubes/chips; and o Approach the release site safely and cautiously.

• Continuously check the site with a monitor and immediately evacuate the hot zone area if any alarm sounds.

• Take benzene readings at various locations to define exposure levels and “zones”.

• Document all monitoring data.

• Evaluate the monitoring data to determine exclusion, decontamination and safe zones and communicate results to IC for safety briefings, and future monitoring schedules.

TABLE 3.1

INITIAL RESPONSE CHECKLIST

FIRST COMPANY PERSON NOTIFIED/ON SCENE

Follow the appropriate "Specific Incident Response Checklist" in Figure 3.1 and "Product Specific

Response Considerations" in Figures 3.2 and 3.3.

Notify Management of the incident.


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Utilize local emergency services as necessary (police, fire, medical).

Notify the Refinery / Pipeline Control Center, as appropriate.

MANAGEMENT

Evaluate the Severity, Potential Impact, Safety Concerns, and Response Requirements based on the initial data provided by the first person on scene.

Assume the role of Incident Commander.

Confirm safety aspects at site, including need for personal protective equipment, sources of

ignition, and potential need for evacuation.

Activate the Local Response Team and primary response contractors, as the situation demands.

Coordinate/perform activation of additional spill response contractors, as the situation

demands (telephone reference is provided in Figure 2.5).

Perform notifications as per Figures 2.1 and 2.2.

Direct and coordinate response and clean-up operations.

Direct containment, dispersion, and/or clean-up operations in accordance with the Product

Specific Response Considerations provided in Figure 3.2.

LOCAL RESPONSE TEAM

Assigned personnel will immediately respond to a discharge from the site, as the situation

demands.

Perform response/clean-up operations as directed or coordinated by the Incident Commander.

INITIAL RESPONSE CHECKLIST

AREA PERSONNEL RESPONSIBILITIES

Making an initial response.

Defining the problem.


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Controlling the situation.

Cleaning up and repairing the damage.

MANAGEMENT

After notification of an incident, area personnel should:

Dispatch one (1) or more area/contract employees to the release site and establish the Incident

Command System (ICS).

Complete a Site Safety Plan (Refer to Appendix K)

Secure the area for safety concerns:

Human Life

Explosion (including rectifiers)

Fire

Health (vapors, water contamination, etc.)

Assemble response equipment and personnel. Dispatch resources to release site.

Define the problem:

Locate the head (leading end) of the release.

Monitor the area to identify all existing hazards and extent of the exposed area.

Monitor the area to identify any environmental impact (wildlife, water supplies, etc.)

Determine the necessary personal protective equipment and precautions (oxygen, deficiencies,

thermal exposure, high Lower Explosive Limit (LELs), and Permissible Exposure Limit (PELs).

Control the situation:

Secure the manual valves.

Take measures to prevent accidents associated with product movement, vapor clouds, or fire.

In highly populated areas:

Eliminate potential sources of ignition, and

Use police, fire department and utility groups to help with evacuation, security, and protection

In high traffic areas:

Divert or stop all traffic in the immediate area, and


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Use police, fire department, and utility groups to help with traffic or crowd control.

Activate contract employees and equipment as needed.

Determine if assistance is needed from an oil spill cooperative (if available) or Local Response Team. Activate them if needed.

Collect the released material into containment sites as quickly as possible.

Locate additional containment sites, if needed.

Evaluate resources to confirm sufficient personnel and equipment.

Clean up to minimize damage to public health and the environment.

Repair the damage to the system.

FIGURE 3.1

DETAILED INCIDENT RESPONSE CHECKLIST CFR §194.107(d)(1)(v); §195.402(e)(2-7)


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Remember, Without Exception, Personnel Safety Is First Priority. Excessive Exposure To

The Vapor And Liquid Stages Of The Spilled Product Should Be Avoided.

INITIAL RESPONSE

_____ Take appropriate personal protective measures.

_____ Call for medical assistance if an injury has occurred.

_____ Check wind direction before investigating incidents where vapor cloud is a possibility.

_____ Utilize lower explosive limit (LEL) meter when you conduct an initial investigation to determine what has been released and the source.

_____ Do not investigate on your own, take a buddy.

_____ If you discover explosive / flammable vapors during your initial investigation or if vapors are a possibility, make sure you inform the 911 operator that police and other emergency responders should NOT use flares to control traffic.

_____ At the evacuation muster point, take a head count to determine if anyone is missing.

_____ If possible, block access to the hot zone and/or entire area (use vehicles, caution tape, traffic cones, etc.).

_____ Restrict access to the spill site and adjacent area as the situation demands. Take any other steps necessary to minimize any threat to health and safety.

_____ Verify the type of product and quantity released (Material Safety Data Sheets are retained in the Safety Department).

_____ Advise personnel in the area of any potential threat and/or initiate evacuation procedures.

_____ Use testing and sampling equipment to determine potential safety hazards, as the situation demands.

_____ Identify/Isolate the source and minimize the loss of product, from a safe distance. _____ Take necessary fire response actions. If fire is in the incipient stage, trained personnel may utilize the facility fire extinguishers if safe to do so. Company personnel are trained only to the incipient stage.

_____ Eliminate possible sources of ignition in the near vicinity of the spill.

INIT

IAL

RES

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_____ Notify Management of the incident.

LINE BREAK OR LEAK, SPECIFIC RESPONSE (Including Piping Rupture/Leak, Valve

Rupture/Leak and Manifold Failure both under and not under pressure)

_____ Shut down pumping equipment.

_____ Close upstream and downstream block valves. _____ Utilize Combustible Gas Indicator, O2 meter, proper colormetric indicator and other air sampling measurements to assure that areas are safe to enter for continued response operations. _____ Mitigate spreading of the product, as the situation demands. Potential containment strategies include:

• Earthen dike/berm;

• Ditching; and

• Spreading sorbent material over the spill.

_____ Prevent the spill from entering the waterways, sewer, etc. to the greatest extent possible, from a safe distance. _____ If located within containment area, ensure that drainage valve(s) is “closed”. _____ Drain the line section, as the situation demands. _____ Make all necessary repairs. _____ Return the line/rack to service when repairs are complete. _____ Clean up spilled product to eliminate any possible environmental problems. Be alert for underground cables. _____ Inform local operators such as utilities, telephone company, railway. _____ If the spill escapes the containment area, review the location of socio-economic and environmentally sensitive areas identified in Section 6.0. Determine which of these may be threatened by the spill and direct the response operation to these locations. Initiate protection and recovery actions. _____ Determine the direction and expected duration of spill movement. Refer to the maps in Section 6.0. _____ Request local authorities to establish traffic control in the area, as the situation

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demands. _____ Complete follow-up and written reporting, as the situation demands.

STORAGE TANK LEAK, SPECIFIC RESPONSE (Including Tank Failure/Leak)

_____ Shut down all tank battery product movement operations and isolate the tank. _____ Initiate Confined Space Entry procedures, as applicable. _____ As applicable, ensure that the containment area drainage valve(s) is “closed”. _____ If near tank bottom, consider filling tank with water and maintain water bottom to suspend the discharge. _____ Utilize Combustible Gas Indicator, O2 meter, proper colormetric indicator and other air sampling measurements to assure that areas are safe to enter for continued response operations. _____ Block drainage of spilled material from traveling offsite. _____ Stop all traffic in hazardous area (inside and outside of property boundaries), as the situation demands. _____ Request local authorities to establish traffic control in the area, as necessary. _____ Remove product from containment area (at a sump or in a low area) with an explosion proof pump, oil skimmer, and/or vacuum truck w/ skimmer attachments. _____ Empty tank as soon as possible. _____ Make all necessary repairs. Return the line/tank to service when repairs are complete and tested. _____ Clean up product spill to eliminate any possible environmental problems. Be alert for underground cables. _____ Inform local operators such as utilities, telephone company, railway. _____ If necessary, call one (1) of the approved waste removal companies to remove the remaining sludge and residue from the containment area. Contact the Company Hazardous Waste Coordinator, if necessary, to remove waste from the Facility for disposal. _____ If the spill escapes the containment area, review the location of socio-economic and environmentally sensitive areas identified in Section 6.0 and ACP. Determine which of these may be threatened by the spill and direct the response to these

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locations. Initiate protection and recovery actions. _____ Determine the direction and expected duration of spill movement. Refer to the maps in Section 6.0. _____ Complete follow-up and written reporting, as the situation demands.

LEAK OR SPILL TO WATER, SPECIFIC RESPONSE CCR §817.02(d)(6)(A-B)

NOTE: For more specific information regarding containment, cleanup, storage, handling and

disposal, refer to the appropriate sections of this manual.

Guidelines If there is an oil release on water, consider these guidelines.

_____ See “Initial Response Actions” heading above. _____ Cease pumping and close valves to prevent any further release. _____ Determine the release source and prevent any further flow from the pipeline. Contain the oil and prevent any further contact with water. _____ Remember that flammable vapor concentrations can exist near spilled oil. (For example, as much as 50% of the original volume of gasoline can evaporate in 10

minutes at 60.5F.) Use explosive meters and safety precautions to prevent fire, explosions, asphyxiation, or health risks to response personnel. _____ Eliminate possible sources of ignition. _____ Determine the actual speed of the oil on water. Remember that oil on water may not travel at the same velocity as the river or stream (due to wind, oil gravity). Use this knowledge for boom placement. _____ Set booms considering wave action and oil pickup points. Consider cascading booms (several layers) if necessary. _____ Contact emergency response contractor and other marine response cooperatives for emergency response assistance, if needed. _____ Consider accessing the release sites by boat rather than land vehicles to protect shorelines and other sensitive areas.

Tracking Oil CCR §817.02(d)(6)(D)

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A number of techniques will be used to track the movement of an oil slick, including:

• direct observation from aircraft, vessels, or elevated areas

• buoy tracking systems

• radiometric oil spill surveillance systems (ROSSS), and

• spill trajectory predictions.

NOTE: Buoy and ROSS tracking systems could be accessed through response cooperatives. Trajectories could be generated by the Scientific Support

Coordinator (i.e., through Unified Command) or by local personnel using the vector addition analysis method. The vector addition analysis method involves plotting the two primary factors that influence the movement of the slick (i.e., surface currents and wind) to determine the estimated trajectory of the slick.

https://www.ndbc.noaa.gov/

Clean up, Storage, Handling, and Disposal

To clean up, store, handle, and dispose of the oil on water, consider these guidelines.

_____ Use skimmers to remove the oil from the water surface. _____ Use sorbent pads and sorbent booms to remove the oil sheen from the water surface. _____ Try to limit the amount of water picked up with the oil when recovering oil. _____ Consider alternatives to vacuum trucks for on-scene storage of recovered oil. _____ Only use dispersants with agency approval and if advised by the Environmental Unit Leader. _____ Make sure that the removal and disposal of oil, water, and debris is consistent with regulatory requirements. Consult a Company environmental representative.

LEAK OR SPILL TO LAND, SPECIFIC RESPONSE

NOTE: For more specific information regarding containment, cleanup, storage, handling and disposal, refer to the appropriate sections of this manual.

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https://www.ndbc.noaa.gov/


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Guidelines If a release of oil occurs on land, consider these guidelines.

_____ See “Initial Response Actions” heading above. _____ Cease pumping and close valves to prevent any further release of oil.

_____ Determine the release source and prevent further flow from the pipeline. _____ Remember that flammable vapor concentrations can exist near spilled oil. (For example, as much as 50% of the original volume of gasoline can evaporate in 10

minutes at 60F.) Use explosive meters and safety precautions to prevent fire, explosions, and asphyxiation or health risks to the response personnel. _____ Eliminate possible sources of ignition. Do not start vehicles in the vicinity of volatile materials that have been released. _____ To avoid vapor ignition, divert or stop traffic if the release impacts a roadway. _____ Prevent oil from entering into drainage or sewer systems, water courses, irrigation channels, or culverts. Block drains, dam ditches, and boom water courses and irrigation channels.

Response Strategies Oil either spreads out or penetrates downward when released on land. When the oil penetration is rapid and the depth of groundwater is shallow, the preferable strategy may be to let the oil spread. If the land surface is impermeable, the desirable strategy may be to allow or cause the oil to collect in pools. NOTE: If oil collects in pools in a contained area, consider using water as a layer between the oil

and the ground.

Consult with a Company environmental representative for guidance on cleanup, storage, handling

and disposal.

NOTE: If possible, treat soil on site.

EXPLOSIONS AND/OR FIRE, SPECIFIC RESPONSE CCR §817.02(f)(4)(A)


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NOTE: In the event of a fire at or near any of the Paramount Pipelines and Lakewood Tank Farm,

Paramount personnel must take action as appropriate to protect employees and public

safety.

_____ Shut down Facility operations and mitigate fuel sources, as the situation demands. _____ Utilize applicable Facility firefighting capability after conducting safety assessment of the area. If fire is in the incipient stage, trained personnel may utilize the facility fire extinguishers if safe to do so. Facility personnel are trained only to the incipient stage. _____ Notify local fire department(s), as the situation demands (telephone references for Fire Departments are provided in Figure 2.5). _____ Consider evacuating the area, as the situation demands, if there are nearby residential or commercial dwellings. _____ Assist the emergency rescue personnel with injured and/or trapped individuals. _____ Determine when the fire started.

INDIVIDUAL DISCOVERING THE FIRE - (All Employees)

_____ Notify Refinery Shift Supervisor on duty. _____ Return to the scene of the fire and, if practical (not beyond incipient stage), attempt to extinguish same with the nearest fire extinguisher available. _____ Prevent secondary problems due to flame impingement, or spills and runoff. _____ In the event the fire is too large for an individual to fight alone, the individual sounding the alarm or making the phone call should stand by at a safe distance to direct the fire department to the scene of the fire and keep personnel and vehicles from entering the danger area. _____ Alert all personnel of the exact location and extent of the fire. _____ Shut off pumps.

TANK RELATED FIRE

FIR

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_____ Determine the tank status (inactive, pumping in or out, gauge level, tank/roof condition). _____ Isolate the tank from connecting lines and facilities if possible. _____ Determine the tank contents (material and characteristics). _____ Determine the type of roof (cone, external floater, internal floater, seal material) on the tank. If the tank has a cone roof, determine if it is equipped with flame arresters, emergency vent shutoffs, snuffers, or other types of fire prevention equipment. _____ Review the fire wall area, drainage (dike drains), proximity of the equipment, and exposed piping.

EXPLOSION NEAR OR AT A PIPELINE FACILITY

Damage Assessment/ Control By On Site Personnel Contact local firefighting authorities and police. Damage assessment/control may be initiated by

on site personnel only if it is safe to engage in such activities.

Guidelines When an explosion occurs, consider these guidelines.

_____ See “Initial Response Actions” heading above. People Related

_____ Call for fire and medical assistance if necessary. _____ Account for personnel known to be working at or near the facility.

Explosion Related

_____ Survey the facility for damage. _____ Try to determine if there is an obvious source of the explosion. For example, ignition of vapors, rapid release of gas or liquid, outside source (collision, bomb, etc.), electrical equipment (transformers, distribution panels, etc.). _____ Considering the source of the explosion and damage if any, isolate the facility to limit additional fuel or fire or explosions.

All personnel are reminded that outsiders other than emergency services will not be allowed in the

facility during the time of an emergency, and that no statements will be issued to the media or other

interested parties except by designated company management. Be courteous with media

representatives and direct them to the designated spokesman.


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VAPOR CLOUD (from a massive spill, line rupture, etc.), SPECIFIC RESPONSE CFR

§195.402(e)(8)

NOTE: If an incident occurs when the pipeline is transporting gas or highly volatile liquids (HVLs)

or refined products, there is a strong possibility of vapor cloud formation.

Material Specific Gravity

When an incident occurs, the specific gravity of the vapor material is relevant. Vapors that are

heavier than air seek low spots, such as ditches and depressions in the ground. Therefore, the

higher specific gravity of a material released, the more likely its vapor cloud would hug the ground.

The following table lists the specific gravities of possible release materials using the specific

gravity for air as a base.

Material Specific Gravity

Gasoline 3.00

Natural Gas 0.55

Jet 0.82 to 1.08

ULS Diesel 0.62 to 0.88

Crude 0.7 to 0.8

Weather Wind and general weather conditions can affect vapor clouds. Such conditions can cause the

boundary area to move and enlarge. If an incident occurs, determine the most likely direction of

vapor cloud movement based on the wind direction.

Vapor Cloud Originating from a Facility Incident

_____ The person who discovers the vapor cloud will sound the alarm and notify the supervisor on duty and vacate the area. _____ Remember: the only proper action in the presence of a vapor cloud is to get away from it. Do not shut off electrical equipment.

_____ All personnel will report to the evacuation muster point for roll call and further

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instructions. _____ After all personnel have been accounted for, the Facility Operator / Manager, will initiate the following actions as deemed necessary:

1. Shut down pipeline.

2. Evacuation of adjacent property.

3. Only the fire department will be permitted to enter the facility.

_____ Contact the appropriate agencies and potentially affected neighbors (refer to Figure 2.5).

Vapor Cloud Originating from a Pipeline Incident

_____ The Initial Responder:

• Discovers the vapor cloud;

• Determines the material causing the vapor cloud;

• Notifies the Controller and maintenance crew; and

• Sees “Initial Response Action” listed previously in this section. _____ The Controller:

• Isolates the pipeline by closing the remotely-operated valves; and

• Notifies the National Response Center. _____ The maintenance crew isolates the pipeline by closing the manually operated valves. _____ The Initial Responder determines:

• If there is a fire, then remain at a safe distance on site, until relieved.

• If there is not a fire, then keep ignition sources away and work with fire department to disperse the vapor cloud.

_____ The Initial Responder:

• Determines the boundary area of the vapor cloud and the vapor concentration using explosimeter or Draeger tube;

• Barricades or identifies the boundary area;

• Identifies the affected area that exists 1,500 feet outside of boundary area and the areas downwind of the vapor cloud; and

• Determines the people and facilities within the affected area, and notifies the police to evacuate the affected area (including areas downwind of the vapor cloud, outside of the affected area).

_____ Police evacuate the boundary area.


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_____ Fire department disperses the vapor cloud with a sustained flow of water spray. _____ The Initial Responder stays on site until:

• Relief arrives; or

• Vapor cloud is completely dispersed, or fire is burned out and the vapor cloud no longer exists.

GAS DETECTED IN A BUILDING, SPECIFIC RESPONSE

NOTE: In the event of gas being detected in a building on or near Paramount facilities, Paramount

personnel should take action as appropriate to protect employees and public safety.

Gas Detection and Confirmation by On Site Personnel Contact the gas utility companies and/or other gas pipeline operations in the immediate area.

Begin leak detection procedures and mitigation procedures (e.g., shutting off the gas and ignition

sources, etc.) only if it is safe to engage in such activities.

Guidelines When gas is detected in or near a building, consider these guidelines.

_____ See “Initial Response Actions” heading above.

People Related

_____ Consider evacuating the area if there are nearby residential or commercial dwellings.

Release Related

_____ Determine the location and source of the gas release. _____ If a vapor cloud has developed, assess the extent and coverage of the vapor cloud and determine the hazardous areas. _____ Refer to guidelines under the “Vapor Clouds” heading above.

BOMB THREATS, SPECIFIC RESPONSE

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The following pages provide guidelines for actions to be taken in the event a bomb threat is

received. A bomb threat to the facilities or personnel may present itself in any of several ways:

• Phone;

• E-mail;

• Fax;

• Radio;

• Mail;

• Word-of-mouth; or

• Third party intelligence.

Other threats to facilities, vehicles, and persons are often treated in the same manner as bomb

threats. These may include:

• Terrorist threats;

• Workplace violence threats;

• General threat to an industry; or

• Civil disturbances.

The following steps should be used as guidance when responding to the above situations. Actions

during a real event will vary based on differences in circumstances, response activities, good

judgment, etc.

PHONE / WRITTEN (FAX, LETTER, TELEGRAM) THREATS

Person Receiving the Call

_____ Immediately refer to the Telephone Bomb Threat Checklist, (this should be kept next to phones that have publicly posted phone numbers), so you can use it during the conversation with the individual making the bomb threat call. If possible, complete the form during the call. _____ Remain calm when talking to the caller. _____ Keep the caller on the line as long as possible in order to obtain as much information as possible. Ask him/her to repeat the message. Try to write down every word spoken by the person. If you have a small hand-held tape recorder available, try to tape the conversation. _____ If the caller does not indicate the location of the bomb or the time of detonation/attack, ask for this information. _____ Inform the caller that the building/Facility is occupied, and that the incident could result in death or serious injury to many innocent people. _____ Pay particular attention to background noises, such as motors, music, and any other noise that may give a clue as to the location of the caller.

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_____ Listen closely to the voice (male, female), voice quality (calm, excited), accents, and speech impediments.

After the Caller Hangs Up & Written Threats

_____ Immediately report the threat call to the Shell person designated by management to receive such information (i.e., Site Security Company, Site Manager, Site Qualified Individual, or appropriate supervisor). Do not use cell phones, personal digital assistants (PDAs), two-way radios, or other similar communication devices in the Facility and/or the general area until the bomb squad approves their use. Turn any such devices off immediately, since an incoming call could be enough to trigger a nearby explosive device.

Pipelines & Tank Farms – Additional Guidance

_____ If the caller does not indicate the location of the bomb/substance or the time of possible detonation/attack, ask him/her for this information. Try to determine the State, pipeline system, and specific location involved, if possible. _____ For offices and control centers, inform the caller that the building/Facility is occupied and the incident could result in death or serious injury to many innocent people. _____ For pipelines and facilities, inform the caller that an incident could result in death of the innocent general public or significant environmental impact.

Secure the Facility and limit access to essential personnel only. _____ If a full or partial Facility evacuation is necessary, activate Facility Evacuation Plan immediately. When in doubt, evacuate. Encourage personnel to be vigilant for suspicious or out of place objects as they evacuate and leave their workstations. Work with local law enforcement and local FBI. Follow their direction. _____ Initiate operations “shut down” procedures, as necessary. _____ If deemed necessary, set up a Command Post at a pre-determined offsite location. Ensure you have:

• Applicable response/security plans;

• Facility maps;

• Access keys; and

• Cell Phones, pagers, and radios. _____ Members of the press or general public should not be permitted inside the Facility. Direct all members of the press to the designated spokesperson.


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Pipelines & Tank Farms – Additional Guidance

_____ Additional actions to consider for pipelines and tank farms:

• Which, if any system(s), should be shutdown; and

• When, if any system(s), should be shutdown. FACILITY SEARCH GUIDELINES

_____ Employees/staff should conduct visual searches as they evacuate the area. _____ Look for obvious signs of things out of place. (The bomb squad will not know what is out of place.) _____ Turn off all cell phones, pages, PDA’s, radios, etc. as you evacuate. _____ Leave all doors, lights, gates, power, etc. as you find them. _____ If a suspicious object is found, DO NOT TOUCH OR MOVE IT! Inform the bomb squad of the object’s location.

Pipelines & Tank Farms – Additional Search Guidance

_____ Survey from a distance with the aid of binoculars:

• Base of tanks;

• Manifolds and station piping; and

• Open pump canopies and switch gear areas. _____ Closed areas should be searched after the open areas have been eliminated unless there is a specific reason for doing otherwise. _____ Due to the expanse of pipeline facilities, aircraft should be considered to aid in the surveying of tank tops and pipeline right-of-way (ROW).


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SUSPICIOUS MAIL / DELIVERED PACKAGES

_____ Frequently seen explosive devices have been incorporated, hidden, or camouflaged in letters, soft cover pocketbooks, hard cover books, manila envelopes, and cardboard boxes. While many are delivered by U.S. mail, they may arrive by private courier or express service. Be alert to recognize suspicious-looking or unexpected items especially those that have:

• Handwritten or poorly typed address;

• Incorrect title, or title but no names;

• Misspelling of common words;

• Oily stains, discolorations, or odor;

• No return address;

• Excessive weight;

• Lopsided, uneven, or ridged envelope;

• Protruding wires or tin foil;

• Excessive securing material (tape, string, etc.);

• Any evidence that the envelope has been opened and re-glued; and/or

• Mail item from a new or strange source. _____ If you receive or find a suspicious-looking letter or package:

• DO NOT TRY TO OPEN IT.

• Isolate the area around the letter or package to the degree possible, and make emergency notifications as previously outlined, and evacuate personnel to a safe distance, as directed.

• If accidentally opened, preserve, BUT DO NOT TOUCH FURTHER all original envelopes, twine, shipping documents, or packaging materials for evidence and release to the police as requested.

• Report the package to the Paramount person designated by management to receive such information (i.e., Facility Security Officer, Facility Manager, Facility Qualified Individual, or appropriate supervisor) or their designee.

• Notify local law enforcement/FBI for local assistance.

• Inform the Paramount or the Corporate Security Department (refer to the Notifications Section).


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PHONE THREAT CHECKLIST (via PHONE)

Person Receiving Call:

Phone Number Received on:

Date/Time of Call:

Type of Threat:

Questions to Ask Caller: (document caller’s answers exactly)

When is the bomb going to explode? (If Bomb Threat)

When will the event take place? (If other)

Where is the device located? (state, county, facility)

What does the device look like? (color, size, shape)

What kind of device is it?

What will trigger the device?

Did YOU put the device on our property? Why?

What is your name? Who do you represent?

Where are you? (address, phone #, etc.)


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PHONE THREAT CHECKLIST (via PHONE) (Cont’d)

Sex: ❑ Male ❑ Female Age: ❑ Preteen ❑ Teen ❑ 20-40 ❑ 40> Length of Call: Caller’s Speech: ❑ Calm ❑ Excited ❑ Nasal ❑ Angry ❑ Taped ❑ Stutter ❑ Lisp ❑ Slow ❑ Raspy ❑ Irrational ❑ Rapid ❑ Deep ❑ Soft ❑ Ragged ❑ Incoherent ❑ Loud ❑ Laughing ❑ Crackling ❑ Deep Breathing ❑ Abusive ❑ Crying ❑ Disguised ❑ Slurred ❑ Familiar ❑ Reading ❑ Distinct ❑ Slang ❑ Vulgar ❑ Well Spoken ❑ Frightened ❑ Accent Type of Accent: If voice is familiar, who does it sound like? Background Noises:

❑ Street noise ❑ Factory ❑ Crockery ❑ Animals ❑ Voices ❑ Quiet ❑ PA System ❑ Static ❑ Music ❑ Motor ❑ Machinery ❑ Aircraft ❑ Railroad/Subway ❑ Playground noises ❑ Office equipment ❑ Other Notes:


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NATURAL DISASTER (Tornados, Severe Storms and Earthquakes), SPECIFIC RESPONSE

Although many disasters cannot be prevented or predicted, preparation can significantly reduce

losses. In the event of a severe weather condition or a natural disaster, the Qualified Individual

or a Terminal Operator will be the emergency coordinator.

A tornado may be monitored and detected by:

• Listening to news reports – know the difference between tornado watch and tornado warning

• Sighting of a funnel formation on the ground or in the clouds, or

• Hearing a roar that sounds like a jet or a locomotive.

Tornados and Severe Storms

_____ Be Aware of Changing Weather Conditions

1. Tornado watch - conditions are right for the formation of a tornado.

2. Tornado warning - a tornado has been sighted but is not in the area at this time.

3. Tornado alert - a tornado has been sighted in the immediate area - take cover

immediately.

_____ If Severe Weather Conditions Threaten

1. Sound fire alarm.

2. Alert facility personnel of condition.

3. If time permits, all personnel should assemble in an inside room in the facility office

for shelter.

4. If time does not permit, seek shelter in low level area away from glass.

5. Make certain facility personnel are aware of the condition.

6. Stay in shelter until "all clear" has been issued.

If a tornado is a direct threat to a pipeline facility:

• Notify appropriate Company personnel

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• Shut down the pipeline facility

• Inform others and take appropriate shelter, and

• After a tornado passes, correct any damage to the Facility and restart operations after obtaining proper approval.

NOTE: Circumstances may require changing the order in which these guidelines are

performed.

_____ Immediately After the Storm 1. Account for all personnel.

2. Survey for damages to facility property.

3. Initiate team for any repairs if needed (i.e. high tank alarms, lighting, etc.).

4. Refer to this Plan for additional response guidance regarding fires, spills, etc., as

needed.

Earthquake

General Guidelines

In the event of an earthquake and you are located within the Tank Farm, you should take the

following actions as precautionary measures:

_____ Immediately press the Emergency Shutdown Button.

_____ Stop and shut down all loading operations. _____ If you are outside, remain in an open area. Stay away from anything that could potentially fall and injure you. _____ If you are inside, move away from all windows. _____ If absolutely necessary, shut off the main power switch. _____ Notify the On-Duty Supervisor as soon as possible (refer to Figure 2.2 for phone references). _____ When the earthquake has subsided, notify the On-Duty Supervisor with an initial report of damage, injury, etc. If more than one person is available, one person should assess damage while the other person stays by the telephone. _____ If any leaks are noticed, isolate the leak by closing the appropriate valves. Do so only with precautions established in this Plan.


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Tank Farm Operator Guidelines

When the inspection of the Facility is completed, and you are satisfied that there are no leaks,

proceed with the following steps:

_____ Call the Scheduler with an updated report. _____ Turn main power back on (if needed). _____ Activate one product pump at a time. Inspect the product filter area for any leaks. _____ If no leaks appear, turn the pump off and go to the next product. Use this same procedure for each product until all product lines have been tested.

Pipeline Related Guidelines and Special Considerations

In the event of a significant earthquake, regional personnel in the affected area should

immediately contact the Control Center and advise them on operational precautions to be taken.

If the Control Center suspects that there has been an earthquake within a region, they will:

_____ Shut down any system(s) they feel may have been affected. _____ Notify the Region of actions taken. _____ Monitor integrity of suspected systems to degree possible. _____ Await directions of regional personnel before restarting suspected systems.

Guidelines

The following outlines the guidelines the Regional operations should consider for significant

earthquakes.

_____ Shut down and isolate pipelines in the affected area, utilizing the Control Center if possible, until the situation is evaluated. _____ Notify supervision and other internal personnel as appropriate. _____ Evaluate system(s) and emergency response needs. _____ Contact additional maintenance and operations personnel as needed to inspect the following in the affected area for structural, mechanical, and electrical integrity as deemed necessary:

• Pump stations;


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• Tanks; and

• Pipeline(s) in ROW. _____ Perform “stand-up” pressure test(s) as necessary. _____ Advise Control Center on restart of affected systems when management considers it prudent considering the following factors:

• Aftershocks;

• Power and communications reliability;

• Requirements of local authorities; and

• Conditions at the origin and destination facilities. Special Considerations

• When system integrity or other problems are suspected, then consider pipeline surveillance using helicopters or fixed-wing aircraft supplemented with “on the ground” inspections when needed.

• When an earthquake occurs and multiple releases are possible, then consider more than the usual amount of emergency response personnel and equipment.

• When bridges or highways are destroyed or impassible, then use alternative transportation routes or modes to close block valves. Response time may be longer than normal. Consider using helicopters as an alternative to driving.

• When the earthquake causes damage to Paramount employees’ homes in the region and they are occupied with their own personal situations, then get assistance from Paramount locations outside the affected area. Include both personnel and equipment. Use contractors and other service providers needed.

• When regular communication is not functional (down or congested), then establish emergency communication in the region.


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FLOODS, SPECIFIC RESPONSE CCR §817.02(c)(4)(D)

Special Considerations

Below are the special considerations to take into account, depending on the magnitude of the

flooding, amount of damage, and prevalent conditions:

• Be alert to areas of flooding and have personnel available for emergency response actions such as shutdown, isolation, and containment.

• Consider extending regulator vents and relief stacks above the level of anticipated flooding as appropriate.

• Evaluate the accessibility of pipeline facilities, such as valve setting needed to isolate water crossings or other sections of pipeline that might be jeopardized.

• Perform frequent patrols to evaluate right-of-way conditions at water crossings during flooding and after waters subside. Determine if flooding has exposed and/or undermined pipelines as a result of forming new channels or erosion of riverbeds.

• Coordinate with other pipeline companies in the flood area and provide personnel to emergency response centers to act as a liaison for pipeline issues. Provide maps and information on pipeline location and condition to emergency responders.

• Determine if normally aboveground facilities (valves, regulator and relief sets, etc.) that have become submerged could be struck by craft operating in flooded areas and supply maps to emergency response centers and mark with buoys, as appropriate.

• Perform surveys to determine the depth of cover over pipelines and notify landowners of reduced cover. Agricultural agencies may be helpful in reminding farmers of the potential hazard of reduced cover over pipelines.

• Assure that line markers are still in place and remind contractors, highway departments, and others involved in excavation and clearing activities associated with flood clean-up of the presence of pipelines and the operating hazards that could occur due to reduced pipeline cover.


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CONTROLLING GROUND, MARINE, AND AIR TRAFFIC CCR §817.02(f)(4)(C)

The first responder or IC will evaluate the release site to determine whether or not ground and marine traffic will hamper the spill response. The FOSC may evaluate air traffic. In the event that control is required before local state, or federal agencies arrive, the first responder or IC will follow the guidelines presented in the table below.

Traffic Control Needed Response Requirements

Ground Call 911 and describe the location and nature of the release. Request highway patrol, sheriff, police, or fire department assistance. If manpower permits:

• Cordon off the area with hazard cones and yellow hazard tape;

• Consider temporary use of vehicles to barricade streets if vehicular traffic is in danger; and

• Keep pedestrians away from the site.

Marine In the event that such a spill reaches marine waters:

• Notify the Coast Guard immediately;

• Request the Captain of the Port to provide assistance for controlling marine vessels; and

• To the extent possible, warn vessels and boats that traversing the release area may be dangerous and may jeopardize response operations.

Leave patrolling and control activities to the direction of Coast Guard or the Captain of the Port.

Air Contact the Federal Aviation Administration (FAA) if it appears that air traffic control will be required via the FAA Hotline (https://hotline.faa.gov/) (Upon approval, the FAA will immediately issue a Notice to Airmen ("NOTAM")). Be prepared to describe the geographical location, or if known, the latitude and longitude of the release.

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AIR

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CIVIL DISORDER, SPECIFIC RESPONSE

General guidelines for responding to a civil disorder are:

_____ Secure the facility; _____ Contact appropriate Company personnel; _____ Shut down the facility, if necessary; _____ Request protection from police or other law enforcement authorities; and _____ When order is restored, correct any damage to the facility and restart operations after obtaining proper approval.

NOTE: Circumstances may require changing the order in which these guidelines are performed.

CIV

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FIGURE 3.2

PRODUCT SPECIFIC RESPONSE CONSIDERATIONS

FLAMMABLE LIQUIDS (Non-Polar/Water-Immiscible)

The following information is intended to provide the initial responder(s) with data that may be useful in making quick decisions and executing prompt response actions. The information is intended for guideline purposes only.

PRODUCTS Diesel Gasoline Crude Gas Oil

HAZARD IDENTIFICATION / RECOGNITION

GUIDE NO. 128

DANGERS • HIGHLY FLAMMABLE: Will be easily ignited by heat, sparks or flames.

• Vapors may form explosive mixtures with air.

• Vapors may travel to source of ignition and flash back.

• Most vapors are heavier than air. They will spread along ground and collect in low or confined areas (sewers, basements, tanks).

• Vapor explosion hazard indoors, outdoors or in sewers.

• Those substances designated with a “P” may polymerize explosively when heated or involved in a fire.

• Runoff to sewer may create fire or explosion hazard.

• Containers may explode when heated.

• Many liquids are lighter than water.

• Substance may be transported hot.

HEALTH • Move victim to fresh air. Call 911 or emergency medical service.

• Apply artificial respiration if victim is not breathing. Administer oxygen if breathing is difficult.

• Remove and isolate contaminated clothing and shoes.

• In case of contact with substance, immediately flush skin or eyes with running water for at least 20 minutes.

• Wash skin with soap and water.

• Keep victim warm and quiet.

• Ensure that medical personnel are aware of the material(s) involved, and take precautions.

PUBLIC SAFETY • Isolate spill or leak area immediately for at least 25 to 50 meters (80 to 160 feet) in all directions.

• Keep unauthorized personnel away.

• Stay upwind.

• Keep out of low areas.

• Ventilate closed spaces before entering.


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EVACUATION

Large Spill

• Consider initial downwind evacuation for at least 300 meters (1,000 feet). Fire

• If tank, rail car or tank truck is involved in a fire, ISOLATE for 800 meters (1/2 mile) in all directions; also, consider initial evacuation for 800 meters (1/2 mile) in all directions.

Information provided by the Emergency Response Guidebook 2008.

3.2 DOCUMENTATION OF INITIAL RESPONSE ACTIONS

It is difficult, particularly during the first few minutes of an initial response operation

to think about the importance of documentation. A log should be maintained which

documents the history of the events and communications that occur during the

response. When recording this information, it is important to remember that the log

may become instrumental in legal proceedings, therefore:

• Record only facts, do not speculate.

• Do not criticize the efforts and/or methods of other people/operations.

• Do not speculate on the cause of the spill.

• Do not skip lines between entries or make erasures. If an error is made, draw a line through it, add the correct entry above or below it, and initial the change.

• Record the recommendations, instructions, and actions taken by government/ regulatory officials.

• Document conversations (telephone or in person) with government/regulatory officials.

• Request that government/regulatory officials document and sign their recommendations or orders (especially if company personnel do not agree with the suggestions, instructions, or actions).

3.3 ESTABLISHING COMMAND POSTS, COMMUNICATIONS POSTS, AND

STAGING AREAS CCR§817.02(f)(2)(A-C)

3.3.1 Command Post

In the event of a major incident, a command post will be established to

serve as the primary location for the Incident Command staff activities and

the various meetings and briefings held throughout response operations.

It is likely the Paramount Refinery would serve as the command post. In

the event that this is not feasible, an alternative location will be chosen as

appropriate depending on circumstances.

The Logistics Section Chief will be responsible for establishing the

command post, taking care to ensure that the command post is located in

an area sufficiently removed from the incident scene (i.e., in a "safe zone").


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The following additional criteria will be used to determine the most

appropriate location:

• Proximity to the incident;

• Sufficient size to allow response personnel to operate effectively and comfortably;

• Room for conferences, Unified Command meetings, and media briefings;

• Secure phone and fax lines;

• Adequate security;

• Office support systems (such as fax machines, photocopiers, telephone lines, computers, file system, AM radios, VHF/UHF radio telephone, base communication station);

• Adequate sanitation facilities; and

• Site surveillance, if safe and desirable.

3.3.2 Communications Post

The communications post will most likely be located in or near the

command post.

3.3.3 Field Command Post

A field command post may also be established at the scene of the incident.

The primary function of the field command post is to conduct all activities

which are directed toward reduction of the immediate hazard, including

recovery and cleanup operations.

3.3.4 Staging Areas

In a major spill response, numerous staging areas may be required to

support containment and cleanup operations.

Staging areas will need to be equipped with prime movers, cranes, and

other machinery necessary to load/unload response equipment and

supplies to trucks, vessels, etc.

Personnel at staging areas will need to establish inventory control systems

to track equipment use.

In selecting a suitable staging area, the following criteria should be

considered:

• Access ability to impacted areas;

• Proximity to secure parking, airports, docks, piers, or boat launches;

• Ability for area to be secured;

• Proximity to populated or environmentally sensitive areas; and


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• Adequate lighting.

3.4 OIL CONTAINMENT, RECOVERY AND DISPOSAL

After initial response has been taken to stop further spillage at the source and

notifications made to the required agencies, the Company will begin spill

containment, recovery, and disposal operations for any released material.

The Incident Commander will assess the size and hazards of the spill. The type of

product, the location of the spill, and the predicted movement of the spill will be

considered.

Based on this assessment, additional clean up personnel and equipment will be

dispatched to the site and deployed to control and contain the spill. Boom may be

deployed in waterways to contain the spill and to protect socio-economic and

environmentally sensitive areas. Booms may also be used in waterways to deflect

or guide the spill to locations where it can more effectively be cleaned up using

skimmers, vacuum trucks, or sorbent material. Clean up equipment and material

will be used in the manner most effective for rapid and complete clean-up of all

spilled product.

Response and cleanup will continue until all recoverable product is removed, the

environment is returned to its pre-spill state, and the unified command of the

Company’s Incident Commander and the On-Scene Coordinators determine that

further response and cleanup is no longer necessary.

Containment Procedures CCR §817.02(e)(4)(A)(1-2)

Introduction

The following describes general containment procedures.

Water Surfaces

The following lists some procedures to consider when containing an oil release on

water.

• Eliminate possible sources of ignition.

• Determine the actual speed of oil on water. Remember that oil on water may not travel at the same velocity as the river or stream. Use this knowledge for boom placement.


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• Set booms considering river speeds and oil pickup points. Consider cascading booms if necessary.

Contaminated Surfaces

The following lists some procedures to consider when containing an oil release on

land.

• Eliminate possible sources of ignition. Do not start vehicles in the vicinity of volatile materials that have been released.

• To avoid vapor ignition, divert or stop traffic if the release impacts a roadway.

• Prevent oil from entering into drainage or sewer systems, water courses, irrigation channels, or culverts. Block drains, dam ditches, and boom water courses and irrigation channels.

• Close water intakes.

Responsibility

The Incident Commander is responsible for determining the method or combination

of methods to use to contain a release.

NOTE: The Incident Commander may delegate this responsibility.

Resources

The Spill Management Team and its contractors can help determine the proper

containment procedures to use. In addition, outside experts and consultants can

offer assistance.

Training

To comply with 29 CFR 1910.120(e), all personnel involved in a post-emergency

response must be trained to work safely in hazardous waste operations. The

workers must complete this training before engaging in hazardous waste operations.

To comply with Title 8 of California Code of Regulation, section 5192, subsection

(q), all employees working on site exposed to hazardous substances, health

hazards, or safety hazards shall not be permitted to participate in or supervise field


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activities until they have been trained to a level required by their job function and

responsibility.

Protection Methods

See Table titled “Protection Methods” in Section 6.0.

Trajectory Information

If a release occurs on water, containment personnel need to know the likely direction

and rate of movement of the released material. In rivers and streams, the flow of

the material is generally obvious to the eye.

If the trajectory of the release material is unknown or unpredictable, incident

responders may have to obtain and analyze certain trajectory and weather

information. In addition, response crews may use aerial surveillance. This data can

then be analyzed by:

• Incident Commander;

• Emergency Management; or

• Consultants.

Trajectory Responsibility

The Incident Commander is responsible for determining the need for trajectory data

and the involvement of consultants.


Dispersant Plan

After an incident occurs, the Incident Commander must consider, with Unified

Command, whether dispersants are a viable option.

NOTE: Use of dispersants is prohibited without approval of the Regional Response

Team and confirmation by the FOSC.

In-Situ Burn


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After an incident occurs, the Incident Commander must consider, with Unified

Command, whether in-situ burning is a viable option.

Removal and Cleanup Procedures CCR §817.02(e)(4)(A)(2)

Introduction

The following describes general removal and cleanup procedures.

Water Surfaces

The Shoreline Cleanup Assessment Team (SCAT) is put together by the Federal

On-Scene Coordinator. The Incident Commander and the cleanup coordinator

should participate in the SCAT.

Contaminated Surfaces

There are several possible methods to use. See heading “Advantages and

Disadvantages” in Section 6.0 for a detailed description of the methods.

Consider these precautions:

• Use high-pressure flushing only as a last resort and as approved by appropriate agencies; and

• Burn only materials such as contaminated twigs and branches when properly permitted.

Responsibility

The Incident Commander is responsible for determining the method or combination

of methods to use to remove and clean up a release.


Resources


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Contact your local environmental representative for determining the proper removal

and cleanup procedures to use. In addition, outside experts and consultants can

offer assistance.

Training

To comply with 29 CFR 1910.120(e), all personnel involved in a post-emergency

response must be trained to work safely in hazardous waste operations.

The workers must complete this training before engaging in hazardous waste

operations. In addition, they must know about:

• Site characterization and analysis; and

• Site Safety and Health Plan.

The Site Characterization and Analysis is a description of the oil spill, worksite, and

status of cleanup operations. The Site Safety and Health Plan describe safety and

health subjects that are relevant to the particular oil spill.

3.5 TEMPORARY STORAGE/DISPOSAL

Strict rules designed to ensure safe and secure handling of waste materials govern

the Company’s waste disposal activities. To ensure proper disposal of recovered

oil and associated debris, the following guidelines should be considered:

• The State will need to quantify waste before it leaves.

• In the event of a product spill, separated product will be pumped to trucks to be carried to the Refinery for processing.

• The recovered product and water will be stored at the Refinery until it is recycled.

• Oily debris will be segregated on site and containerized for temporary storage prior to disposal in accordance with RCRA/CERCLA regulations and state and local requirements.

• Transportation of waste material will be performed in accordance with all applicable federal and state guidelines.

• Waste associated with the spill will be disposed of at Company pre-approved sites which have the necessary permits to accept the type of waste to be discharged.

The Company’s Safety and Environmental Departments will coordinate activities

and secure the necessary permits to ensure proper disposal or recycling of

recovered product and debris.


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3.6 SAMPLING

The Company’s sampling and waste analysis practices are governed by the

regulations for the applicable state and the United States Environmental Protection

Agency (EPA). These regulations outline methods and procedures for determining

the chemical and physical characteristics of wastes generated by the facility,

including waste associated with spills, so that they may be properly stored, treated,

or disposed of.

3.7 SAFETY AWARENESS

It is the corporate policy of the Company to provide a safe workplace for all workers.

All employees and contractors are responsible for maintaining the safety and health

of all workers at the Facility and the response operations.

Prior to engaging in any spill response activity:

• All employees/contractors must have received orientation from the Company’s Safety Plan.

• All contractor response personnel must be in compliance with CALOSHA training requirements.

• All other personnel will have completed appropriate training for their position as outlined in Section 4.0.

• No employee/contractor shall engage in activities which place them at risk without the appropriate protective equipment and training.

3.7.1 General Response Safety

All Company and contractor personnel are expected to comply with the Site

Safety and Health Plan for each spill incident. This document has been

written as a supplement to the Paramount Safety and Health Plan or to

whatever specific Health and Safety Plan that may be written by a

contractor working at the Paramount Pipelines and Lakewood Tank Farm

to fulfill the Company’s language contained in specific contract documents

between the contractor and the Company.

• Any concern regarding health or safety issues should be immediately addressed.

• The First Responder must consider the spill site as dangerous and the local atmosphere explosive until air monitoring procedures prove that the area is safe.

• The First Responder must exit the area against or across the wind if possible and must also evacuate others who are working in the area.

• All injuries, no matter how minor, must be reported to management in a timely manner.

• Prior to entering a spill area, a qualified person must perform an initial safety and health evaluation of the site.


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3.7.2 Air Monitoring

• A Safety Monitor shall be designated who is trained in the operation of air monitoring equipment. The Incident Commander must ensure that Safety Monitors are trained and that their equipment is maintained and ready for use.

• The air monitoring equipment shall be activated and checked at the location in which it is stored.

• Air monitoring measurements which are to be made prior to entry into the spill area include:

o Lower explosive limit (LEL); o Oxygen content; and o Benzene level.

• LEL readings above 10% require immediate evacuation of the area and elimination of ignition sources.

• Oxygen readings below 19.5% require the use of air supplied respiratory protection.

• After assuring that there are no hazards relating to explosion or oxygen depletion, sampling for benzene shall dictate the appropriate respiratory devices to be used by persons entering the area as follows:

Benzene

o 0.50 PPM or less, none required o 0.50 to 1.0 PPM, half face air purifying o to 50.0 PPM, full face air purifying o 50.0 PPM or greater, pressure demand SCBA

• The Incident Commander is responsible for industrial hygiene monitoring in the post discovery period.


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3.7.3 Decontamination CCR §817.02(f)(8)

Through training programs, site personnel know and understand the

importance of the removal of hazardous substances from their person if

they are contaminated. Within the facility, eyewash stations and, in some

cases, safety showers are located strategically to quickly remove gross

contamination of harmful agents, including gasoline. For offsite releases a

temporary shower will be constructed for decontamination. Personnel must

immediately shower and remove any clothing which is wet or otherwise

contaminated. Showers in the change room are to be used for thorough

cleansing. Persons should inspect themselves thoroughly before donning

a fresh change of clothing. Employees who become saturated with gasoline

should supply a urine sample (for the benzene standard’s phenol test) at

the end of their shift.

Contaminated clothing should be allowed to dry, protected from an ignition

source, then laundered before wearing again. Contaminated personal

protective equipment must be washed and sanitized before re-using. The

washing of contaminated equipment is performed in a “contained area” to

assure that the disposal of the wash water can be handled properly.

Establishing "Exclusion - Hot", "Decontamination - Decon", and "Support -

Safe" zones are required to prevent the removal of contaminants from the

containment area as well as unauthorized entry into contaminated areas.

• Regardless of the decontamination facilities available, all efforts to minimize personnel exposure should be taken.

• Decontamination facilities should be positioned prior to employee/ contractor entrance to areas where the potential for exposure to contamination exists. The appropriate Material Safety Data Sheets (MSDS) are available to aid health professionals treating the injured parties. SDS are separately maintained at the Facility.

• Decontamination facilities should be designed to prevent further contamination of the environment and should have a temporary storage area for items that will be reused in the contaminated area.

• Particular attention should be paid to personal hygiene prior to eating, drinking, or smoking.

• The appropriate decontamination procedure will depend on the contaminant and its physical properties. The decontamination stations and process should be confined to the Contamination Reduction Zone. Steps for personnel decontamination are outlined on the following page.


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• Access will be handled by the lead OSRO contractor on site per their policies and procedures.

Eight-Step Decontamination Plan For Personnel

Step 1. Contaminated tools and equipment drop -Plastic sheet

Step 2. Contaminated trash drop

Hot Line

Step 3. Boot and glove wash/rinse

(SCBA and mask if Level B)

Step 4. Primary garment removal -Most obviously contaminated piece first -Provide for contaminated trash

Step 5. Facepiece removal/drop -Can be combined with Stations 7 & 8

Step 6. Boot drop

Step 7. Inner glove removal

Contamination Control Line

Step 8. Shower and clothing change

Exclusion or Hot Zone

Returning with fresh air tanks and clean primary garment and outer gloves/boots.

3.a. Air Tank Charge

Contamination

Reduction Zone

Support/Clean Zone

• Additional information regarding decontamination requirements can

be found in the Facility Manual.


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3.7.4 Personnel Protective Equipment (PPE)

All PPE will be provided by the Oil Spill Response Operator such as

MSRC. The following represents CALOSHA/EPA designated PPE levels

for responding to emergencies, post emergency cleanup sites, and/or

Temporary Storage and Disposal (TSD) sites. The responder’s PPE

should be chosen based on his/her level of training and assigned job

duties.

Personal Protective Equipment

LEVEL A

• Self-Contained Breathing Apparatus (SCBA) (worn inside suit);

• Encapsulated chemical protective suit;

• Chemical protective gloves;

• Chemical protective boots; and

• Hard hat.

LEVEL B

• SCBA (worn outside suit);

• Chemical protective suit with hood;

• Chemical protective boots;

• Chemical protective gloves; and

• Hard hat.

LEVEL C

• Air purifying respirator (APR);

• APR ½ face /full face;

• Hard hat;

• Glasses (worn with ½ face APR);

• Chemical protective boots;

• Chemical protective gloves; and

• Chemical protective suit/Tyvek).

LEVEL D

• Hard hat;

• Safety glasses;

• Work uniform / clothes;

• Leather gloves;

• Safety boots; and

• Nomex.

MODIFIED LEVEL C

Same as Level C except no APR requirements.

3.8 EMERGENCY MEDICAL TREATMENT AND FIRST AID CCR §817.02(f)(4)(B)

The Lakewood Tank Farm has arrangements for medical emergencies and first aid.

The local contract physician’s name, address, and phone number are posted on the

facility bulletin board and in Section 2.0. For medical advice and consultation on

matters of facility health, the local doctor and/or Emergency Medical Technician.


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They should be consulted. This information can also be found on the facilities

bulletin board and in Section 2.0.

On-site emergency medical response requires the same rapid assessment of the

patient as any other situation, but requires the responders to be aware of other

considerations that may affect the way they handle the patient. These

considerations include the following:

• The potential for contamination of the patient, responders, and equipment should be addressed. Responders should arrange to treat all patients AFTER the injured party has been decontaminated according to the Site Safety and Health Plan.

• Site personnel should make the initial assessment of the patient and determine the severity of the injury/illness.

• If the treatment needed is critical care or "life saving" treatment, rapid decontamination of the injured/ill party should be started. Refer to the Site Safety and Health Plan for steps to be taken in an "abbreviated" decontamination for medical treatment.

• The need for full decontamination should be carefully weighed against the need for prompt medical treatment.

• The ambulance responding to medical emergencies shall be contacted as soon as possible and instructed exactly where to respond when needed and the nature of the contaminant. Telephone reference is provided in Figure 2.5.

• Two persons should be sent to meet external emergency responders and guide them to the incident location, if the incident location is internal to the Facility. Two individuals are necessary as emergency responders may not all arrive at the same time.

• SDS information is maintained at nearest field office and will be available from the Incident Commander and should be provided to medical personnel to alert them of decontamination requirements.

• If emergency medical treatment is needed, the Incident Commander will request assistance from trained medical personnel.

3.9 SITE SAFETY AND HEALTH PLAN(S) DEVELOPMENT

The Incident Commander or Safety Representative is responsible for preparing a

Site Safety and Health Plan that establishes site-specific policies, practices, and

procedures to protect workers and the public from contacting potential chemical

and/or physical hazards. A Site Safety and Health Plan will:


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• Describe who is responsible for monitoring site safety.

• Characterize the risks associated with each operation that will be conducted in the area covered by the plan.

• Describe known chemical and physical hazards, and the measures that have been instituted to eliminate the hazards or reduce them to acceptable levels.

• Define the level of HAZWOPER training required for workers commensurate with their job responsibilities.

• Describe site control measures, and will include a site map.

• Describe decontamination procedures for personnel and equipment.

The Site Safety and Health Plan prior to response.

3.10 DRUG AND ALCOHOL TESTING CCR §817.02(c)(5)(D)

All personnel (including supervisors and contractors) associated with the operation

and maintenance of the pipeline facilities covered by this Plan are subject to drug

and alcohol testing as dictated by the United States Department of Transportation

(DOT) under 49 CFR part 199. These regulations provide for mandatory pre-

employment, random, and post accident drug and alcohol testing.


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4 RESPONSE TEAMS

4.1 INTRODUCTION

The Company utilizes the Incident Command System (ICS) to manage emergency

response activities. The ICS is a management tool that is readily adaptable to very

small incidents as well as those of considerable significance. ICS shall be

implemented for all discharge incidents. The staffing levels required to meet the

specific needs of the incident will be based on its size and severity.

The first response to a discharge originating from this operation will be provided by

the local responders. In the event that the response operation is beyond the

capability of the local responders (Local Response Team), the Incident

Commander/Qualified Individual will activate the Spill Management Team.

A detailed explanation of the Incident Command System and the roles and

responsibilities for primary members of the Spill Management Team are provided in

this Section.

4.2 QUALIFIED INDIVIDUAL

Vital duties of the Qualified Individual (QI) which can be delegated for efficiency of

response:

• Activate internal alarms and hazard communication systems to notify all Facility personnel.

• Notify all response personnel, as needed.

• Identify the character, exact source, amount, and extent of the release, as well as the other items needed for notification.

• Notify and provide necessary information to the appropriate federal, state, and local authorities with designated response roles, including the National Response Center (NRC), State Emergency Response Commission (SERC), and local response agencies.

• Serve as liaison with the On-Scene Coordinator.

• Assess the interaction of the spilled substance with water and/or other substances stored at the Facility and notify response personnel at the scene of that assessment.

• Assess the possible hazards to human health and the environment due to the release. This assessment must consider both the direct and indirect effects of the release (i.e., the effects of any toxic, irritating, or asphyxiating gases that may be generated or the effects of any hazardous surface water runoffs from water or chemical agents used to control fire and heat-induced explosion).

• Assess and implement prompt removal actions to contain and remove the substance released.

• Coordinate rescue and response actions as previously arranged with all response personnel.


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• Access Company funding to initiate clean-up activities.

• Direct clean-up activities until properly relieved of this responsibility.

Arrangements will be made between the QI and the Alternate Qualified Individual

(AQI) to ensure that either one or the other is available on a 24-hour basis and is

able to arrive at the Facility in a reasonable amount of time. The AQI shall replace

the QI in the event of his absence and have the same responsibilities and authority.

4.3 LOCAL RESPONSE TEAM

The first Company person on scene will function as the Incident Commander (IC)

and person-in-charge until relieved by an authorized supervisor who will then

assume the position of IC. Transfer of command will take place as more senior

management respond to the incident. For response operations within the control of

the Local Response Team (LRT), the role of IC will typically be assumed and

retained by Management.

The number of positions/personnel required to staff the LRT will depend on the size

and complexity of the incident. The duties of each position may be performed by

the IC directly or delegated as the situation demands. The IC is always responsible

for directing the response activities and will assume the duties of all the primary

positions until the duties can be delegated to other qualified personnel.

A complete functional ICS organization is show in Figure 4.1. The LRT should try

to fill the necessary positions and request additional support from the Spill

Management Team to fill/back up all the positions as the incident may dictate.

4.4 SPILL MANAGEMENT TEAM

For spill response operations outside the capabilities of the LRT, the QI or IC will

determine the need for mobilization of the Spill Management Team (SMT). The

members of the LRT will typically become members of the SMT.

The SMT, once fully staffed, is designed to cover all aspects of a comprehensive

and prolonged incident response. The number of positions/personnel required to

the staff the SMT will depend on the size and complexity of the incident. During a

prolonged response, additional personnel may be transferred in, and more than one

level within the Team may be involved to sustain 24-hour operations.

Led by the Incident Commander, the SMT is composed of the following principal

components:

• Command


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• Logistics

• Planning

• Finance

• Operations

The SMT is staffed by specially trained personnel from various corporate locations

and various contract resources as the situation requires. The SMT organization

chart is provided in Figure 4.1; telephone reference is provided in Figure 2.2.

Command and Unit Leader responsibilities are described in Section 4.8.

4.5 INCIDENT COMMAND SYSTEM

The Incident Command System is intended to be used as a management tool to aid

in mitigating all types of emergency incidents. This system is readily adaptable to

very small emergency incidents as well as more significant or complex emergencies.

The Incident Command System (ICS) utilizes the following criteria as key

operational factors:

• Assigns overall authority to one individual;

• Provides structured authority, roles and responsibilities during emergencies;

• Is simple and familiar, and is used routinely at all incidents;

• Allows structured communication;

• Is a structured system for response and assignment of resources;

• Provides for expansion, escalation, and transfer/transition of roles and responsibilities; and

• Allows for “Unified Command” where outside agency involvement at the command level is required.

Effective establishment and utilization of the ICS during response to all types of

emergencies can:

• Provide for increase safety;

• Shorten emergency mitigation time by providing more effective and organized mitigation;

• Cause increased confidence and support from local, state, and federal emergency response personnel; and

• Provide a solid cornerstone for emergency planning efforts.

Section 4.8 provides a comprehensive list of every response team member’s duty

assignment.


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4.6 UNIFIED COMMAND

As a component of an ICS, the Unified Command (UC) is a structure that brings

together the Incident Commanders of all major organizations involved in the incident

to coordinate an effective response while still meeting their own responsibilities. The

Unified Command (UC) system links the organizations responding to the incident

and provides a forum for the Responsible Party and responding agencies and

responders may blend together throughout the organization to create an integrated

response team. The UC process requires the UC to set clean objectives to guide

the on-scene response resources.

Multiple jurisdictions may be involved in a response effort utilizing the Unified

Command of the Incident Command System. These jurisdictions could be

represented by any combination of:

• Geographic boundaries;

• Government levels;

• Functional responsibilities; and

• Statutory responsibilities

The participants of the UC for a specific incident will be determined by taking into

account the specifics of the incident and existing response plans and/or decisions

reached during the initial meeting of the UC. The UC may change as an incident

progresses, in order to account for changes in the situation.

The UC is responsible for overall management of an incident. The UC directs

incident activities and approves appropriation and release of resources. The UC

structure is a vehicle for coordination, cooperation and communication which is

essential to an effective response.

UC representatives must be able to:

• Agree on common incident objectives and priorities;

• Have the capability to sustain a 24-hour-7-days-a-week commitment to the incident;

• Have the authority to commit agency or company resources to the incident;

• Have the authority to spend agency or company funds;

• Agree on an incident response organization;

• Agree on the appropriate Command and General Staff assignments;

• Commit to speak with “one voice” through the Information Officer or Joint Information Center.


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• Agree on logistical support procedures; and

• Agree on cost-sharing procedures

4.7 DISCHARGE CLASSIFICATION

The severity of a discharge will have a bearing on the level of management

involvement necessary and the extent of resource mobilization. The following

definitions provide guidance in the early classification of discharges:

TIER I EVENT

Incident Command will normally be assumed by Facility Management. Regional and Head Office support will be utilized on an as needed basis.

Exposure

The potential public and environmental exposure is moderate. The type and quantity of material released, while considering the overall nature of the incident (e.g. fire, proximity to private dwellings, etc.), will have moderate impact on the public and/or the environment.

Degree of Control

The incident can be controlled in a short period of time through implementation of the local resources available to the Facility (including contract resources).

Governmental Involvement

Government involvement will be moderate and generally restricted to state and local levels.

Media Involvement

Media interest will be moderate and generally restricted to state and local levels.

TIER II EVENT

Local Company resources may have to be supplemented with Head Office and external resources to manage the spill incident.

Exposure

The potential public and environmental exposure is moderately high. The type and quantity of material released, while considering the overall nature of the incident (e.g. fire, proximity to private dwellings, etc.), will have moderate impact on the public and/or the environment.

Degree of Control

The incident can be brought under control in a moderate period of time through implementation of the local resources available to the Facility (including contract resources) with possible implementation of regional resources.


Government involvement will be moderately high and generally restricted to regional levels.

Media Involvement

Media interest will be moderately high and generally restricted to regional levels.


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TIER III EVENT

Maximum Company and external resources must be implemented to respond to the spill incident. Activation of the Crisis Management Team would be anticipated during a Tier III incident.

Exposure

The potential public and environmental exposure is significant. The type and quantity of material released, while considering the overall nature of the incident (e.g. fire, proximity to private dwellings, etc.), will have significant impact on the public and/or the environment.

Degree of Control

Maximum Company and third-party resources must be implemented in order to gain control of the incident.


Government involvement will be high.

Media Involvement

Media interest will be high.


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FIGURE 4.1

LOCAL RESPONSE TEAM

*NOTE: Spill

Management Team (SMT) personnel can assume any of these positions as

necessary.

INCIDENT

COMMANDER*

INFORMATION

OFFICER SAFETY OFFICER

LIAISON

OFFICER LEGAL OFFICER

OPERATIONS

SECTION

CHIEF*

PLANNING

SECTION

CHIEF*

LOGISTICS

SECTION

CHIEF*

FINANCE

SECTION

CHIEF*


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4.8 ICS ROLES AND RESPONSIBILITIES

COMMON RESPONSIBILITIES The following is a checklist applicable to all personnel in an ICS organization:

• Receive assignment, including: o Job assignment; o Resource order number and request number; o Reporting location; o Reporting time; o Travel instructions; and o Special communications instructions.

• Upon arrival, check-in at designated check-in location.

• Receive briefing from immediate supervisor.

• Acquire work materials.

• Supervisors maintain accountability for assigned personnel.

• Organize and brief subordinates.

• Know your assigned radio frequency(s) and ensure communications equipment is operating properly.

• Use clear text and ICS terminology (no codes) in all communications.

• Complete forms and reports required of the assigned position and send to Documentation Unit.

• Maintain unit records, including Unit/Activity Log.

• Respond to demobilization orders and brief subordinates regarding demobilization.

UNIT LEADER RESPONSIBILITIES In ICS, a Unit Leader’s responsibilities are common to all units in all parts of the

organization. Common responsibilities of Unit Leaders are listed below.

• Review common responsibilities.

• Receive briefing from Incident Commander, Section Chief or Branch Director, as appropriate.

• Participate in incident planning meetings, as required.

• Determine current status of unit activities.

• Order additional unit staff, as appropriate.

• Determine resource needs.

• Confirm dispatch and estimated time of arrival of staff and supplies.

• Assign specific duties to staff; supervise staff.

• Develop and implement accountability, safety and security measures for personnel and resources.

• Supervise demobilization of unit, including storage of supplies.

• Provide Supply Unit Leader with a list of supplies to be replenished.

• Maintain unit records, including Unit/Activity Log.


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INCIDENT COMMANDER • Assess the situation and/or obtain a briefing from the prior IC.

• Determine Incident Objectives and Strategy. o Keep the public informed of response activities. o Manage a coordinated response effort. o Maximize protection of environmentally sensitive areas. o Contain and recover spilled material. o Recover and rehabilitate injured wildlife. o Remove oil from impacted areas. o Minimize economic impacts. o Keep stakeholders informed of response activities.

• Establish the immediate priorities. o Ensure the safety of citizens and response personnel. o Control the source of the spill.

• Establish an Incident Command Post (ICP).

• Brief Command Staff and Section Chiefs.

• Review meetings and briefings.

• Establish an appropriate organization.

• Ensure planning meetings are scheduled as required.

• Approve and authorize the implementation of an Incident Action Plan (IAP).

• Ensure that adequate safety measures are in place.

• Coordinate activity for all Command and General Staff.

• Coordinate with key people and officials.

• Approve requests for additional resources or for the release of resources.

• Keep Company administrator(s) informed of incident status.

• Approve the use of trainees, volunteers, and auxiliary personnel.

• Authorize release of information to the news media.

• Ensure incident Status Summary (Figure 5.9) is completed and forwarded to appropriate higher authority.

• Order the demobilization of the incident when appropriate.

INFORMATION OFFICER • Determine from the IC if there are any limits on information release.

• Develop material for use in media briefings.

• Obtain IC approval of media releases.

• Inform media and conduct media briefings.

• Arrange for tours and other interviews or briefings that may be required.

• Obtain media information that may be useful to incident planning.

• Maintain current information summaries and/or displays on the incident and provide information on he status of the incident to assigned personnel.


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LIAISON OFFICER • Be a contact point for agency representatives.

• Maintain a list of assisting and cooperating agencies and agency representatives. Monitor check-in sheets daily to ensure that all agency representatives are identified.

• Assist in establishing and coordinating interagency contacts.

• Keep agencies supporting the incident aware of incident status.

• Monitor incident operations to identify current or potential inter-organizational problems.

• Participate in planning meetings, providing current resource status, including limitations and capability of assisting agency resources.

• Coordinate response resource needs for Natural Resource Damage Assessment and NRDAR activities with the Operations Section during oil and HAZMAT responses.

• Coordinate response resource needs for incident investigation activities with the Operations Section.

• Ensure that all required agency forms, reports and documents are completed prior to demobilization.

• Have debriefing session with IC prior to departure.

• Coordinate activities of visiting dignitaries.

SAFETY OFFICER • Participate in planning meetings.

• Identify hazardous situations associated with the incident.

• Review the IAP for safety implications.

• Exercise emergency authority to stop and prevent unsafe acts.

• Investigate accidents that have occurred within the incident area.

• Assign assistants, as needed.

• Review and approve the medical plan.

• Develop the Site Safety Plan and publish Site Safety Plan summary (Figure 5.14) as required.

LEGAL OFFICER • Participate in planning meetings, if requested.

• Advise on legal issues relating to in-situ burning, use of dispersants, and other alternative response technologies.

• Advise on legal issues relating to differences between Natural Resource Damage Assessment and Restoration (NRDAR) and response activities.

• Advise on legal issues relating to investigations.

• Advise on legal issues relating to finance and claims.

• Advise on legal issues relating to response.


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OPERATIONS SECTION CHIEF • Develop operations portion of IAP.

• Brief and assign Operations Section personnel in accordance with the IAP.

• Attend planning meetings.

• Supervise Operations Section.

• Determine need for and request additional resources.

• Review suggested list of resources to be released and initiate recommendation for release of resources.

• Assemble and disassemble Strike Teams assigned to the Operations Section.

• Report information about special activities, events, and occurrences to the IC.

• Respond to resource requests in support of NRDAR activities.

• Resolve logistic problems reported by subordinates.

• Approve accident and medical reports originating within the Branch.

PLANNING SECTION CHIEF

• Collect and process situation information about the incident.

• Supervise preparation of the IAP.

• Provide input to the IC and the Operations Section in preparing the IAP.

• Chair planning meetings and participate in other meetings as required.

• Reassign out-of-service personnel already on-site to ICS organizational positions as appropriate.

• Establish information requirements and reporting schedules for Planning Section Units (e.g., Resources, Situation Units).

• Determine the need for any specialized resources in support of the incident.

• If requested, assemble and disassemble Strike Teams and Task Forces not assigned to Operations.

• Establish special information collection activities as necessary (e.g., weather, environmental, toxics, etc.).

• Assemble information on alternative strategies.

• Provide periodic predictions on incident potential.

• Report any significant changes in incident status.

• Compile and display incident status information.

• Oversee preparation and implementation of the Incident Demobilization Plan.

• Incorporate plans (e.g., Traffic, Medical, Communications, Site Safety) into the IAP.


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LOGISTICS SECTION CHIEF • Plan the organization of the Logistics Section.

• Assign work locations and preliminary work tasks to Section personnel.

• Notify the Resources Unit of the Logistics Section units activated including names and locations of assigned personnel.

• Assemble and brief Branch Directors and Unit Leaders.

• Participate in preparation of the IAP.

• Identify service and support requirements for planned and expected operations.

• Provide input to and review the Communications Plan, Medical Plan and Traffic Plan.

• Coordinate and process requests for additional resources.

• Review the IAP and estimate Section needs for the next operational period.

• Advise on current service and support capabilities.

• Prepare service and support elements of the IAP.

• Estimate future service and support requirements.

• Receive Incident Demobilization Plan from Planning Section.

• Recommend release of Unit resources in conformity with Incident Demobilization Plan.

• Ensure the general welfare and safety of Logistics Section personnel.

FINANCE/ADMINISTRATION SECTION CHIEF • Attend planning meetings, as required.

• Manage all financial aspects of an incident.

• Provide financial and cost analysis information, as requested.

• Gather pertinent information form briefings with responsible agencies.

• Develop an operating plan for the Finance/Administration Section; fill supply and support needs.

• Determine the need to set up and operate an incident commissary.

• Meet with assisting and cooperating agency representatives, as needed.

• Maintain daily contact with Company administrative headquarters on finance/administration matters.

• Ensure that all personnel time records are accurately completed and transmitted, according to policy.

• Provide financial input to demobilization planning.

• Ensure that all obligation documents initiated at the incident are properly prepared and completed.

• Brief administrative personnel on all incident-related financial issues needing attention or follow-up prior to leaving incident.


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5 RESPONSE PLANNING

5.1 INCIDENT ACTION PLAN

Emergency response activities are planned and coordinated through the use of an

Incident Action Plan (IAP) which is developed for each Operational Period of a

response by the Incident Management Team. For small responses, an ICS 201

(Incident Briefing Form provided in this Section), may be used as the IAP and for all

incidents, the ICS 201 will serve as the initial IAP.

For larger or more complex incidents a more complete IAP will be necessary. These

IAP’s are generally created through the completion and compilation of several

standard ICS forms. These forms include, but are not limited to:

ICS FORM NUMBER FORM TITLE PREPARED BY*

201 Incident Briefing Initial Response IC

None ICS IAP Cover Situation Unit Leader

202 Incident Objectives Planning Section Chief

203 Organization Assignment List Resources Unit Leader

204 Assignment List Operations Section Chief &

Resources Unit Leader

205 Incident Radio Communications

Plan

Communications Unit Leader

206 Medical Plan Medical Unit Leader

207 Incident Organization Resources Unit Leader

209 Incident Status Summary Incident Commander

214 Unit Log Situation Unit Leader

218 Support Vehicle Inventory Ground Support Unit Leader

220 Air Operations Summary Air Operations Branch Director

232 Resources at Risk Summary Situation Unit Leader

SSP Site Safety Plan Safety Officer

* The Planning Section Chief may assign preparation of forms to other personnel on

the Incident Management Team if identified position is unassigned or vacant when

the IAP is produced.

Depending on the nature and severity of the emergency, additional documents may

be included in the IAP. These may include:

• Sensitivity Maps (Provided in Section 6);

• Waste Management & Disposal Plans (Provided in Appendix B)’

• Plans for use of Alternative Technologies (Dispersant/In-situ Burning/Bioremediation;


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• Security Plans;

• Decontamination Plans; and

• Traffic Plans

5.2 SITE SAFETY PLAN

Site Safety Plans (SSP) are required by OSHA (29CFR1910.120(b)(4)) for all

hazardous waste operations. The SSP should address all on-site operations and

hazardous as well as on-site emergency procedures. A template for use in

producing an SSP is provided in this Section.

The SSP is typically prepared by the Safety Officer and approved by the Incident

Commander. All personnel must be familiar with the contents of the SSP and the

SSP must be updated as conditions, operations and hazards associated with the

response change.

5.3 ICS FORMS

https://www.nwcg.gov/publications/ics-forms

https://www.nwcg.gov/publications/ics-forms


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6 SPILL IMPACT CONSIDERATIONS

6.1 CRITICAL AREAS TO PROTECT

The critical areas to protect are classified as high, moderate, and low sensitivity to

oil for non-coastal/inland environments. The Federal, State, and Local authorities

will further clarify these categories at the time of the response. The categories are

defined as follows:

HIGH SENSITIVITY

• Areas which are high in productivity, abundant in many species, extremely sensitive, difficult to rehabilitate, or inhabited by threatened/endangered species.

• Areas which consist of forested areas, brush/grassy areas, wooded lake areas, freshwater marshes, wildlife sanctuaries/refuges, and vegetated river/stream banks.

MODERATE SENSITIVITY

• Areas of moderate productivity, somewhat resistant to the effects of oiling.

• Areas which consist of degraded marsh habitat, clay/silt banks with vegetated margins, and gravel/cobble beaches.

LOW SENSITIVITY

• Areas of low productivity, man-made structures, and/or high energy.

• Areas which consist of gravel, sand, or clay material, barren/rocky riverbanks and lake edges, man-made structures, and concrete/compacted earthen drainage ditches.

SEASONAL SENSITIVITY

• Areas of fluctuating productivity due to seasonal changes and migration.

• Areas which consist of gravel, sand, or clay material, barren/rocky riverbanks and lake edges, man-made structures, and concrete/compacted earthen drainage ditches.

• Areas which consist of forested areas, brush/grassy areas, wooded lake areas, freshwater marshes, wildlife sanctuaries/refuges, and vegetated river/stream banks.

6.2 ENVIRONMENTAL / SOCIO-ECONOMIC SENSITIVITIES

Environmental/Socio-economic sensitivities are of extreme importance when

planning a response effort. The health and safety of the public and the environment,

as well as the protection of the various socio-economic sensitivities, must be

promptly addressed in order to mitigate the extent of damage and minimize the cost

of the clean-up effort.


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All environmental/socio-economic sensitivities are worthy of protection, but must be

prioritized during a response effort. When making decisions on which areas

to designate as collection areas and which to protect, the following sources may be

consulted:

• U.S. Fish and Wildlife Service and related State agencies;

• Applicable Area Contingency Plans; and

• Other industry and private experts. The environmental and socio-economic sensitivities in the vicinity of the Pipeline

have been broken down into specific categories and identified in this Section. To

further clarify the location of the sensitive areas of concern references to published

Area Contingency Plans and Environmental Sensitivity Maps are also provided in

this section.

6.3 WILDLIFE PROTECTION AND REHABILITATION

The Company will work with Federal, State, and local agency personnel to provide

labor and transportation to retrieve, clean, and rehabilitate birds and wildlife affected

by an oil spill, as necessary. Oversight of the Company's wildlife preservation

activities and coordination with Federal, State, and Local agencies during an oil

spill is the responsibility of the Incident Commander.

Special consideration should be given to the protection and rehabilitation of

endangered species and other wildlife and their habitat in the event of an oil spill

and subsequent response. Jurisdictional authorities should be notified and worked

with closely on all response/clean-up actions related to wildlife protection and

rehabilitation. Laws with significant penalties are in place to ensure appropriate

protection of these species.

6.3.1 Endangered/Threatened Species

The U.S. Fish and Wildlife Service (USFWS) and related state agencies

classify the status of various wildlife species in the potentially effected

states. A summary of critical birds, reptiles, mammals, and plant species

status as related to the Pipeline’s operating areas (area of highest oil spill

potential) is presented in Figure 6.1.

6.3.2 Wildlife Rescue

The Company will work with Federal, State, and Local agency personnel

to provide labor and transportation to retrieve, clean, and rehabilitate

wildlife affected by an oil spill, as the situation demands.


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The following are items which should be considered for wildlife rescue and

rehabilitation during a spill response:

• Bird relocation can be accomplished using a variety of deterrents, encouraging birds to avoid areas of spilled oil. Bird relocation can be accomplished by utilizing deterrent methods including:

o Use of visual stimuli, such as inflatable bodies, owls, stationary figures, or helium balloons, etc.

o Use of auditory stimuli, such as propane cannons, recorded sounds, or shell crackers.

o Use of herding with aircraft, boats, vehicles, or people (as appropriate).

o Use of capture and relocation.

6.3.3 Search and Rescue – Points to Consider

• The Company's involvement should be limited to offering assistance as needed or requested by the agencies.

• Prior to initiating any organized search and rescue plan, authorization must be obtained from the appropriate federal/state agency.

• Initial search and rescue efforts, if needed, should be left up to the appropriate agencies. They have the personnel, equipment, and training to immediately begin capturing contaminated wildlife.

• With or without authorization it must be anticipated that volunteer citizens will aid distressed/contaminated wildlife of their own. It is important to communicate that it may be illegal to handle wildlife without express authority from appropriate agencies. Provisions should be made to support an appropriate rehabilitator; however, no support should be given to any unauthorized volunteer rescue efforts.

• The regulatory agencies and response personnel should be provided the name and location of a qualified rehabilitator in the event contaminated wildlife is captured.

• Resources and contacts that can assist with wildlife rescue and rehabilitation are provided in Section 2.0. This list includes:

o Outside rehabilitation organizations o Local regulatory agencies o Other resources

6.4 STAGING AREAS

When establishing personnel and equipment staging areas for a response to a

Pipeline discharge, the following criteria should be evaluated:

• Access to waterborne equipment launching facilities and/or land equipment.


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• Access to open space for staging/deployment of heavy equipment and personnel.

• Access to public services utilities (electricity, potable water, public phone, restroom and washroom facilities, etc.)

• Access to the environmental and socio-economically sensitive areas which are projected for impact.

6.5 CONTAINMENT AND RECOVERY OF SPILLED PRODUCT

General descriptions of various specific response techniques that may be applied

during a response effort are discussed below. Company responders are free to use

all or any combination of these methods as incident conditions require, provided

they meet the appropriate safety standards and other requirements relative

to the situation encountered. Data was obtained from reports, manuals and

pamphlets prepared by the American Petroleum Institute, Environmental Protection

Agency and the United States Coast Guard. The most effective cleanup of a product

spill will result from an integrated combination of clean-up methods. Each operation

should complement and assist related operations and not merely transfer spillage

problems to areas where they could be more difficult to handle.

The spill should be assessed as soon as possible to determine the source, extent

and location of travel. Terrain and other physical conditions downgradient of the

spill site will determine the methods of control at a point in advance of the moving

product. Often, the bulk of a spill can be contained at a single location or a few key

locations in the immediate vicinity of the source point. When possible the execution

of this type of initial containment strategy helps confine a spill to a relatively limited

area.

6.5.1 Spill on Land (Soil Surfaces)

• Confinement Methods Product can be trapped in ditches and gullies by earth dams. Where

excavating machinery is available, dams can be bulldozed to contain lakes

of product. Dams, small and large, should be effectively employed to

protect priority areas such as inlets to drains, sewers, ducts and

watercourses. These can be constructed of earth, sandbags, absorbents,

planks or any other effective method. If time does not permit a large dam,

many small ones can be made, each one holding a portion of the spill as it

advances. The terrain will dictate the placement of the dams. If the spill is

minor, natural dams or earth absorption will usually stop the product before

it advances a significant distance. Cleanup is the main concern in such

situations.


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In situations where vapors from a spill present a clear and present danger

to property or life (possible ignition because of passing automobiles, nearby

houses, or work vehicles approaching the area), spraying the surface of

the spill with dispersant will greatly reduce the release of additional vapors

from the product. This method is especially adapted to gasoline spills on

soil surfaces.

• Removal Methods The recovery and removal of free product from soil surfaces is a difficult

job. The best approaches at present seem to be:

• Removal with suction equipment to tank truck if concentrated in volumes large enough to be picked up. Channels can be formed to drain pools of product into storage pits. The suction equipment can then be used.

• Small pockets may have to be dipped up by hand or absorbent material.

• If practicable after removal of the bulk of the spill, controlled burning presents the possibility of a fast, simple, and inexpensive method of destruction of the remainder of the product. If all other options have been executed and the site is still unsafe for further activity because explosive vapors persist, the vapors may need to be intentionally ignited to prevent an accumulation sufficient to become an explosive mixture, provided the other requirements of these guidelines for controlled burning are met.

Intentional ignition to remove released product should be utilized only if all

of the following conditions are met:

• Other steps and procedures have been executed and a determination has been made that this is the safest remaining method of control.

• Intentional burning will not unduly damage the pipeline, adjacent property, or the environment.

• Controlled burning is permitted by government authorities. Local government authorities to be contacted may include city council, county board of commissioners, city or county fire chiefs, the county forestry commission or fire tower, and the local environmental protection agency. In seeking permission from these authorities, be prepared to convince them that adequate safety precautions have been and will be taken during the operation.

• Controlled burning is conducted with the consent of local landowners.


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• Safety must always be a prime consideration when considering controlled burning of product. Sparks and heat radiation from large fires can start secondary fires and strong winds make fire control difficult. There must be no danger of the fire spreading beyond control limits. All persons must be at a safe distance from the edge of the inflammable area. Remember that all burning must be controlled burning.

6.5.2 Spill on Lake or Pond (calm or slow-moving water)

• Confinement Methods A lake or pond offers the best conditions for removal of product from water.

Although the removal is no easy task, the lake or pond presents the

favorable conditions of low or no current and low or no waves.

The movement of product on a lake or pond is influenced mainly by wind.

The product will tend to concentrate on one shore, bank or inlet. Booms

should be set up immediately to hold the product in the confined area in the

event of a change in wind direction.

If the spill does not concentrate itself on or near a shore (no wind effect),

then a sweeping action using boats and floating booms will be necessary.

The essential requirement for this operation is that it be done very slowly.

The booms should be moved at not more than 40 feet per minute. Once

the slick is moved to a more convenient location (near shore), the normal

operations of removal should begin.

If the slick is small and thin (rainbow effect) and not near the shoreline, an

absorbent boom instead of a regular boom should be used to sweep the

area very slowly and absorb the slick. The product may not have to be

moved to the shoreline.

• Removal Methods If the confined slick is thick enough, regular suction equipment may be used

first; however, in most instances, a floating skimmer should be used. If

judged appropriate or useful, a surface collecting agent should be applied

once the slick is isolated to facilitate the removal. The surface collecting

agent will concentrate the product into a smaller area and make the floating

skimmer work more efficiently. If the floating skimmer starts picking up

excess water (slick becomes thin), do not stop using it if it is not removing

any appreciable amount of product.


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Additions of more surface collecting agent from time to time may improve

the skimming efficiency of the skimmer. It will continue to concentrate the

slick into a smaller area, thus making the film thickness greater. Drawing

the boom closer to the bank as product is removed will also keep film of

product thicker. However, when the slick becomes too thin, the skimmer

should be stopped, and an absorbent applied (with a boat if necessary) to

remove the final amounts.

The floating skimmer (if speed is a must) or hand skimmers (if water is

shallow enough) or both can be used to pick up the product-soaked

absorbent. Before pumping the product-soaked absorbent with a floating

skimmer, insure that the absorbent in question can be pumped and will not

harm the pump.

Several types are nonabrasive to pump internals. If the floating skimmer is

used first, the product-soaked absorbent/water mixture should be pumped

into a tank truck.

A better method of retrieving the product-soaked absorbent is to draw it in

as close to the shore as possible with the booms used to confine the

product initially. The absorbent can then be hand skimmed from the water

surface and placed in drums, on plastic sheets or in lined roll-off boxes. It

should then be disposed of by acceptable means.

The final rainbow on the surface can be removed with additions of more

absorbent.

6.5.3 Spill on Small to Medium Size Streams (relatively fast-flowing creeks)

• Confinement Methods The techniques used for product containment on fast-flowing shallow

streams are quite different from the ones used on lakes, ponds, or other

still bodies of water. The containment and removal processes require a

calm stretch of water to allow the product to separate onto the surface of

the water. If a calm stretch of water does not exist naturally, a deep slow-

moving area should be created by damming. The dam can be constructed

by using sandbags, planks or earth. If a dam is required, it should be

situated at an accessible point where the stream has high enough banks.

The dam should be constructed soundly and reinforced to support the

product and water pressure.

• Underflow dam - The underflow dam is one method that can be used, especially on small creeks. The water is released at the


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bottom, of the dam using a pipe or pipes which are laid during construction of the dam. The flow rate through the pipe must be sufficient to keep the dam from overflowing. One method is to lay the pipe at an angle through the dam (while dam is being constructed) so that the height of the downstream end of the pipe will determine the height the water will rise behind the dam.

• Overflow dam – Another method of containment is the overflow type dam. The dam is constructed so that water flows over the dam, but a deep pool is created which slows the surface velocity of the water. Therefore, the condition of a calm stretch of water is met. The overflow dam may be used where larger flow rates (medium size creeks) of water are involved. With this type dam, a separate barrier (floating or stationary boom) must be placed across the pool created by the dam. The separate barrier arrests the surface layer of product.

At the same time, the water is flowing under the barrier and over the top of the dam. The barrier should be placed at an angle of 45 % across the pool to decrease the effective water velocity beneath it. Also, it helps to concentrate the product at the bank and not all along the barrier. A second barrier should be placed approximately 10 to 15 feet downstream of the first one as a secondary back-up. The stationary boom type barrier should be made of wood planks or other suitable material. The stationary boom should be soundly constructed and sealed against the bank. The ends of the planks can be buried in the banks of the stream and timber stakes driven into the stream bed for support as needed. The necessary length of the boom will be approximately 1-1/2 times the width of the waterway. The plank boom should extend six to eight inches deep into the water and about two inches or higher above the water level. If the increase in velocity under the stationary boom is causing release of trapped product, it should be moved upward slightly. At no time should barrier be immersed more than 20% of the depth of the pool at the barrier location; that is, if the pool created by damming is three feet deep, do not exceed an immersion depth of seven inches with the barrier at the position the barrier is installed. Another method used with the underflow dam is having the pipe or pipes sized to carry only a portion of the flow needed. The pipe would be placed at the bottom of the dam and level with the creek bed. The remaining flow of the creek could be siphoned or preferably pumped around the dam from a point away from the dam and from the deepest portion of the pool. The pumping or siphoning


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can be controlled to maintain the desired water level at the dam. The key is the removal of water through or around the dam at the lowest point in the basin. This prevents the oil from escaping with the released water. A floating boom can be used in place of the stationary type if the created pool’s size (bank to bank) and depth will permit. Since changing the depth and/or length of a standard floating boom in a small stream is difficult, the use of the separation of product and water. The advantages of using a floating boom are the speed of deployment and the fact that there is not need for additional support as with the stationary boom.

• Multiple Impoundments – Since emergency built dams (either underflow or overflow) are seldom perfect, a series of dams is ones that are downstream will trap the last traces of product. Precautions should be taken to ensure that the foundations of emergency dams are not washed away by the released water. If earth is used to construct an overflow dam, a layer of earth-filled bags should be placed on top of the dam so erosion will not take place.

• Removal Methods Once the containment dams are constructed, the problem or removal of the

product from the water surface should be the prime consideration. The

removal must be continuous or else build-up of product behind the dams

or booms might lead to product escaping the traps.

The type of removal procedures used depends largely on the amount of

product being trapped in a given span of time, if the amount of product

moving down the stream is of sufficient quantity, the first dam or fixed boom

would quite possibly trap enough for the floating skimmer to work efficiently.

The skimmer will pump the product and possibly some water to a tank truck

or other holding tank. Separated water may be released from the bottom

of the tank truck if it becomes necessary. The absorbents (straw,

ground corncobs, or other stocked absorbent) could then be used at

downstream dams or booms. It is inadvisable to place an absorbent in the

stream prior to or at the first dam in anticipation of the arriving product. Let

the product accumulate at the first dam and use the floating skimmer to

recover the product.

Disposal of gross amount of product-soaked absorbent would not then be

a problem. Follow directions on use of each absorbent. Some are

designed to be placed on water before product arrives (straw and other

new types); others are intended only to be placed on the product after it


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accumulates on the water (ground corncobs and others). Plastic sheets

should be used to place the product-soaked absorbent on as it is hand

skimmed from the water. Alternatively, the material may be placed in

drums or lined roll-off boxes.

If the amount of product in the stream is minor, a straw-bale may be

constructed to filter out the product. The slowing of the water would not be

necessary, but several dams might be necessary to ensure complete

removal. The downstream dams would also offer protection when the

upstream bales are removed, releasing traces of product. Straw-bale dams

can also be used downstream from underflow and overflow dams for added

protection.

Thus, the containment and removal of spilled product on small to medium

fast-flowing streams might require a combination of underflow or overflow

dams, fixed booms, skimmers, absorbents, and straw-bale dams to

ensure a complete cleanup.

6.5.4 Spill in a Mud or Tidal Flat Area

• Confinement Method Shoreline boom lined with absorbent boom should be placed at the surf line

to prevent oil from washing up onto the flat area. If oiling has already

occurred the boom is used to prevent further oiling and keep oil that has

impacted the flat from spreading.

• Removal Method Natural Recovery, Flooding and Sorbents are the three preferred methods.

Any invasive type of recovery method poses a risk of driving the oil into the

substrate of the flat and endangering the biologicals that live there.

Invasive methods should only be used in order to protect more sensitive

areas.

6.5.5 Spill in Urban Areas

Oil spills in urban areas can greatly impact recreational use, human health,

wildlife habitat(s), and potential beach or park closures. Manmade

structures along waterways require unique protection strategies.

Manmade structures could include vertical shore protection structures such

as seawalls, piers, and bulkheads, as well as riprap revetments and groins,

breakwaters, and jetties. Vertical structures can be constructed of concrete,

wood, and corrugated metal. They usually extend below the water surface,

although seawalls can have beaches or riprap in front of them. These

structures are very common along developed shores, particularly in


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harbors, marinas, and residential areas. The range in degree of exposure

to waves and currents varies widely, from very low in dead-end canals, to

very high on offshore breakwaters. Boat wakes can generate wave energy

in otherwise sheltered areas.

Maintaining shipping or other kinds of vessel traffic through navigation

channels or waterways during a spill response is a difficult consideration

because there is usually economic and political pressure to re-establish

normal operations as soon as possible. This consideration extends to

vehicular traffic through urban areas. Deploying booms and skimmers or

constructing recovery sites can conflict with such traffic for several days.

Also, passage of deep-draft vessels through the waterway can suddenly

change water level and flow or create wakes, causing booms to fail. For

these reasons, recovery efforts must be coordinated through the Unified

Command to ensure the cooperation of all parties involved.

6.6 SHORELINE DESCRIPTORS AND RESPONSE CONSIDERATIONS

The following is an excerpt taken from the NOAA Shoreline Assessment Manual,

Third Edition, August 2000. It is intended to offer guidance on the response

considerations for the various shoreline types and structures found within the

response zones. The descriptors, including oil behavior and response

considerations is as follows:

Exposed Rocky Cliffs ESI = 1A

DESCRIPTION

• The intertidal zone is steep (greater than 30o slope), with very little width.

• Sediment accumulations are uncommon and usually ephemeral, because waves remove the debris that has slumped from the eroding cliffs.

• There is strong vertical zonation of intertidal biological communities.

• Species density and diversity vary greatly, but barnacles, snails, mussels, sea stars, limpets, sea anemones, shore crabs, polychaetas, and macroalgae are often very abundant.

PREDICTED OIL BEHAVIOR

• Oil is held offshore by wave reflecting off the steep cliffs.

• Any oil that is deposited is rapidly removed from exposed faces.

• The most resistant oil would remain as a patchy band at or above the high-tide line.

• Impacts to intertidal communities are expected to be short-term in duration. An exception would be where heavy concentrations of a light refined product came ashore very quickly.

RESPONSE CONSIDERATIONS

• Cleanup is usually not required.

• Access can be difficult and dangerous.


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Exposed, Solid Man-Made Structures ESI = 1B

DESCRIPTION

• This shoreline type consists of solid man-made structures such as seawalls, groins, revetments, piers, and port facilities.

• They are constructed of concrete, wood, or metal.

• Often there is no exposed substrate at low tide, but a wide range of habitats may be present.

• They are built to protect the shore from erosion by waves, boat wakes, and currents, and thus are exposed to rapid natural removal processes.

• Attached animals and plants are sparse to moderate. PREDICTED OIL BEHAVIOR

• Oil is held offshore by waves reflecting off the steep, hard surface in exposed settings.

• Oil readily adheres to the dry, rough surfaces, but it does not adhere to wet substrates.

• The most resistant oil would remain as a patchy band at or above the high-tide line.


• Cleanup is usually not required.

• High-pressure water spraying may be conducted to: remove persistent oil in crevices; improve aesthetics; or reduce leaching of oil.

Wave-Cut Platforms ESI = 2

DESCRIPTION

• The intertidal zone consists of a flat rock bench of highly variable width.

• The shoreline may be backed by a steep scarp or low bluff.

• There may be a beach of sand- to boulder-sized sediments at the base of the scarp.

• The platform surface is irregular and tidal pools are common.

• Small amounts of gravel can be found in the tidal pools and crevices in the platform.

• These habitats can support large populations of encrusting animals and plants, with rich tidal pool communities.


• Oil will not adhere to the rock platform, but rather be transported across the platform and accumulate along the high-tide line.

• Oil can penetrate in beach sediments, if present.

• Persistence of oiled sediments is usually short-term, except in wave shadows or where the oil has penetrated sediments at the high-tide line.


• Cleanup is usually not required. • Where the high-tide area is accessible, it may be feasible to remove

heavy oil accumulations and oiled debris.


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Fine-Grained Sand Beaches ESI = 3A

DESCRIPTION

• These beaches are generally flat and hard-packed. • Though they are predominantly fine sand, there is often a small amount

of shell hash. • There can be heavy accumulations of wrack present. • They are utilized by birds and turtles for nesting and feeding. • Upper beach fauna are generally sparse, although amphipods can be

abundant; • Lower beach fauna can be moderately abundant, but highly variable.

PREDICTED OIL BEHAVIOR • Light oil accumulations will be deposited as oily bands along the upper

intertidal zone. • Heavy oil accumulations will cover the entire beach surface; oil will be

lifted off the lower beach with the rising tide. • Maximum penetration of oil into fine-grained sand is about 10 cm. • Burial of oiled layers by clean sand within the first week after a spill

typically will be less than 30 cm along the upper beach face. • Organisms living in the beach sediment may be killed by smothering or

lethal oil concentrations in the interstitial water. • There may be declines in infauna, which can affect important shorebird

foraging areas. RESPONSE CONSIDERATIONS

• These beaches are among the easiest shoreline types to clean. • Cleanup should concentrate on removing oil and oily debris from the

upper swash zone once oil has come ashore. • Activity through oiled and dune areas should be limited, to prevent oiling of

clean areas. • Manual cleanup, rather than road graders and front-end loaders, is usually

advised to minimize the volume of sand removed from the shore and requiring disposal.

• All efforts should focus on preventing the mixture of oil deeper into the sediments by vehicular and foot traffic.

• Mechanical reworking of lightly oiled sediments from the high-tide line to the upper intertidal zone can be effective along outer beaches.

Scarps and Steep Slopes in Sand ESI = 3B

DESCRIPTION

• This shoreline type occurs where sandy bluffs are undercut by waves or currents and slump.

• They normally form along embankments of sandy dredge material and at cut banks in rivers; they also form where tidal creeks intercept old sandy beach ridge deposits.

• Some scarps are fronted by narrow beaches, if the erosion rates are moderate and episodic.


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• Trees growing at the top of these slopes are eventually undercut and the debris can accumulate at the base of the scarp.

• Biological utilization by birds and infauna is low. PREDICTED OIL BEHAVIOR

• Any stranded oil will concentrate at the high-water line and may penetrate sandy sediments.

• Oil will adhere to the dry surface of any woody debris accumulated at the base of the scarp.

• There is little potential for burial except when a major slumping of the bluff occurs.

• Active erosion of the scarp will remove the oil. RESPONSE CONSIDERATIONS

• In most cases, cleanup is not necessary because of the short residence time of the oil.

• The need for removal of oiled sediments and debris should be carefully evaluated because of the potential for increased erosion.

• Closely supervised manual labor should be used so that the minimal amount of material is removed during cleanup.

Medium- to Coarse-Grained Sand Beaches ESI = 4

DESCRIPTION • These beaches have relatively steep beach faces and soft substrates. • Coarse-sand beaches can undergo rapid erosion/deposition cycles, even

within one tidal cycle. • The amount of wrack varies considerably. • They are utilized by birds and turtles for nesting and feeding.

PREDICTED OIL BEHAVIOR • Light oil accumulations will be deposited as oily bands along the upper

intertidal zone. • Heavy oil accumulations will cover the entire beach surface; oil will be lifted

off the lower beach with the rising tide. • Maximum oil penetration is about 20 cm. • Burial of oiled layers by clean sand within the first week after a spill can be

up to 50 cm. • Organisms living in the beach sediments may be killed by smothering or

lethal oil concentrations in the interstitial water. • There may be declines in infauna, which can affect important shorebird

foraging areas.

RESPONSE CONSIDERATIONS • Coarse sand sediments are less trafficable, increasing the risk of mixing oil

into the substrate by foot and vehicular traffic. • Cleanup should concentrate on removing oil and oily debris from the upper

swash zone once oil has come ashore. • Traffic through oiled and dune areas should be limited, to prevent oiling of

clean areas.


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• Manual cleanup, rather than road graders and front-end loaders, is advised to minimize the volume of sand removed from the shore and requiring disposal.

• All efforts should focus on preventing the mixture of oil deeper into the sediments by vehicular and foot traffic.

• Mechanical reworking of lightly oiled sediments from the high-tide zone to the upper intertidal zone can be effective along outer beaches.

Mixed Sand and Gravel Beaches ESI = 5

DESCRIPTION • These beaches are moderately sloping and composed of a mixture of sand

and gravel. • Because of the mixed sediment sizes, there may be zones of pure

sand, pebbles, or cobbles. • There can be large-scale changes in the sediment distribution patterns

depending upon season, because of the transport of the sand fraction offshore during storms.

• Because of sediment desiccation and mobility on exposed beaches, there are low densities of attached animals and plants.

• The presence of attached algae and animals indicates beaches that are relatively sheltered, with the more stable substrate supporting a richer biota.

PREDICTED OIL BEHAVIOR • During small spills, oil will be deposited along and above the high-tide

swash. • Large spills will spread across the entire intertidal area. • Oil penetration into the beach sediments may be up to 50 cm; however, the

sand fraction can be quite mobile, and oil behavior is much like on a sand beach if the sand exceeds 40 percent.

• Burial of oil may be deep at and above the high-tide line, where oil tends to persist, particularly where beaches are only intermittently exposed to waves.

• In sheltered pockets on the beach, pavements of asphalted sediments can form if there is no removal of heavy oil accumulations, because most of the oil remains on the surface.

• Once formed, these asphalt pavements can persist for many years. • Oil can be stranded in the coarse sediments on the lower part of the beach,

particularly if the oil is weathered or emulsified. RESPONSE CONSIDERATIONS

• Remove heavy accumulations of pooled oil from the upper beach face. • All oiled debris should be removed. • Sediment removal should be limited as much as possible. • Low-pressure flushing can be used to float oil away from the sediments for

recovery by skimmers or sorbents. High-pressure spraying should be avoided because of potential for transporting contaminated finer sediments (sand) to the lower intertidal or subtidal zones.


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• Relocation of oiled sediments from the high-tide zone to the upper intertidal zone can be effective in areas regularly exposed to wave activity (as evidence by storm berms). However, oiled sediments should not be relocated below the mid- tide zone.

• Tilling may be used to reach deeply buried oil layers in the middle zone on exposed beaches.

Gravel Beaches ESI = 6A

DESCRIPTION

• Gravel beaches are composed of sediments ranging in size from pebbles to boulders. The gravel-sized sediments can be made up of shell fragments.

• They can be very steep, with multiple wave-built berms forming the upper beach.

• Attached animals and plants are usually restricted to the lowest parts of the beach, where the sediments are less mobile.

• The presence of attached algae, mussels, and barnacles indicates beaches that are relatively sheltered, with the more stable substrate supporting a richer biota.


• Deep penetration and rapid burial of stranded oil is likely on exposed beaches.

• On exposed beaches, oil can be pushed over the high-tide and storm berms, pooling and persisting above the normal zone of wave wash.

• Long-term persistence will be controlled by the depth of penetration versus the depth of routine reworking by storm waves.

• On the more sheltered portions of beaches, formation of asphalt pavements is likely where accumulations are heavy.

RESPONSE CONSIDERATIONS • Heavy accumulations of pooled oil should be removed quickly from the

upper beach. • All oiled debris should be removed. • Sediment removal should be limited as much as possible. • Low- to high-pressure flushing can be used to float oil away from the

sediments for recovery by skimmers or sorbents. • Relocation of oiled sediments from the high-tide zone to the upper intertidal

zone can be effective in areas regularly exposed to wave activity (as evidenced by storm berms). However, oiled sediments should not be relocated below the mid- tide zone.

• Tilling may be used to reach deeply buried oil layers in the upper- to mid-tide zone on exposed beaches.

Riprap ESI = 6B

DESCRIPTION

• • Riprap is composed of cobble- to boulder-sized blocks of granite, limestone, or concrete.


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• Riprap structures are used for shoreline protection and channel stabilization (jetties).

• Attached biota are sparse. PREDICTED OIL BEHAVIOR

• Oil adheres readily to the rough surfaces of the blocks. • Deep penetration of oil between the blocks is likely. • Uncleaned oil can cause chronic leaching until the oil solidifies.


• When the oil is fresh and liquid, high pressure flushing and/or water flooding may be effective, making sure to recover all liberated oil.

• Heavy and weathered oils are more difficult to remove, requiring scrapping and/or hot-water flushing.

• In extreme cases, it may be necessary to remove heavily oiled blocks and replace them.

Exposed Tidal Flats ESI = 7

DESCRIPTION • Exposed tidal flats are broad intertidal areas composed primarily of sand

and minor amounts of shell and mud. • The dominance of sand indicates that currents and waves are strong enough

to mobilize the sediments. • They are usually associated with another shoreline type on the landward

side of the flat, though they can occur as separate shoals; they are commonly associated with tidal inlets.

• Biological utilization can be very high, with large numbers of infauna, heavy use by birds for roosting and foraging, and use by foraging fish.

PREDICTED OIL BEHAVIOR • Oil does not usually adhere to the surface of exposed tidal flats, but rather

moves across the flat and accumulates at the high-tide line. • Deposition of oil on the flat may occur on a falling tide if concentrations are

heavy. • Oil does not penetrate water-saturated sediments. • Biological damage may be severe, primarily to infauna, thereby reducing

food sources for birds and other predators. RESPONSE CONSIDERATIONS

• Currents and waves can be very effective in natural removal of the oil. • Cleanup is very difficult (and possibly only during low tides). • The use of heavy machinery should be restricted to prevent mixing of oil into

the sediments. Sheltered Rocky Shores ESI = 8A

DESCRIPTION

• These are bedrock shores of variable slope (from vertical cliffs to wide, rocky ledges) that are sheltered from exposure to most wave and tidal energy.

• Wide shores may have some surface sediments, but bedrock is the dominant substrate type.


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• Species density and diversity vary greatly, but biota are often very abundant. PREDICTED OIL BEHAVIOR

• Oil will adhere readily to the rough rocky surface, particularly along the high-tide line, forming a distinct oil band.

• Even on wide ledges, the lower intertidal zone usually stays wet (particularly when algae covered), preventing oil from adhering to the rock surface.

• Heavy and weathered oils can cover the upper zone with little impacts to the rich biological communities of the lower zone.

• Where surface sediments are abundant, oil will penetrate into the crevices formed by the surface rubble, forming persistent pavements.

• Where the rubble is loosely packed, oil will penetrate deeply, causing long-term contamination of the subsurface sediments.

RESPONSE CONSIDERATIONS • Low-pressure flushing at ambient temperatures is most effective when the

oil is fresh. • Extreme care must be taken not to spray in the biologically rich lower

intertidal zone or when the tidal level reaches that zone. • Cutting of oiled, attached algae is not recommended; tidal action will

eventually float this oil off, so sorbent booms should be deployed.

Sheltered, Solid Man-made Structures ESI = 8B

DESCRIPTION

• These structure are solid man-made structures such as seawalls, groins, revetments, piers, and port facilities.

• Most structures are constructed of concrete, wood, or metal, and their composition, design and condition are highly variable.

• Often there is no exposed beach at low tide, but a wide variety habitats may be present.

• Attached animal and plant life can be moderate to high. PREDICTED OIL BEHAVIOR

• Oil will adhere readily to the rough surface, particularly along the high-tide line, forming a distinct oil band.

• The lower intertidal zone usually stays wet (particularly if algae covered), preventing oil from adhering to the surface.

RESPONSE CONSIDERATIONS • Cleanup of seawalls is usually conducted for aesthetic reasons or to prevent

leaching of oil. • Low- to high-pressure flushing at ambient water temperatures is most

effective when the oil is fresh. Hot water is needed for heavy or weathered oils.

Sheltered Tidal Flats ESI = 9A

DESCRIPTION • Sheltered tidal flats are composed primarily of mud with minor amounts of

sand and shell.


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• They are present in calm-water habitats, sheltered from major wave activity, and are frequently backed by marshes.

• The sediments are very soft and cannot support even light foot traffic in many areas.

• They can be sparsely to heavily covered with algae and/or seagrasses. • They can have very heavy wrack accumulations along the high-tide line. • There can be large concentrations of shellfish, worms, and snails on and in

the sediments. • They are heavily utilized by birds and fish for feeding.

PREDICTED OIL BEHAVIOR • Oil does not usually adhere to the surface of sheltered tidal flats, but rather

moves across the flat and accumulates at the high-tide line. • Deposition of oil on the flat may occur on a falling tide if concentrations are

heavy. • Oil will not penetrate the water-saturated sediments but could penetrate

burrows and root cavities. • Biological damage may be severe.

RESPONSE CONSIDERATIONS • These are high-priority areas for protection since cleanup options are

very limited. • Cleanup is very difficult because of the soft substrate; many methods may

be restricted. • Deluge flooding and deployment of sorbents from shallow-draft boats may

be helpful.

Vegetated Low Riverine Banks ESI = 9B

DESCRIPTION

• This shoreline type consists of either low banks with grasses or low eroding banks with trees and tree roots exposed to the water.

• The banks are flooded occasionally by high water. • These shorelines are generally found in fresh or brackish water localities.

PREDICTED OIL BEHAVIOR • During low water stages there could be little impact, with the oil coating a

narrow band of sediment at the water level. • During high water, the oil will cover and coat the grasses and base of the

trees. • May cause loss of the grasses, but the trees should survive unless oil

penetrates and persists. RESPONSE CONSIDERATIONS

• Low-pressure flushing of oiled areas is effective in removing moderate to heavy accumulations of oil from along the banks.

• Sorbent and containment boom should be placed on the water side of the cleanup operations to contain and collect oil outflow.

• Low- to high-pressure flushing can be used to remove oil from tree roots and trunks, if deemed necessary in high-use areas.

Salt- and Brackish-Water Marshes ESI = 10A


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DESCRIPTION

• These marshes contain vegetation which tolerates water salinity down to about 5 ppt.

• Width of the marsh can vary widely, from a narrow fringe to extensive areas. • Sediments are composed of organic-rich muds except on the margins of

barrier islands where sand is abundant. • Exposed areas are located along waterbodies with wide fetches and along

busy waterways. • Sheltered areas are not exposed to significant wave or boat wake activity. • Resident flora and fauna are abundant with numerous species with

high utilization by birds, fish, and shellfish. PREDICTED OIL BEHAVIOR

• Oil adheres readily to intertidal vegetation. • The band of coating will vary widely, depending upon the water level at the

time oil slicks are in the vegetation. There may be multiple bands. • Large slicks will persist through multiple tidal cycles and coat the entire stem

from the high-tide line to the base. • If the vegetation is thick, heavy oil coating will be restricted to the outer

fringe, although lighter oils can penetrate deeper, to the limit of tidal influence.

• Medium to heavy oils do not readily adhere to or penetrate the fine sediments, but can pool on the surface of in burrows and root cavities.

• Light oils can penetrate the top few centimeters of sediment and deeply into burrows and mud cracks (up to one meter).

RESPONSE CONSIDERATIONS • Under light oiling, the best practice is to let the area recover naturally. • Natural removal processes and rates should be evaluated prior to

conducting cleanup. • Heavy accumulations of pooled oil can be removed by vacuum, sorbents, or

low- pressure flushing. During flushing, care must be taken to prevent transporting oil to sensitive areas down slope or along shore.

• Cleanup activities should be carefully supervised to avoid vegetation damage.

• Any cleanup activity must not mix the oil deeper into the sediments. Trampling of the roots must be minimized.

• Cutting of oiled vegetation should only be considered when other resources present are at great risk from leaving the oiled vegetation in place.


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FIGURE 6.1

ON WATER RESPONSE FLOWCHART


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6.7 RISK AND HAZARD ANALYSIS

6.7.1 Introduction

Paramount Pipeline LLC, located at 14700 Downey Avenue,

Paramount California uses a pipeline system connecting the refinery

with Paramount’s Lakewood Tank Farm in Lakewood, the Valero Refinery

in Long Beach, the Marathon East Hynes Terminal in Lakewood and the

Kinder Morgan terminal in Carson. Additionally, the pipelines connect to

several lines operated by others. These connections are located in

subterranean valve vaults.

Paramount’s pipelines are used to receive Tallow, Corn Oil and

petroleum products and to ship naphtha fractions, jet fuel, diesel fuel and

gas oil. All pipelines Paramount owns leases and/or operates are located

in the greater Los Angeles area.

Per the requirements of CCR Title 14, Division 1, Subdivision 4,

Section 817.02(c)(1), Paramount is required to perform a risk and hazard

analysis of the pipeline system. A preliminary analysis was performed

using the “What If” Analysis procedure. The main purpose of the “What

If” Analysis was to carefully consider and review possible unexpected

events of a system that could result in an adverse consequence. The

following subsections of Section 3 of this Plan report the review and

discussions of the What If Analysis and summarize the findings and

recommendations.

6.7.2 Methodology

The What If Analysis was performed according to procedures described in

detail in “Guidelines for Hazard Evaluation Procedures” published by the

American Institute of Chemical Engineers for The Center for Chemical

Process Safety. The method involves conducting a thorough and

systematic investigation of a system by asking questions that begin with

“What if...” The questions (or review) usually start at the input of a system

(or process), follows the logical flow of the process and ends at the

termination point of the system under study. The questions, answers,

including potential hazards, consequences and solutions of importance are

all recorded. The discussions and findings of the study are compiled in a

report which is submitted to the responsible individual and after review and

comments from appropriate management levels; a final report is prepared

which completes the study.


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The Paramount pipeline system What If Analysis was prepared by team of

qualified and experienced professionals who have overall system and

process knowledge and expertise.

The What If Analysis was performed by the team using the following (but

not limited to) typical documents and information on the system:

• Piping and instrumental diagrams (P&IDs);

• Plot Plans and general arrangements;

• Equipment description and data sheets;

• Operation and maintenance manuals;

• Physical properties of the commodities transported; and

• Past history and knowledge of pipeline operations and upsets.

• General Traffic Patterns

The What If Analysis for Paramount’s pipeline system was performed at

the

Paramount refinery, Paramount, California during the third and fourth

quarters of 2000. The initial team consisted of:

Robert Burke, P.E., Environmental Engineering Consultant

Eric Pedrosa, Pipeline Engineer (part) Dick Mellor, Director of Engineering

(part)

The completed analysis was reviewed by:

Clay Totten, Director of Fire, Safety and Security

Jack Harding, Director of Pipeline Operations

Roger Goenner, Operations Manager

June Christman, Director of Environmental Services

The following paragraphs list the pipelines included in the study and define

the basic assumptions regarding personnel, operating and maintenance

procedures, data collection, communications and spill history used in the

preparation of the analysis.

A. The following pipeline systems were studied using the What If Analysis:

• CSFM 051/PPC#2 - A 4 inch diameter, 800 foot line located at the Lakewood Tank Farm that connects to CSFM 121 at the valve vault


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located at the Lakewood Tank farm service road south of Orizaba Alley. The line is used to transfer jet fuel.

• CSFM 121/PPC#35 - A 4 inch diameter, 21,710 foot line that connects the refinery with the Lakewood Tank Farm. There are three valve vaults on this line: one is located at Somerset Ave. and Lakewood Blvd.; the second is located at South Street and Lakewood Blvd.; and the third is located on South Street at Orizabe Ave. The line is used primarily used for shipping jet fuel.

• CSFM 131,132/PPC# 160 - A 39,571 foot line with sections of different diameters (6, 8, 10 and 12 inch). Paramount’s portion of this line begins at a valve box located on Willow Street at the boundary of the City of Long Beach and Los Angeles County. The line runs north and northeast, passes through the Lakewood Tank Farm and ends at Marathon’s East Hynes Terminal.

• CSFM 244/PPC 12” Crude - A 12 inch diameter, 3-1/2 mile line that connects the refinery to a valve vault located east of Orizaba Ave on South Street. There is an intermediate valve vault located at Downey Ave and Artesia Blvd. The line is used for moving hydrogen gas.

B. All pipeline operations personnel are experienced and trained in operations and have close communications and coordination with their counterparts at the opposite end of their respective originating or terminating points.

C. The analysis was conducted only for the pipeline systems. The originating or terminating points at the refinery were considered to be the first flange face after entering either facility. The originating or terminating points at Lakewood Tank Farm were considered to be either tank TK-55001 or tank TK-55002. The originating or terminating points in the various valve vaults were considered to be the flange face after the last valve.

D. Paramount has in place appropriate technical data, operating

procedures and emergency response procedures for the pipeline systems in which the concerned employees are trained and experienced.

E. The basic mode of communication between the terminals is

telephones. Backup communications is by radio and ultimately via automobile messengers.


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F. At the sending and receiving ends of a pipeline system, operating data (pressures, temperatures, flow rates, etc.) are observed and recorded at two hour intervals, at odd hours e.g., 1:00 PM, 3:00 PM, etc.

G. The Paramount pipeline system is connected with Dig Alert (phone

(800) 227-2600. Any outside party that plans digging or construction related work within the pipeline’s vicinity is required to inform Dig Alert, which informs Paramount. Paramount in turn alerts the appropriate pipeline personnel.

H. During Paramount’s pipeline operations, catastrophic failures

leading to severe consequences of fire, injury, or death have not occurred.

I. The pipelines are rated as schedule 40 and made of carbon steel.

Each pipeline system is hydrostatically tested regularly per State Fire Marshal regulations.

J. Several pipelines have connections to various other users. At each

connection, appropriate isolation valves and provisions for inserting slip blinds are in place to “line up” the system as required.

K. Prior to transfer between any given points on a pipeline, personnel

at sending and receiving points communicate, check and agree on the transfer procedures. Appropriate valves, equipment and systems are “lined up” prior to start of transfer. Multiple point transfers are not done.

The records and discussions for the pipeline system’s “What If Analysis”,

the findings of the analyses and the Offsite Consequence Analyses are

presented in this section in the order in which each pipeline was

considered.

6.8 ALTERNATIVE RESONSE STRATEGIES

There are no pre-approved response options for inland spills within the United

States. Any plans to use dispersants or in situ burn by the Company will be

submitted to the Federal On-Scene Coordinator for Regional Response Team

approval prior to such action being taken.


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6.9 ENDANGERED/THREATENED SPECIES LISTING – CALIFORNIA

https://www.dfg.ca.gov/wildlife/nongame/t_e_spp/

6.10 ACP Forms (2019)

https://nrm.dfg.ca.gov/documents/ContextDocs.aspx?cat=OSPR-AreaContingencyPlans

https://www.dfg.ca.gov/wildlife/nongame/t_e_spp/

https://nrm.dfg.ca.gov/documents/ContextDocs.aspx?cat=OSPR-AreaContingencyPlans


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7 APPENDIX A

WORST CASE DISCHARGE ANALYSIS AND SCENARIO

7.1 INTRODUCTION

This appendix identifies potential causes for oil discharges and discusses the response efforts that are necessary for successful mitigation. Included in this appendix are hypothetical scenarios for various types of spills that have the potential to occur along the system. It is anticipated that The Company will respond to spills in a consistent manner regardless of the location. Therefore, the guidelines discussed in this appendix will apply to all spills whenever possible. DOT/PHMSA requires that pipeline operators calculate a worst case discharge amount for each response zone. The calculations and descriptions are as follows:

• Worst Case Discharge The largest volume (Bbls) of the following:

o Pipeline's maximum release time (hrs), plus the maximum shutdown

response time (hrs), multiplied by the maximum flow rate (bph), plus the largest line drainage volume after shutdown of the line section.

OR o Largest foreseeable discharge for the line section is based on the maximum

historic discharge, if one exists, adjusted for any subsequent corrective action or preventive action taken.

OR o Capacity of the single largest breakout tank or battery of tanks within a

single secondary containment system, adjusted for the capacity or size of the secondary containment system.

Scenario Types

The occurrence of a Worst Case Discharge (WCD) could be the result of any number of scenarios along the pipeline system including:

• Piping rupture;

• Piping leak, under pressure and not under pressure;

• Explosion or fire; and

• Equipment failure (e.g. pumping system failure, relief valve failure, or other general equipment relevant to operational activities associated with internal or external facility transfers).

The response actions to each of these scenarios are outlined in Section 3.1 and Figure 3.1. The response resources are identified in a quick reference format in Figure 2.6. Pipeline response personnel list/telephone numbers and other internal/external resources telephone numbers are detailed in Figures 2.2 and 2.5.

7.2 RESPONSE CAPABILITY SCENARIOS

PIPELINE WORST CASE DISCHARGE AT LOS ANGELES RIVER = 3,070 BBLS


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The worst case discharge in this Pipeline is 3,070 bbls. Description

This size discharge would originate from the Pipeline 145 (CSFM 0166) at the Compton Creek River. The type of material that could be discharge is Diesel.

Volume

This WCD scenario involves a line segment using the pipeline’s maximum release time in hours, plus the maximum shutdown response time in hours, multiplied by the maximum flow rate expressed in barrels per hour (bph), plus the largest line drainage volume after shutdown of the line section. For the Pipeline 145, the following calculations were used:

Pipeline maximum release time 2.0 hour Maximum shutdown time 0.33 hour Maximum flow rate 1,000 bph Largest line drainage volume 740 bbls Worst case discharge [(2.00 + 0.33) x 1,000] + 740 =

3070 bbls

This WCD scenario does not involve breakout tankage. Therefore single largest volume breakout tank adjustments/calculations are not considered in this WCD. Note: Adverse weather will not affect detection or shut down times.

PIPELINE WORST CASE DISCHARGE AT LOS ANGELES RIVER = 3,070 BBLS

Response Requirement

The Company has identified sufficient response resources, by contract or other approved means, to respond to a worst case discharge to the maximum extent practicable. These response resources include:

• Resources capable of arriving at the staging area within the applicable response tier requirements for non-high volume areas (Tier 1 = 12 hours; Tier 2 = 36 hours; Tier 3 = 60 hours).

• Resources capable of oil recovery in inclement weather conditions (i.e. heavy rain, snow, ice).


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• The State of California uses a similar methodology to calculate the reasonable worst-case spill. Title 14 CCR Section 817.02(d) requires Paramount Pipeline to first compute a “reasonable worst-case spill” and then a “response planning volume.” These hypothetical volumes and the response capability standards are then evaluated to ensure that the necessary response capabilities are available.

• The reasonable worst-case spill volume is calculated using the portion of the total line fill capacity which could be lost during a spill; plus the amount of additional spillage that could reasonably be expected during emergency shut-off, transfer or pumping stations, other safety devices, emergency reaction times and maximum transfer rates.

• The reasonable worst-case spill volume was computed using the same line section of the CSFM 0166 line as was used in the preceding calculation.

• The worst-case spill volume is the same for both the Federal and State requirements.

Notes:

• Contracted and Company owned equipment and manpower resources are detailed in Appendix E.

• Telephone references are provided in Figures 2.2 and 2.5.


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PARAMOUNT PIPELINE LLC - REASONABLE WORST CASE SCENARIO

Location Data

Location Type Inland

Area Type Non-High Volume Area

WCD Product Type Diesel

PHMSA WCD Volume (bbls) 3,070

Discharge Volumes/Calculations

Worst Case Discharge - Based on PHMSA criteria (bbls) 3,070

Selected Calculation Factors (Based on USCG Tables)

Removal Capacity Planning Volume - Percent Natural Dissipation 30%

Removal Capacity Planning Volume - Percent Recovered Floating Oil 50%

Removal Capacity Planning Volume - Percent Oil Onshore 50%

Emulsification Factor 2.0

Tier 1 - On Water Oil Recovery Resource Mobilization Factor 15% Tier

2 - On Water Oil Recovery Resource Mobilization Factor 25% Tier 3

- On Water Oil Recovery Resource Mobilization Factor 40%

Response Planning Volume Calculation

On-Water Recovery Volume (bbls) 1,535

Shoreline Recovery Volume (bbls) 1,535

Shoreline Cleanup Volume (bbls) 3,070

On-Water Recovery Cpcty (bbls/day)

Shallow Water Resp Cpblty (bbls/day)

Storage Capacity (bbls/day)

On-Water Response Caps (bbls/day)

Additional Response Req'd (bbls/day)

Response Time (hrs)

Tier 1 Tier 2 Tier 3

461

92

921

768

153

1,554

1,228

246

2,456

8,954

0

12

15,903

0

36

31,807

0

60


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8 APPENDIX B

TRAINING AND DRILLS

8.1 RESPONSE TEAM TRAINING

The Company provides training related to discharge prevention, testing and response, including measures to repair pipeline ruptures and mitigate discharges. The Training Methods address oil discharges from the pipeline from several perspectives: human health and safety, rupture control and repair operations, pollution control, and overall (crisis) management of the emergency. The competency of each training program is closely monitored by the Training Section through observation of and/or participation in actual training sessions. Through the various training methods described below The Company's training program is intended to ensure the following results: That all personnel know:

• Their responsibilities under the Plan;

• The name, address and procedures for contacting the operator on a 24-hour basis; and

• The name of, and procedures for contacting the Qualified Individual on a 24-hour basis.

That all reporting personnel know:

• The pipelines and response zone details for the affected area (Figure 1.3);

• The telephone number of the National Response Center and other required notifications (Section 2.0); and

• The notification process. (Section 2.0).

That all response personnel know:

• The characteristics and hazards of the oil discharged (Section 3.0);

• The conditions that are likely to worsen emergencies, including the consequences of pipeline malfunctions, and the appropriate corrective actions; and

• The steps necessary to control any accidental discharge of oil and to minimize the potential for fire, explosion, toxicity or environmental damage (Section 3.0).

Integrated Contingency Plan Review All Pipeline Response Team Members should review their Oil Spill Response Plan whenever their job position or responsibilities change under the Plan. A copy of this Plan will be available at all times to Team Members.


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HAZWOPER (24 CFR 1910.120)

Federal and state regulations require that response team members maintain up-to-date HAZWOPER training necessary to function in their assigned positions. At a minimum, Team members will receive “First Responder Awareness Level” training. All personnel responding to an incident must satisfy the applicable HAZWOPER training requirements of 29 CFR 1910.120.

OSHA HAZWOPER TRAINING REQUIREMENTS

Responder Classification

Required Training Hours

Refresher

29CFR 1910.120(q) Emergency Response

First Responder - Awareness Level First Responder - Operations Level Hazardous Materials Technician Hazardous Materials Specialist Incident Commander

2-4 hrs demonstration of competency 8 hrs 24 hrs plus competency 24 hrs plus competency in specialized areas 24 hrs plus competency

same 8 hrs 8 hrs 8 hrs 8 hrs

29CFR 1910.120(e) Clean Up Sites

General Site Workers Occasional Workers (Limited Tasks) General Site Workers (Low Hazard) Supervisors

40 hrs / 3 days on the job training 24 hrs / 1 day on the job training 24 hrs / 1 day on the job training 8 hrs supervisor training

8 hrs 8 hrs 8 hrs 8 hrs

29CFR 1910.120(p)(7)(8) RCRA TSD Sites

New Employees Current Employees*

24 hrs 24 hrs

8 hrs 8 hrs

* Previous work experience and/or training certified as equivalent by employer.

Incident Command System

Response team members will receive ICS training and may also receive supplemental training in other related general topics. Training Records

Training records for local team members will be maintained at the pipeline office according to Federal, state, and local government requirements (three (3) years for the U.S. Coast Guard and five (5) years for the U.S. Environmental Protection Agency and Department of Transportation). Training Records Maintenance


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Emergency response training records are maintained at the Company’s Atlanta Office. Training records for response personnel will be maintained for as long as personnel have duties in this response plan.

Contractor Training

The Company also recognizes that contract personnel must also have sufficient training to respond emergency response situations. The Company communicates this training need to its key contractors during contract negotiations and often specifically spells out this requirement in its contracts. The Company also tends to use well-known spill response contractors whose reputation and experience levels help ensure personnel who respond will be trained to appropriate levels. Training Qualifications

As no formalized method of certifying training instructors has been provided by CALOSHA, the Company ensures the competency of its instructors and training organizations by selecting trainers and/or organizations with professional reputations and extensive hands-on and classroom experience in their subject matter. The Company personnel with responsibility to coordinate the training program also conduct periodic informal audits of training courses selected for The Company training program to ensure their suitability for the program.

8.2 RESPONSE TEAM EXERCISES

Local/Spill Management Team members, government agencies, contractors, and other resources must participate in response exercises required by Federal, state, or local regulations and as detailed in the “National Preparedness for Response Exercise Program (PREP) Guidelines.” The Company will conduct announced and unannounced drills to maintain compliance, and each plan-holder must participate in at least one exercise annually. The following table lists the triennial exercise cycle for facilities (see PREP Guidelines for full details).

TRIENNIAL CYCLE

Total Number

Frequency Exercise Type/Description

12 Quarterly QI Notification Exercise

6 Semi-Annual (Annually-DOT)

Equipment Deployment Exercise (Facility-owned equipment)

3 Annual Response Team Tabletop Exercise

3 Annual Equipment Deployment Exercise (facilities with OSRO- owned equipment)

3 Annual Unannounced Exercise (not a separate exercise) Actual response can be

considered as an unannounced exercise.

NOTE: All response plan components must be exercised at least once in the Cycle.

Quarterly QI Notification Exercise


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Scope: Exercise communication between pipeline personnel and the QI(s) and/or designated alternate(s). At least once each year, one of the notification exercises should be conducted during non-business hours.

Objective: Contact must be made with a QI or designated alternate, as identified in the Plan.

General: All personnel receiving notification shall respond to the notification and verify their receipt of the notification. Personnel who do not respond should be contacted to determine whether or not they received the notification. Semi-Annual/Annual Equipment Deployment Exercise (for facilities with equipment)

Scope: Deploy and operate response equipment identified in the response plan. The equipment to be deployed must include the following, at a minimum:

• 1,000 feet of representative type of boom;

• One of each type of skimming system; or

• The equipment necessary to respond to the pipeline’s Small/Average Most Probable Discharge (AMPD), whichever is less.

Objective: Demonstrate personnel’s ability to deploy and operate response equipment. Ensure that the response equipment is in proper working order. General: The Pipeline owner/operator may take credit for actual equipment deployment to a spill, or for training sessions, as long as the activities are properly documented. Annual Equipment Deployment Exercise (OSRO-owned equipment)

Review: The Pipeline owner/operator should verify that the OSRO(s) has completed the equipment deployment exercise requirements and has maintained the necessary documentation. The OSRO may deploy equipment at any location, so long as it occurs within an operating environment similar to the Pipeline’s.

Scope: OSRO must deploy and operate response equipment identified in the response plan. The equipment to be deployed must include the following, at a minimum:

• 1,000 feet of representative type of boom.

• One of each type of skimming system.

Objective: OSRO must demonstrate the ability of the personnel (OSRO) to deploy and operate response equipment (OSRO). Ensure that the response equipment (OSRO) is in proper working order. Annual Response Team Tabletop Exercise


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Scope: Exercise the response team's organization, communication, and decision- making in managing a spill response. Each team identified within the plan must conduct an annual Response Team Tabletop Exercise.

Objective: Exercise the response team in a review of the following:

• Knowledge of the Plan;

• Ability to organize team members to effectively interface with unified command;

• Proper notifications;

• Communications system and capability;

• Ability to access an OSRO;

• Coordination of internal spill response personnel;

• Review of the transition from a local team to a regional team;

• Ability to effectively coordinate response activity with the National Response System (NRS) Infrastructure;

• Coordination for response capabilities outlined in the Plan; and

• Ability to access information in the Area Contingency Plan. General: A minimum of one Response Team Tabletop Exercise in a triennial cycle will involve a Worst-Case Discharge scenario. Government-Initiated Unannounced Exercise

Scope: The Pipeline owner/operator is required to participate in only one unannounced exercise every 36 months from the date of the last government- initiated unannounced exercise.

• Exercises are limited to approximately four hours in duration.

• Exercises would involve response to a Small/Average Most Probable Discharge scenario.

• Exercise would involve equipment deployment to respond to a spill scenario. Objective: Conduct proper notifications to respond to unannounced scenario of a Small/Average Most Provable Discharge.

• Designated emergency response team members should demonstrate adequate knowledge of their facility response plan and the ability to organize, communicate, coordinate, and respond in accordance with that plan.

General: This exercise is only applicable to those facilities which are randomly chosen. Area Exercises


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Objective: The purpose of the area exercise is to exercise the entire response community in a particular area. An area is defined as “that geographic area for which a separate and distinct Area Contingency Plan has been prepared, as described in OPA 90.” The response community includes the federal, state, and local government and industry. The area exercises are designed to exercise the government and industry interface for spill response.

General: The goal is to ensure that all areas of the country are exercised triennially. All of the area exercises will be developed by an exercise design team. The exercise design team is comprised of representatives from the federal, state, and local government and industry. A lead plan holder would lead each area exercise. The lead plan holder is the organization government or industry) that holds the primary plan that is exercised in the area exercise. The lead plan holder would have the final word on designing the scope and scenario of the exercise.

Exercise Documentation All exercises should be documented and maintained at the pipeline office; documentation should specify:

• The type of exercise;

• Date and time of the exercise;

• A description of the exercise;

• The objectives met in the exercise;

• The components of the response plan exercised; and

• Lessons learned. Exercise documentation should be kept on file for the required length of time depending on the regulating agency (three (3) years for the U.S. Coast Guard and DOT PHMSA, and five (5) years for the U.S. Environmental Protection Agency).


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9 APPENDIX C

FOLLOW UP INVESTIGATION CFR §194.121(b)(1)(v); §195.195.402(e)(9)

In the event of a discharge covered under this Plan, the Company will review the plan to evaluate and validate its effectiveness. Input on the effectiveness of the Plan will be sought from management, company personnel, regulatory agencies, and others as deemed necessary. Based on the review, amendments to the Plan may be necessary.

9.1 REVIEW OF OSRP IMPLEMENTATION AND ADEQUACY – 49 CFR 194

The following explains the guidelines to follow for conducting a review of the incident response. The Company must conduct a review of responses to certain incidents in accordance with:

• 49 CFR 194.121(b) after containment and initial cleanup of a “oil spill” to evaluate the implementation of the FRP and its adequacy;

• 49 CFR 195.402(e)(9) to evaluate the effectiveness of emergency operational procedures; and

• CCR §817.02(f)(7) of the California Code of Regulations requires that the review be forwarded to the California Office of Oil Spill Prevention & Response within 90 days following the completion of response and clean-up procedures.

Certain “oil spills” result in Paramount implementing its OSRP and activating its location response team. In these cases, a review of the plans’ implementation and the plan’s adequacy must be conducted. This review should begin as soon as possible while the facts of the incident are fresh in the responders’ minds. Ideally, this would be initiated during the proactive phase of the incident or immediately following conclusion of the response. The following list outlines the responsibilities and the procedures for conducting a review of a response to contain and mitigate an “oil spill".

• Identify the review leader. Unless specifically directed otherwise by management, the review leader will be the Incident Commander for the facility or Location Response Team, as appropriate.

• The review leader will determine the depth of the review based upon the magnitude of the response and improvements encountered.

• The Incident Commander may assign members of the response team as necessary to assist with the review.

• Discuss all improvements regarding the response or the plan’s adequacy with Paramount’s management before issuing the formal review.

• All reviews must be documented.

• Consider the following guidelines in review preparation: o State only facts o Do not express opinions o Do not assign blame, and o Do not evaluate individual performance.


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• Paramount’s compliance Coordinator will serve as the focal point for addressing any noted improvements.

9.2 REVIEW OF OPERATIONAL RESPONSE – 49 CFR PART 195

All operational responses to emergency conditions for hazardous liquid pipelines are required to be reviewed to determine the adequacy of the procedures in mitigating the different types of emergencies.

9.3 PURPOSE OF REVIEW AND EVALUATION

This section provides procedures and information useful to responders for post incident/exercise review and evaluation. Post incident/exercise reviews should be conducted in a timely manner following an incident/exercise. The Plan should be evaluated to determine its usefulness during the incident/exercise and appropriate revisions should be made. All incident/exercise documentation should be included in the Plan evaluation process. Outline of Review Given below are items a team composed of outside people knowledgeable in spill response and key members of the response teams should examine. These questions are intended as guidelines only; many other questions are likely to be appropriate at each stage of a critique. Detection

• Was the spill detected promptly?

• How was it detected?

• By whom?

• Could it have been detected earlier? How?

• Are any instruments or procedures available to consider which might aid in spill detection?

Notification

• Were proper procedures followed in notifying government agencies? Were notifications prompt?

• Was management notified promptly?

• Was management response appropriate?

• Was the Pipeline owner/operator notified promptly? If so, why, how, and who? If not, why not?

Assessment/Evaluation

• Was the magnitude of the problem assessed correctly at the start?

• What means were used for this assessment?

• Are any guides or aids needed to assist spill evaluation?

• What sources of information were available on winds and on water currents?

• Is our information adequate?


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• Was this information useful (and used) for spill trajectory forecasts? Were such forecasts realistic?

• Do we have adequate information on product properties?

• Do we need additional information on changes of product properties with time, i.e., as a result of weathering and other processes?

Mobilization

• What steps were taken to mobilize spill countermeasures?

• What resources were used?

• Was mobilization prompt?

• Could it have been speeded up or should it have been?

• What about mobilization of manpower resources?

• Was the local spill cooperative used appropriately?

• How could this be improved?

• Was it appropriate to mobilize the Pipeline owner/operator resources and was this promptly initiated?

• What other corporate resources are available and have they been identified and used adequately?

Response - Strategy

• Is there an adequate spill response plan for the location?

• Is it flexible enough to cope with unexpected spill events?

• Does the plan include clear understanding of local environmental sensitivities?

• What was the initial strategy for response to this spill?

• Is this strategy defined in the spill plan?

• How did the strategy evolve and change during this spill and how were these changes implemented?

• What caused such changes?

• Are there improvements needed? More training? Response - Resources Used

• What resources were mobilized?

• How were they mobilized?

• How did resource utilization change with time? Why?

• Were resources used effectively? o Contractors o Government agencies o Company resources o Cooperatives o Volunteers o Consultants o Other (e.g., bird rescue centers)

• What changes would have been useful?


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• Do we have adequate knowledge of resource availability?

• Do we have adequate knowledge of waste disposal capabilities? Response - Effectiveness

• Was containment effective and prompt?

• How could it have been improved?

• Should the location or the local cooperative have additional resources for containment?

• Was recovery effective and prompt?


• Should the location or the local cooperative have additional resources for recovery of spilled product?

• Was contaminated equipment disposed of promptly and safely?

• Was there adequate in-house product separation, recovery, and disposal?


• Were there adequate outside disposal resources available? Command Structure

• Who was initially in charge of spill response?

• What sort of organization was initially set up?

• How did this change with time? Why?

• What changes would have been useful?

• Was there adequate surveillance?

• Should there be any changes?

• Were communications adequate?

• What improvements are needed? Hardware, procedures, etc.

• Was support from financial services adequate? Prompt?

• Should there be any changes?

• Is more planning needed?

• Should financial procedures be developed to handle such incidents? Measurement

• Was there adequate measurement or estimation of the volume of product spilled?

• Was there adequate measurement or estimation of the volume of product recovered?

• Was there adequate measurement or estimation of the volume of product disposed of?

• Should better measurement procedures be developed for either phase of operations?

• If so, what would be appropriate and acceptable?


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Government Relations

• What are the roles and effects of the various government agencies which were involved?

• Was there a single focal point among the government agencies for contact?

• Were government agencies adequately informed at all stages?

• Should there have been better focus of communications to the agencies?

• Were government agencies adequately informed at all stages?

• Were too many agencies involved?

• Are any changes needed in procedures to manage government relations?

• Examples of affected U.S. agencies (there may be others): o U.S. Coast Guard o Environmental Protection Agency o National Oceanographic Atmospheric Administration o Dept of Fish and Wildlife o State Parks o Harbors and Marinas o States o Cities o Counties

• Was there adequate agreement with the government agencies on disposal methods?

• Was there adequate agreement with the government agencies on criteria for cleanup?

• How was this agreement developed?

• Were we too agreeable with the agencies in accepting their requests for specific action items (e.g., degree of cleanup)?

• Should there be advance planning of criteria for cleanup, aimed at specific local environmentally sensitive areas? (Such criteria should probably also be designed for different types of product.)

Public Relations

• How were relations with the media handled?

• What problems were encountered?

• Are improvements needed?

• How could public outcry have been reduced? Was it serious?

• Would it be useful to undertake a public information effort to "educate" reporters about product and effects to it if spilled?

• These areas should be investigated shortly after the incident to assure that actions taken are fresh in peoples' minds.


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10 APPENDIX D PHMSA F 7000-1 LINK

https://www.phmsa.dot.gov/sites/phmsa.dot.gov/files/docs/forms/12436/hlaccidentinstru

ctionsphmsa-f-7000-1on-or-after-january-1-2010_0.pdf

https://www.phmsa.dot.gov/sites/phmsa.dot.gov/files/docs/forms/12436/hlaccidentinstructionsphmsa-f-7000-1on-or-after-january-1-2010_0.pdf

https://www.phmsa.dot.gov/sites/phmsa.dot.gov/files/docs/forms/12436/hlaccidentinstructionsphmsa-f-7000-1on-or-after-january-1-2010_0.pdf


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10.1 QUALIFIED INDIVIDUAL (QI) NOTIFICATION EXERCISE – INTERNAL

EXERCISE DOCUMENTAITON

PIPELINE NAME MMS COMPLEX ID NO.

1. Date performed:

2. Exercise or actual response:

3. Person initiating exercise:

4. Name of person notified:

Is this person identified in the response plan as the: QI AQI

5. Time initiated:

Time QI or AQI responded:

6. Method used to contact:

Telephone Pager Radio

Other

7. Description of notification procedure:

8. Identify which components of your response plan were exercised during this particular

exercise:

Organizational Design Response Support Notifications Communications Staff Mobilization Transportation Ability to Operate Within the Response Management System Described in the Plan

Personnel Support


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Certifying Signature: Name (Printed):

Date:

10.2 RESPONSE TEAM TABLETOP EXERCISE – INTERNAL EXERCISE

DOCUMENTATION 1. Date(s) performed:

2. Exercise or actual response:

Exercise type: 0 Announced 0 Unannounced

3. Location of exercise:

4. Time started:

Time completed:

5. Response plan scenario used (check one):

0 Small 0 Medium 0 Worst Case Discharge

Size of (simulated) spill Bbls

6. Describe how the following objectives were exercised:

a) Response Team's knowledge of oil spill response plan:

b) Proper notifications:

Operational Response Equipment Maintenance and Support Discharge Control Procurement Assessment of Discharge Documentation Containment of Discharge Recovery of Spilled Material Protection of Economically and Environmentally Sensitive Areas Disposal of Recovered Product


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c) Communications system:

d) Response Team's ability to access contracted OSRO:

e) Response Team's ability to coordinate spill response with OSC, state and applicable

agencies:

f) Response Team's ability to access sensitive site and resource information in Area

Contingency Plan:

7. Identify which components of your response plan were exercised:


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8. Attach description of lesson(s) learned and person(s) responsible for follow up of corrective

measures.

Certifying Signature: Name (Printed):

Date:

10.3 INTERNAL EXERCISE DOCUMETATION FORM – EQUIPMENT DEPLOYMENT

EXERCISE 1. Date(s) performed:

2. Exercise or actual response?

If an exercise, announced or unannounced?

3. Deployment location(s):

4. Time started:

Time completed:

5. Equipment deployed was: Facility - owned


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Oil Spill Removal Organization-owned if so, which OSRO? Both

6. List type and amount of all equipment (e.g., boom and skimmers) deployed and number of support personnel employed:

7. Describe goals of the equipment deployment and list any Area Contingency Plan strategies tested (Attach a sketch of equipment deployments and booming strategies):

8. For deployment of facility-owned equipment, was the amount of equipment deployed at least the amount necessary to respond to your facility's average most probable spill?

Was the equipment deployed in its intended operating environment?

For deployment of OSRO-owned equipment, was a representative sample of each type deployed?

Was the equipment deployed in its intended operating environment?

10. Are all pipeline personnel that are responsible for response operations involved in a comprehensive training program, and all pollution response equipment involved in a comprehensive maintenance program?

If so, describe the program:


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Date of last equipment inspection:

11. Was the equipment deployed by personnel responsible for its deployment in the event of an actual spill?

12. Was all deployed equipment operational? If not, why not?

Response Equipment Inspection Log

Inspector Date Comments

10.4 INTERNAL EXERCISE DOCUMENTATION FORM – SPILL MANAGEMENT

TEAM TABLETOP EXERCISE

1. Date(s) performed:

2. Exercise or actual response?

If an exercise, announced or unannounced?

3. Location of Tabletop:


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4. Time started:

Time

completed:

5. Response plan scenario used (check one):

Average most probable discharge

Maximum most probable discharge

_ Worst case discharge

Size of (simulated) spill bbls

6. Describe how the following objectives were exercised:

a) Spill Management Team’s knowledge of oil spill response plan:

b) Proper Notifications:

c) Communications System:

d) Spill Management Team’s ability to access contracted Oil Spill Removal Organizations:

e) Spill Management Team’s ability to operate within a Unified Command:


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f) Spill Management Team’s ability to access sensitive site and resource information in the Area Contingency Plan:

7. Identify which of the 15 core components of your response plan were exercised during this particular exercise:

Notifications Disposal

Staff Mobilization Communications

Operate in Response Mgmt. System Transportation

Discharge Contained Personnel Support

Assessment Equipment Maintenance

Containment Procurement

Recovery Documentation

Protection

8. Attach description of lesson(s) learned and person(s) responsible for follow up of

corrective measures.

Raymond G. Meyer Director of Response Services

Response Management Associates, Inc.

Retain this form for a minimum of three (3) years (for USCG/PHMSA/BSEE) or five (5) years (for EPA).

11 APPENDIX E

RESPONSE EQUIPMENT/RESOURCES

The following Sections outline the various response equipment/resources available from the

Facility, other Company facilities, Oil Spill Removal Organizations, and other outside resources.


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11.1 FACILITY RESPONSE EQUIPMENT

Paramount Pipeline LLC contracts all equipment needs from contracted OSROs. The

OSROs minimum equipment requirements are listed in Figure E.1.

The Qualified Individual has the authority to activate other Company resources or that of

private contractors and other experts and consultants as the situation demands.

11.2 OTHER COMPANY RESOURCES

Other Company resources are not available at the facility.

11.3 CONTRACT RESOURCES

In the event of a discharge which is beyond the initial response capabilities of the Local

Response Team, contract manpower and equipment resources can be obtained through

Oil Spill Removal Organization(s) (OSRO). These OSROs can provide manpower and

containment/clean-up equipment for the response operation.

The resources will be secured from a Company approved contractor. Facility Management

will typically handle Notification/implementation of these resources. (Note: The Company

will ensure that each OSRO has a comprehensive maintenance program and applicable

training / drills programs in place at contract renewal).

11.4 COOPERATIVE AND MUTUAL AID RESOURCES

Cooperative and mutual aid resources are not available at the facility.

11.5 EXPERTS AND CONSULTANTS

The Company maintains a relationship with various environmental and technical

consultants that can provide support in the event of an emergency incident. These

consultants can provide expertise and support in the areas of emergency response

management, environmental services, site assessment, permitting, waste treatment,

recycling, dewatering, hazardous waste disposal, and remediation.

11.6 VOLUNTEERS

Volunteers will not be utilized by the Company for the response operations. All volunteers

will be referred to the State or Federal On-Scene Coordinator.

11.7 COMMUNICATIONS

Effective and efficient communications systems are essential for emergency response at

every level. The communications system will be utilized to gather information and current

status reports as well as to provide coordination and direction to widely separated work

groups involved in search, containment/ diversion, repair, traffic control, public control or

evacuation, and restoration.


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Lines of communication between the Incident Commander, Emergency Response Team

and Spill Management Team members are demonstrated in the organization chart provided

in Figure 4.1. Communication of the overall spill response operation between the Company

and the responsible government agencies in the Federal Regional Response Team (RRT)

will occur between the Incident Commander and the Federal On-Scene Coordinator.

11.7.1 Central Communications Systems

Prearranged communication channels are of the utmost importance in dealing with

Company emergencies. The notification procedures and telephone contacts

documented in Section 2.0 will be reviewed in accordance with the earlier

documented updating procedures.

11.7.2 Communications Equipment

Field communications during a spill response to a small or medium discharge will

be handled via the existing Company communications network. This network will

utilize existing radios, telephones, pagers, fax machines, and computers and will

be maintained by Company personnel. In the event of a Worst-Case Discharge,

field communications will be enhanced with other Company and contract resources

as the situation demands.

11.7.3 Communication Types

Radios – Hand-held and vehicle-mounted radio sets are the most effective means

of communication for the field response operation. The units are battery operated,

multi-channeled, and have a typical range that will cover the area of the response

operation. Additional radio sets and battery packs/charges will be necessary in the

event of a prolonged response operation. Frequencies will be assigned at the

Command Center.

Telephone (Conventional) - Conventional land-line telephones are the most

effective means of communication for regulatory and advisory notifications during

a spill response operation. Additional telephone lines can be installed in the

event of a prolonged response operation.

Telephone (Cellular) - Cellular telephones allow for added mobility and response

effectiveness. Cellular phones are commonly maintained by certain Company

personnel. Additional cellular phones can be secured in the event of a prolonged

response operation.


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FAX Machines - FAX machines allow for a rapid transfer of information/

documentation such as status reports/updates, written notifications, and purchase

orders.

Computers - Computers are commonly used in networks which allow access to

various other locations and Company personnel. Computers also speed the

consolidation of information and preparation of written report.

FIGURE E.1

MSRC LOS ANGELES AND LONG BEACH COTP ZONE

OSRO Name: Marine Spill Response Corporation -#22


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Operating

Environment

Facility

MMPD

Facility

WCD1

Facility

WCD2

Facility

WCD3

Vessel

MMPD

Vessel

WCD1

Vessel

WCD2

Vessel

WCD3

River or Canal Yes Yes Yes Yes Yes Yes Yes Yes

Inland Yes ~ Yes Yes Yes Yes Yes Yes

Ocean Yes ~ Yes Yes Yes Yes Yes Yes

Near Shore Yes ~ Yes Yes Yes Yes Yes Yes

Off Shore Yes ~ Yes Yes Yes Yes Yes Yes

OSRO Name: National Response Corporation -#16

Operating

Environment

Facility

MMPD

Facility

WCD1

Facility

WCD2

Facility

WCD3

Vessel

MMPD

Vessel

WCD1

Vessel

WCD2

Vessel

WCD3

River or Canal Yes Yes Yes Yes Yes Yes Yes Yes

Inland Yes Yes Yes Yes Yes Yes Yes Yes

Ocean ~ ~ Yes Yes Yes Yes Yes Yes

Near Shore Yes Yes Yes Yes Yes Yes Yes Yes

Off Shore Yes Yes Yes Yes Yes Yes Yes Yes

FIGURE E.2 MSRC EQUIPMENT LIST


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FIGURE E.3 MSRC CONTRACT


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12 APPENDIX F

SPILL HISTORY

12.1 CSFM NO. 1183 (CHEMOIL LINE) APRIL 26TH, 2007

This Chemoil line leased by Paramount Petroleum beginning in February of 2007 leaked on

April 26, 2007 at approximately 555 Pico Avenue in the Port of Long Beach. The leak

occurred in a section of line that had been severely damaged previously by a 3rd party

contractor. Proximate time that this occurred was in 1999 when storm water drain lines were

installed parallel to the Chemoil Line. The heavy equipment used to excavate the dirt for

the storm water line tore a 7’ gash in the coating and damaged the pipeline as well. This

damage was not repaired or reported, and the line was subsequently buried. After about 2

months of operation in 2007, a pinhole leak occurred in the line which leaked 5 BBLS of

Crude into the Storm Drain and down into the Harbor. Approximately 400’ of line was

replaced and moved two feet to the west of the storm drain to avoid future interference.

12.2 CSFM NO. 1085 (PPC LINE 160) APRIL 16TH, 2010

The Line 160, CSFM 1085, failed to hold pressure during hydrotest. Subsequent

investigation located two line leaks, one in the Metro Train Yard and one in the Hinkle and

McCoy site. Both leaks were identified to be at threaded coupling connections. Liquids

containing hydrocarbon and contaminated soil were removed at both sites and 300 ft. of

new pipeline was installed replacing 17 threaded couplings. After the line was repaired, it

was successfully hydrotested and returned to service.

12.3 OTHER PARAMOUNT LINES

There have been no significant leaks or spills from these lines in the past 10 years.

12.4 LAKEWOOD TANK FARM

The Lakewood Tank Farm has not had any reportable oil spills since Paramount

purchased the tank farm in 1982.

13 APPENDIX G

DISPOSAL PLAN


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Abandon Pipeline: A pipeline or pipeline segment which has met the criteria of an Out-Of-Service pipeline (purged, sealed and disconnected from an operating system) but will not be maintained to minimum USDOT inspection and maintenance standards.

Activate: The process of mobilizing personnel and/or equipment within the response organization to engage in response operations.

Activator: An individual in the response organization whose responsibilities include notifying other individuals or groups within the organization to mobilize personnel and/or equipment.

Active Pipeline: A pipeline or pipeline segment which is in service whether or not the pipeline is fully operational. This includes pipelines which may have been utilized to transport hazardous liquids but are currently static or unused.

Adverse Weather: The weather conditions that will be considered when identifying response systems and equipment in a response plan for the applicable operating environment. Factors to consider include significant wave height, ice, temperature, weather - related visibility, and currents within the Captain of the Port (COTP) zone in which the systems or equipment are intended to function.

Agency Representative: Individual assigned to an incident from an agency who has been delegated full authority to make decisions on all matters affecting that agency's participation in response operations.

Alert: Means an incident has occurred at the terminal which has the potential to affect off-site locations.

Area Committee: As defined by Sections 311(a)(18) and (j)(4) of CWA, as amended by OPA, means the entity appointed by the President consisting of members from Federal, State, and local agencies with responsibilities that include preparing an Area Contingency Plan for the area designated by the President. The Area Committee may include ex- officio (i.e., non-voting) members (e.g., industry and local interest groups).

Area Contingency Plan: As defined by Sections 311(a)(19) and (j)(4) of CWA, as amended by OPA, means the plan prepared by an Area Committee, that, in conjunction with the NCP, shall address the removal of a discharge including a worst-case discharge and the mitigation or prevention of a substantial threat of such a discharge from a vessel, offshore facility, or onshore facility operating in or near an area designated by the President

Average Most Probable Discharge: A discharge of the lesser of 50 barrels or 1% of the volume of the worst case discharge. Barrel (bbl): Measure of space occupied by 42 U.S. gallons at 60 degrees Fahrenheit. Bioremediation Agents: Means microbiological cultures, enzyme additives, or nutrient additives that are deliberately introduced into an oil discharge and that will significantly increase the rate of biodegradation to mitigate the effects of the discharge. Boom: A piece of equipment or a strategy used to either contain free floating oil to a confined area or protect an uncontaminated area from intrusion by oil. Booming Strategies: Strategic techniques which identify the location and quantity of boom required to protect certain areas. These techniques are generated by identifying a potential spill source and assuming certain conditions which would affect spill movement on water. Breakout Tank: Means a tank used to (a) relieve surges in a hazardous liquid pipeline system or (b) receive and store hazardous liquid transported by a pipeline for reinjection and continued transportation by pipeline. Bulk: Material that is stored or transported in a loose, unpackaged liquid, powder, or granular form capable of being conveyed by a pipe, bucket, chute, or belt system. Captain of the Port Zone (COTP): Means a zone specified in 33 CFR Part 3 and the seaward extension of that zone to the outer boundary of the exclusive economic zone (EEZ). CERCLA: Means the Comprehensive Environmental Response, Compensation Liability Act regarding hazardous substance releases into the environment and the cleanup of inactive hazardous waste disposal sites. Chemical Agents: Means those elements, compounds, or mixtures that coagulate, disperse, dissolve, emulsify, foam, neutralize, precipitate, reduce, solubilize, oxidize, concentrate, congeal, entrap, fix, make the pollutant mass more rigid or viscous, or otherwise facilitate the mitigation of deleterious effects or the removal of the oil pollutant from the water. Chemical agents include biological additives, dispersants, sinking agents, miscellaneous oil spill control agents, and burning agents, but do not include solvents.

Recovered product, oil and any recoverable hydrocarbons will be transferred to the process

equipment for reuse. An effort will be made to minimize the amount of waste resulting from a spill.

Any contaminated soil, cleanup materials such as oily rags, spill booms, and sorbent materials

will be collected, held in approved containers in regulated areas, and eventually sent off-site for

treatment to an approved facility. Waste minimization through the use of reuse or recovery will be

given a high priority.

Wastes deemed unsuitable for in-plant reuse or recovery will be shipped to approved waste

management sites. Requirements for labeling, placarding, manifesting and permitting for these

waste shipments will follow Federal/State Requirements.

The need to decant oil-contaminated water back into the environment is not anticipated. If such a

need arises, pre-approval from the Federal On-Scene Commander must be obtained and other

permits may be required due to environmental sensitivities. The Environmental Department will

be responsible for obtaining all such approvals and permits.

14 GLOSSARY


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CHEMTREC: Means the Chemical Transportation Emergency Center operated by Chemical Manufacturers Association. Provides information and/or assistance to emergency responders. Can be reached 24 hours a day by calling 800-424-9300.

Clean-up Contractor: Persons contracted to undertake a response action to clean up a spill.

Cleanup: For the purposes of this document, cleanup refers to the removal and/or treatment of oil, hazardous substances, and/or the waste or contaminated materials generated by the incident. Cleanup includes restoration of the site and its natural resources.

Coastal Waters: For the purpose of classifying the size of discharges, means the waters of the coastal zone except for the Great Lakes and specified ports and harbors on inland rivers.

Coastal Zone: As defined for the purpose of the NCP, means all United States waters subject to the tide, United States waters of the Great Lakes, specified ports and harbors on inland rivers, waters of the contiguous zone, other waters of the high seas subject to the NCP, and the land surface or land substrata, ground waters, and ambient air proximal to those waters. The term coastal zone delineates an area of federal responsibility for response action. Precise boundaries are determined by EPA/USCG agreements and identified in federal regional contingency plans.

Coast Guard District Response Group (DRG): As provided for by CWA sections 311(a)(20) and (j)(3), means the entity established by the Secretary of the department in which the USCG is operating within each USCG district and shall consist of: the combined USCG personnel and equipment, including firefighting equipment, of each port within the district; additional prepositioned response equipment; and a district response advisory team.

Command: The act of controlling manpower and equipment resources by virtue of explicit or delegated authority.

Command Post: A site located at a safe distance form the spill site where response decisions are made, equipment and manpower deployed, and communications handled. The Incident Commander and the On-Scene Coordinators may direct the on- scene response from this location.

Communications Equipment: Equipment that will be utilized during response operations to maintain communication between the Company employees, contractors, Federal/State/Local agencies. (radio/ telephone equipment and links)

Containment Boom: A flotation/freeboard device, made with a skirt/curtain, longitudinal strength member, and ballast unit/weight designed to entrap and contain the product for recovery. Contingency Plan: (1) A document used by federal, state, and local agencies to guide their planning and response procedures regarding spills of oil, hazardous substances, or other emergencies; and/or (2) a document used by industry as a response plan to spills of oil, hazardous substances, or other emergencies occurring upon their vessels or at their facilities. Contract or Other Approved Means: For OPA 90, a written contract with a response contractor; certification by the facility owner or operator that personnel and equipment are owned, operated, or under the direct control of the facility, and available within the stipulated times; active membership in a local or regional oil spill removal organization; and/or the facility’s own equipment. Critical Areas to Monitor: Areas which if impacted by spilled oil may result in threats to public safety or health. Cultural Resources: Current, historic, prehistoric and archaeological resources which include deposits, structures, ruins, sites, buildings, graves, artifacts, fossils, or other objects of antiquity which provide information pertaining to the historical or prehistorical culture of people in the state as well as to the natural history of the state. Damage Assessment: The process of determining and measuring damages and injury to the human environment and natural resources, including cultural resources. Damages include differences between the conditions and use of natural resources and the human environment that would have occurred without the incident, and the conditions and use that ensued following the incident. Damage assessment includes planning for restoration and determining the costs of restoration. Decontamination: The removal of hazardous substances from personnel and their equipment necessary to prevent adverse health effects. Discharge: Any spilling, leaking, pumping, pouring, emitting, emptying, or dumping. Dispersants: Means those chemical agents that emulsify, disperse, or solubilize oil into the water column or promote the surface spreading of oil slicks to facilitate dispersal of the oil into the water column.


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Diversion Boom: A floatation/freeboard device, made with a skirt/curtain, longitudinal strength member, and ballast unit/weight designed to deflect or divert the product towards a pick up point, or away from certain areas.

Drinking Water Supply: As defined by Section 101(7) of CERCLA, means any raw or finished water source that is or may be used by a public water system (as defined in the Safe Drinking Water Act) or as drinking water by one or more individuals.

Economically Sensitive Areas: Those areas of explicit economic importance to the public that due to their proximity to potential spill sources may require special protection and include, but are not limited to: potable and industrial water intakes; locks and dams; and public and private marinas.

Emergency Planning Zone: Means the area designated by the jurisdiction boundaries of those communities which are within a radial distance of one-half mile from the terminal.

Emergency Response: Means the response to any occurrence which results, or is likely to result, in a release of a hazardous substance due to an event.

Emergency Service: Those activities provided by state and local government to prepare for and carry out any activity to prevent, minimize, respond to, or recover from an emergency.

Emulsion: Suspension of oil in water.

Environmentally Sensitive Areas: Streams and water bodies, aquifer recharge zones, springs, wetlands, agricultural areas, bird rookeries, endangered or threatened species (flora and fauna) habitat, wildlife preserves or conservation areas, parks, beaches, dunes, or any other area protected or managed for its natural resource value.

Exclusive Economic Zone: Means the zone contiguous to the territorial sea of the United States extending to a distance up to 200 nautical miles from the baseline from which the breadth of the territorial sea is measured.

Facility (DOT): Means new and existing pipe, rights-of-way and any equipment, facility, or building used in the transportation of hazardous liquids or carbon dioxide.

Facility (EPA/USCG): Either an onshore facility or an offshore facility and includes, but is not limited to structures, equipment, and appurtenances thereto, used or capable of being used to transfer oil to or from a vessel or a public vessel. A facility includes federal, state, municipal, and private facilities.

Facility That Could Reasonably Be Expected To Cause Significant And Substantial Harm: Means any fixed MTR on-shore facility (including piping and any structures that are used for the transfer of oil between a vessel and a facility) that is capable of transferring oil, in bulk, to or from a vessel of 250 barrels or more, and a deepwater port. This also includes any facility specifically identified by the COTP. Facility That Could Reasonably Be Expected To Cause Substantial Harm: Means any mobile MTR facility that is capable of transferring oil to or from a vessel with a capacity of 250 barrels or more. This also includes any facility specifically identified by the COTP. Facility Operator: The person who owns, operates, or is responsible for the operation of the facility. Federal Fund: The spill liability trust fund established under OPA. Federal Regional Response Team (RRT): The federal response organization (consisting of representatives from selected federal and state agencies) which acts as a regional body responsible for planning and preparedness before an oil spill occurs and providing advice to the FOSC in the event of a major or substantial spill. Federal Response Plan (FRP): Means the agreement signed by 25 federal departments and agencies in April 1987 and developed under the authorities of the Earthquake Hazards Reduction Act of 1977 and the Disaster Relief Act of 1974, as amended by the Stafford Disaster Relief Act of 1988. First Responders, First Response Agency: A public health or safety agency (e.g., fire service or police department) charged with responding to a spill during the emergency phase and alleviating immediate danger to human life, health, safety, or property. General Emergency: Means an incident has occurred and the affected community is implementing protective actions. Handle: To transfer, transport, pump, treat, process, store, dispose of, drill for, or produce. Harmful Quantity Of Oil: The presence of oil from an unauthorized discharge in a quantity sufficient either to create a visible film or sheen upon or discoloration of the surface of the water or a shoreline, tidal flat, beach, or marsh, or to cause a sludge or emulsion to be deposited beneath the surface of the water or on a shoreline, tidal flat, beach, or marsh.


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Hazardous Chemicals: Means all chemicals which constitute a physical hazard or a health hazard as defined by 29 CFR 1910.1200, with the exceptions listed in section 311(e). This term comprises approximately 90 percent of all chemicals.

Hazardous Material: Any nonradioactive solid, liquid, or gaseous substance which, when uncontrolled, may be harmful to humans, animals, or the environment. Including but not limited to substances otherwise defined as hazardous wastes, dangerous wastes, extremely hazardous wastes, oil, or pollutants.

Hazardous Substance: Any substance designated as such by the Administrator of the EPA pursuant to the Comprehensive Environmental Response, Compensation, and Liability Act; regulated pursuant to Section 311 of the Federal Water Pollution Control Act, or discharged by the SERC.

Hazardous Waste: Any solid waste identified or listed as a hazardous waste by the Administrator of the EPA pursuant to the federal Solid W aste Disposal Act, as amended by the Resource Conservation and Recovery Act (RCRA), 42 U.S.C., Section 6901, et seq as amended. The EPA Administrator has identified the characteristics of hazardous wastes and listed certain wastes as hazardous in Title 40 of the Code of Federal Regulations, Part 261, Subparts C and D respectively.

HAZMAT: Hazardous materials or hazardous substances, exposure to which may result in adverse effects on health or safety of employees.

HAZWOPER: Hazardous Waste Operations and Emergency Response Regulations published by OSHA to cover worker safety and health aspects of

Health Hazard: Means a chemical for which there is statistically significant evidence based on at least one study conducted in accordance with established scientific principals that acute or chronic health effects may occur in exposed employees.

Heat Stress: Dangerous physical condition caused by over exposure to extremely high temperatures.

Hypothermia: Dangerous physical condition caused by over exposure to freezing temperatures.

Incident: Any event that results in a spill or release of oil or hazardous materials. Action by emergency service personnel may be required to prevent or minimize loss of life or damage to property and/or natural resources.

Incident Briefing Meeting: Held to develop a comprehensive, accurate, and up-to-date understanding of the incident, nature of status of control operations, and nature and status of response operations; ensure the adequacy of control and response operations; begin to organize control and response operations; and prepare for interactions with outside world. Incident Command Post (ICP): That location at which all primary command functions are executed. Incident Command System (ICS): The combination of facilities, equipment, personnel, procedures, and communications operating within a common organizational structure, with responsibility for the management of assigned resources at an incident. Incident Commander (IC): The one individual in charge at any given time of an incident. The Incident Commander will be responsible for establishing a unified command with all on-scene coordinators. Indian Tribe: As defined in OPA section 1001, means any Indian tribe, band, nation, or other organized group or community, but not including any Alaska Native regional or village corporation, which is recognized as eligible for the special programs and services provided by the United States to Indians because of their status as Indians and has governmental authority over lands belonging to or controlled by the Tribe. Initial Cleanup: Remedial action at a site to eliminate acute hazards associated with a spill. An initial clean-up action is implemented at a site when a spill of material is an actual or potentially imminent threat to public health or the environment, or difficulty of cleanup increases significantly without timely remedial action. All sites must be evaluated to determine whether initial cleanup is total cleanup, however, this will not be possible in all cases due to site conditions (i.e., a site where overland transport or flooding may occur). Initial Notification: The process of notifying the necessary Company personnel and Federal/ State/Local agencies that a spill has occurred, including all pertinent available information surrounding the incident. Initial Response Actions: The immediate actions that are to be taken by the spill observer after detection of a spill.


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Inland Area: means the area shoreward of the boundary lines defined in 46 CFR part 7; in the Gulf of Mexico, it means the area shoreward of the lines of demarcation (COLREG lines) as defined in §80.740 through 80.850 of this chapter. The inland area does not include the Great Lakes.

Inland Waters: State waters not considered coastal waters; lakes, rivers, ponds, streams, underground water, et. al. Inland Zone: Means the environment inland of the coastal zone excluding the Great Lakes, and specified ports and harbors on inland rivers. The term inland zone delineates an area of federal responsibility for response action. Precise boundaries are determined by EPA/USCG agreements and identified in federal regional contingency plans.

Interim Storage Site: A site used to temporarily store recovered oil or oily waste until the recovered oil or oily waste is disposed of at a permanent disposal site. Interim storage sites include trucks, barges, and other vehicles, used to store waste until the transport begins.

Internally Reported Event: An incident that does not meet the reporting criteria established for notification of off-site authorities. No evacuation has occurred.

Lead Agency: The government agency that assumes the lead for directing response activities.

Lead Federal Agency: The agency which coordinates the federal response to incident on navigable waters. The lead federal agencies are:

• U.S. Coast Guard: Oil and chemically

hazardous materials incidents on navigable

waters. • Environmental Protection Agency: Oil

and chemically hazardous materials incidents on inland waters.

Lead State Agency: The agency which coordinates state support to federal and/or local governments or assumes the lead in the absence of federal response.

Line Section: Means a continuous run of pipe between adjacent pressure pump stations, between a pressure pump station and terminal or breakout

tanks, between a pressure pump station and a block valve, or between adjacent block valves.

Light Oil Terminal Operations: Means the storage and distribution of gasoline and diesel fuel to wholesale customers. Loading: Transfer from Facility to vehicle. Local Emergency Planning Committee (LEPC): A group of local representatives appointed by the State Emergency Response Commission (SERC) to prepare a comprehensive emergency plan for the local emergency planning district, as required by the Emergency Planning and Community Right-to-Know Act (EPCRA). Local Response Team: Designated Facility individuals who will fulfill the roles determined in the oil spill response plan in the event of an oil or hazardous substance spill. They will supervise and control all response and clean-up operations. Lower Explosive Limit: Air measurement utilized to determine the lowest concentration of vapors that support combustion. This measurement must be made prior to entry into a spill area. Marinas: Small harbors with docks, services, etc. for pleasure craft. Marine Transportation Related Facility (MTR FACILITY): Means an on-shore facility, including piping and any structure used to transfer oil to or from a vessel, subject to regulation under 33 CFR Part 154 and any deepwater port subject to regulation under 33 CFR Part 150. Maximum Extent Practicable: Means the planning values derived from the planning criteria used to evaluate the response described in the response plan to provide the on-water recovery capability and the shoreline protection and cleanup capability to conduct response activities for a worst case discharge from a facility in adverse weather. Maximum Most Probable Discharge: Means a discharge of the lesser of 1,200 barrels or 10 percent of the volume of a worst case discharge.

Medium Discharge: Means a discharge greater than 2,100 gallons (50 Bbls) and less than or equal to 36,000 gallons (85+ Bbls) or 10% of the capacity of the largest tank, whichever is less and not to exceed the WCD.


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National Contingency Plan: The plan prepared under the Federal Water Pollution Control Act (33 United State Code §1321 et seq) and the Comprehensive Environmental Response, Compensation, and Liability Act of 1980 (42 United State Code § 9601 et seq), as revised from time to time.

National Pollution Funds Center (NPFC): Means the entity established by the Secretary of Transportation whose function is the administration of the Oil Spill Liability Trust Fund (OSLTF). Among the NPFC’s duties are: providing appropriate access to the OSLTF for federal agencies and states for removal actions and for federal trustees to initiate the assessment of natural resource damages; providing appropriate access to the OSLTF for claims; and coordinating cost recovery efforts.

National Response System (NRS): Is the mechanism for coordinating response actions by all levels of government in support of the OSC. The NRS is composed of the NRT, RRTs, OSC, Area Committees, and Special Teams and related support entities.

National Strike Force (NSF): Is a special team established by the USCG, including the three USCG Strike Teams, the Public Information Assist Team (PIAT), and the National Strike Force Coordination Center. The NSF is available to assist OSCs in their preparedness and response duties.

National Strike Force Coordination Center (NSFCC): Authorized as the National Response Unit by CWA section 311(a)(23) and (j)(2); the entity established by the Secretary of the Department of Transportation through which the USCG, operating from Elizabeth City, North Carolina, is responsible for administration of the USCG Strike Teams, maintenance of response equipment inventories and logistic networks, and conducting a national exercise program.

Natural Resource: Land, fish, wildlife, biota, air, water, ground water, drinking water supplies, and other such resources belonging to, managed by, held in trust by, appertaining to or otherwise controlled by the state, federal government, private parties, or a municipality.

Navigable Waters: As defined in section 502(7) of the FWPCA. The term includes:

All navigable waters of the United States, as defined in judicial decisions prior to the passage of the 1972 Amendments of the Federal Water Pollution Control Act, (FWPCA) (Pub. L. 92-500) also known as the Clean Water Act (CWA), and tributaries of such waters.

Interstate waters Intrastate lakes, rivers, and streams which are utilized by interstate travelers for recreational or other purposes. Intrastate lakes, rivers, and streams from which fish or shellfish are taken and sold in interstate commerce. Nearshore Area: For OPA 90, the area extending seaward 12 miles from the boundary lines defined in 46 CFR Part 7, except in the Gulf of Mexico. In the Gulf of Mexico, it means the area extending seaward 12 miles from the line of demarcation defined in §80.740 - 80.850 of title 33 of the CFR. Non-persistent or Group I Oil: A petroleum-based oil that, at the time of shipment, consists of hydrocarbon fractions: 1. At least 50% of which by volume, distill at a

temperature of 340 degrees C (645 degrees F); 2. At least 95% of which volume, distill at a

temperature of 370 degrees C (700 degrees F). Ocean: The open ocean, offshore area, and nearshore area as defined in this subpart. Offshore area: The area up to 38 nautical miles seaward of the outer boundary of the nearshore area. Oil or Oils: Naturally occurring liquid hydrocarbons at atmospheric temperature and pressure coming from the earth, including condensate and natural gasoline, and any fractionation thereof, including, but not limited to, crude oil, petroleum gasoline, fuel oil, diesel oil, oil sludge, oil refuse, and oil mixed with wastes other than dredged spoil. Oil does not include any substance listed in Table 302.4 of 40 CFR Part 302 adopted August 14, 1989, under Section 101(14) of the federal comprehensive environmental response, compensation, and liability act of 1980, as amended by P. L. 99-499. Oil Spill Liability Trust Fund: Means the fund established under section 9509 of the Internal Revenue Code of 1986 (26 U.S.C. 9509). Oil Spill Removal Organization (OSRO): Means an entity that provides response resources. Oily Waste: Product-contaminated waste resulting from a spill or spill response operations. On-Scene Coordinator (OSC): Means the federal official predesignated by the EPA or the USCG to coordinate and direct response under subpart D.


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On-site: Means the areal extent of contamination and all suitable areas in very close proximity to the contamination necessary for implementation of a response action.

Open Ocean: means the area from 38 nautical miles seaward of the outer boundary of the nearshore area, to the seaward boundary of the exclusive economic zone.

Operating Area: Refers to the rivers and canals, inland, nearshore, Great Lakes, or offshore geographic location(s) in which a facility is handling, storing, or transporting oil.

Operating Environment: Refers to rivers and canals, inland, Great Lakes, or ocean. These terms are used to define the conditions in which response equipment is designed to function.

Out of Service (OOS) Pipeline: A pipeline or pipeline segment which has been effectively cleaned of all hazardous liquids, filled with water or inert gas and blinded or otherwise isolated from an active pipeline system.

Owner or Operator: Any person, partnership, corporation, association, governmental unit or public or private organization of any character that owns, operates pipelines, facilities, or is involved in the transportation of oil.

Persistent Oil: A petroleum-based oil that does not meet the distillation criteria for a non-persistent oil. For the purposes of this Appendix, persistent oils are further classified based on specific gravity as follows:

1. Group II specific gravity less than .85 2. Group III specific gravity between .85 and less

than .95 3. Group IV specific gravity .95 and including 1.0 4. Group V specific gravity greater than 1.0

PHMSA: Pipeline and Hazardous Materials Safety Administration (replaced by RSPA)

Pipeline System: Means all parts of a pipeline facility through which a hazardous liquid or carbon dioxide moves in transportation, including but not limited to, line pipe, valves, and other appurtenances connected to line pipe, pumping units, fabricated assemblies associated with pumping units, metering and delivery stations and fabricated assemblies therein, and breakout tanks.

Plan Holder: The plan holder is the industry transportation related facility for which a response plan is required by federal regulation to be submitted by a vessel or facility’s owner or operator.

Post Emergency Response: The phase of a response performed after the immediate threat of a release has been stabilized or eliminated and cleanup of the sites has begun. Primary Response Contractors or Contractors: An individual, company, or cooperative that has contracted directly with the plan holder to provide equipment and/or personnel for the containment or cleanup of spilled oil. Qualified Individual (QI): That person or entity who has authority to activate a spill cleanup contractor(s), act as liaison with the "On-Scene Coordinator" and obligate funds required to effectuate response activities. Recreation Areas: Publicly accessible locations where social/sporting events take place. Regional Response Team (RRT): The Federal response organization (consisting of representatives from selected federal and state agencies) which acts as a regional body responsible for overall planning and preparedness for oil and hazardous materials releases and for providing advice to the OSC in the event of a major or substantial spill.

Remove or Removal: As defined by section 311(a)(8) of the CWA, refers to containment and removal of oil or hazardous substances from the water and shorelines or the taking of such other actions as may be necessary to minimize or mitigate damage to the public health or welfare (including, but not limited to, fish, shellfish, wildlife, public and private property, and shorelines and beaches) or to the environment. For the purpose of the NCP, the term also includes monitoring of action to remove discharge. Response Activities: The containment and removal of oil from the water and shorelines, the temporary storage and disposal of recovered oil, or the taking of other actions as necessary to minimize or mitigate damage to public health or welfare, or the environment. Response Contractors: Persons/companies contracted to undertake a response action to contain and/or clean up a spill. Response Guidelines: Guidelines for initial response that are based on the type of product involved in the spill, these guidelines are utilized to determine clean-up methods and equipment. Response Plan: A practical manual used by industry for responding to a spill. Its features include: (1) identifying the notifications sequence, responsibilities, response techniques, etc. in a easy to use format; (2) using decision trees, flowcharts, and checklists to ensure the proper response for spills with varying characteristics; and (3)


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Spill Response Personnel: Federal, state, local agency, and industry personnel responsible for participating in or otherwise involved in spill response. All spill response personnel will be pre- approved on a list maintained in each region.

Staging Areas: Designated areas near the spill site accessible for gathering and deploying equipment and/or personnel.

State Emergency Response Commission (SERC): A group of officials appointed by the governor to implement the provisions of Title III of the Federal Superfund Amendments and Re- authorization Act of 1986 (SARA). The SERC approves the State Oil and Hazardous Substance Discharge Prevention and Contingency Plan and Local Emergency Response Plans.

Substantial Threat of a Discharge: Means any incident or condition involving a facility that may create a risk of discharge of fuel or cargo oil. Such incidents include, but are not limited to storage tank or piping failures, above ground or underground leak, fires, explosions, flooding spills contained within the facility, or other similar occurrences.

Surface Collecting Agents: Means those chemical agents that form a surface film to control the layer thickness of oil.

Surface Washing Agent: Is any product that removes oil from solid surfaces, such as beaches and rocks, through a detergency mechanism and does not involve dispersing or solubilizing the oil into the water column.

Tanker: A self-propelled tank vessel constructed or adapted primarily to carry oil or hazardous material in bulk in the cargo spaces.

Tidal Current Tables: Tables which contain the predicted times and heights of the high and low waters for each day of the year for designated areas.

Toxic Substances: Any substances which have the capacity to produce personal injury or illness to man through ingestion, inhalation, or absorption through any body surface.

Trajectory Analysis: Estimates made concerning spill size, location, and movement through aerial surveillance or computer models.

Transfer: Any movement of oil to, from, or within a vessel by means of pumping, gravitation, or displacement.

Trustee: Means an official of a federal natural resources management agency designated in subpart G of the NCP or a designated state official or Indian tribe or, in the case of discharges covered by the OPA, a foreign government official, who may pursue claims for damages under section 1006 of the OPA. Underwriter: An insurer, a surety company, a guarantor, or any other person, other than an owner or operator of a vessel or facility, that undertakes to pay all or part of the liability of an owner or operator. Unified Command: The method by which local, state, and federal agencies and the responsible party will work with the Incident Commander to: • Determine their roles and responsibilities for a

given incident. • Determine their overall objectives for

management of an incident. • Select a strategy to achieve agreed-upon

objectives. • Deploy resources to achieve agreed-upon

objectives. Unified or Coordinated Command Meeting: Held to obtain agreement on strategic objectives and response priorities, review tactical strategies, engage in joint planning, integrate response operations, maximize use of resources, and minimize resolve conflicts. Unusual Event: Means an incident has occurred which is noticeable and dramatic from the Terminal perimeter; however, no outside assistance is required and no evacuation outside the incident scene has occurred. Volunteers: An individual who donates their services or time without receiving monetary compensation. Waste: Oil or contaminated soil, debris, and other substances removed from coastal waters and adjacent waters, shorelines, estuaries, tidal flats, beaches, or marshes in response to an unauthorized discharge. Waste means any solid, liquid, or other material intended to be disposed of or discarded and generated as a result of an unauthorized discharge of oil. Waste does not include substances intended to be recycled if they are in fact recycled within 90 days of their generation or if they are brought to a recycling facility within that time. Waters of the U.S. - See Navigable Waters.


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AC - Area Committee

ACP - Area Contingency Plan

ADAPTS - Air Deliverable Anti-Pollution Transport

AFFF - Aqueous Film Forming Foam

AGT - Any Gross Tonnage (TONS)

AOR - Area of Responsibility

API - American Petroleum Institute

AQI - Alternate Qualified Individual

ARPA - Automatic Radar Plotting Aid

AST - Aboveground Storage Tank

ASTM - American Society for Testing and Materials

AT - Airtight

ATSDR - Agency for Toxic Substances and Disease Registry

AWG - American Wire Gauge

B - Beam

BIA - Bureau of Indian Affairs

BBL - Barrel (Unit of Volume Equal to 42 Gallons)

BLM - Bureau of Land Management

BPD - Barrels Per Day

BPH - Barrels Per Hour

BOD - Biological Oxygen Demand

BOM - Bureau of Mines

C - Degrees Centigrade

C3 - Command, Control, and Communications

C & R - Cargoes and Restriction (List)

CAER - Community Awareness and Emergency Response

CERCLA - Comprehensive Environmental Response, Compensation and Liability Act

CCR - California Code of Regulations

CDB - Continuous Discharge Book

CDG - Subcommittee on the Carriage of Dangerous Goods

CEQ - Council on Environmental Quality

CFM - Cubic Feet per Minute

CFR - Code of Federal Regulations

CG or USCG - Coast Guard

CGA - Compressed Gas Association

CH - Cargo Hold

CHEMTREC - Chemical Transportation Emergency Center

CHRIS - Chemical Hazards Response Information System

CMA - Chemical Manufacturers Association

CNG - Compressed Natural Gas

CO - Commanding Officer COA

- Certificate of Adequacy

COC - Certificate of Compliance

COE - U. S. Army Corps of Engineers

COF - Certificate of Fitness

COFR - Certificate of Financial Responsibility

COI - Certificate of Inspection

COIL - Central Oil Identification Laboratory

COMDTINST - Commandant Instruction

COMDTNOTE- Commandant Notice

COMDTPUB - Commandant’s Publication

CONUS - Continental United States

COPH - Cargoes of Particular Hazard

CORE - Contingency Response

COTP - Captain of the Port Zone

COW - Crude Oil Washing

CRZ - Contamination Reduction Zone

CS - General Cargo Ship

CSA - Canada Standards Association

CSC - International Convention for Safe Containers, 1972

CT - Cargo Tank

C/V - Container Vessel

CVS - Commercial Vessel Safety Program

CWA - Clean Water Act (Federal - Public Law 100-4)

CWS - Community Water System

CZM - Coastal Zone Management

DECON - Decontamination

DEQ - Department of Environmental

Quality

DL - Decision Letters

DOC - Department of Commerce


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DOD - Department of Defense

DOE - Department of Energy

DOI - Department of Interior

DOJ - Department of Justice

DOL - Department of Labor

DOS - Department of State

DOSC Deputy On-Scene Coordinator

DOT - Department of Transportation

DSHO - Designated Safety and Health Official

DWT - Deadweight Tons

EBS - Emergency Broadcast System

EEBA - Emergency Escape Breathing Apparatus

EEI - Essential Elements of Information

EERU - Environmental Emergency Response Unit

EG - Emergency Generator Room

EHS - Extremely Hazardous Substance

EIS - Environmental Impact Statement

EMA - Emergency Management Agency

EMS - Emergency Medical Service

EMT - Emergency Medical Technician

EO - Executive Order

EOC - Emergency Operations Center

EOD Explosive Ordinance Disposal

EP - Estimated Position

EPA - U. S. Environmental Protection Agency

EPCRA - The Emergency Planning and Right-to-Know Act of 1986 (Title III of SARA)

EQ - Environmental Quality

ERT - Environmental Response Team

ESA - Endangered Species Act

ESD - Emergency Shutdown

ETA - Estimated Time of Arrival

ETF - Emergency Task Force

FAA - Federal Aviation Administration

FAX - Facsimile Machine

FCC - Federal Communications Commission

FCL - Flammable Cryogenic Liquid

FEMA - Federal Emergency Management Agency

FMC - Federal Maritime Commission

FOIA - Freedom of Information Act

FOIL - Field Oil Identification Laboratory

FOSC - Federal On-Scene Coordinator

FP - Flashpoint

FPN - Federal Project Number

FR - Federal Register

FRDA - Freshwater Resource Damage Assessment

FRF - Federal Revolving Fund

FT - Fuel Tank

FTJ - Failure to Join

FWPCA - Federal Water Pollution Control Act (as amended) (33 U.S.C. 1251 et seq.)

GIS - Geographic Information System

GMT - Greenwich Mean Time

GPM - Gallons Per Minute

GSA - General Services Administration

GT - Gross Tons HAZMAT -

Hazardous Materials HAZWOPER

- Hazardous Waste Operations and Emergency Response

HHS - Department of Health and Human Services

HP - High Pressure

IC - Incident Commander

ICS - Incident Command System

IDLH - Immediately Dangerous to Life - or Health

IG - Inert Gas

IGS - Inert Gas System

IOPP - International Oil Pollution Prevention Convention

IS - Intrinsically Safe

JRT - Joint Response Team

KW - Kilowatt

LEL - Lower Explosive Limit

LEPC - Local Emergency Planning Committee

LFL - Lower Flammable Limit

LNG - Liquefied Natural Gas

LOA - Length Overall

LOC - Letter of Compliance


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LOP - Line of Position

LOSC - Local On-Scene Coordinator

LOX - Liquefied Oxygen

LP - Low Pressure

LPG - Liquefied Petroleum Gas

LRT - Local Response Team

MAWP - Maximum Allowable Working Pressure

MBL - Mobile

MEP - Marine Environmental Protection

MOU - Memorandum of Understanding

MSDS - Material Safety Data Sheet

MSO - Marine Safety Office

MSU - Marine Safety Unit

N/A - Not Applicable

NC - Not Certified

NCP - National Contingency Plan

NCWS - Non-Community Water System

NEPA - National Environmental Policy Act

NIIMS - National Interagency Incident Management System

NIOSH - National Institute for Occupational Safety and Health

NLS - Noxious Liquid Substances

NM - Nautical Mile

NMFS - National Marine Fisheries Service

NMT - Not More Than

NOAA - National Oceanic and Atmospheric Administration (Department of Commerce)

NPDES - National Pollution Discharge Elimination System

NPFC - National Pollution Funds Center

NPRM - Notice of Proposed Rulemaking

NPS - National Park Service

NRC - National Response Center

NRDA - Natural Resource Damage Assessment

NRS - National Response System

NRT - National Response Team

NSF - National Strike Force

NSFCC - National Strike Force Coordination Center

NTNCWS - Non -Transient Non-Community Water System

OPA - Oil Pollution Act

OPS - Office of Pipeline Safety (DOT)

ORB - Oil Record Book

OSC - On-Scene Coordinator

OSHA - Occupational Safety and Health Administration (USDL)

OSLTF - Oil Spill Liability Trust Fund

OSPRA - Oil Spill Prevention and Response Act

OSRL - Oil Spill Response Limited

OSRO - Oil Spill Response Organization

OT - Oil Tight

OVA - Organic Vapor Analyzer

OWS - Oily Water Separator

PCB - Polychlorinated Biphenyls

PFD - Personal Flotation Device

PGR - Pager

PHMSA - Pipeline and Hazardous Materials Safety Administration

PIAT - Public Information Assist Team

POLREP - Pollution Report

PPE - Personal Protective Equipment

PPM - Parts Per Million

PSD - Prevention of Significant Deterioration

QDC - Quick Disconnect Coupling

QI - Qualified Individual

RACT - Reasonably Achievable Control Technology

RCP - Regional Contingency Plan

RCRA - Resource Conservation and Recovery Act

RECON - Reconnaissance

RQ - Reportable Quantity

RSPA - Research and Special Programs Administration (DOT - OPS)

SARA - Superfund Amendments and Reauthorization Act

SCBA - Self Contained Breathing Apparatus

SDWA - Safe Drinking Water Act

SERC - State Emergency Response Commission

SI - Surface Impoundment


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SIC - Standard Industrial Classification

SKIM - Spill Cleanup Equipment Inventory

SMT - Spill Management Team

SONS - Spill of National Significance

SOP - Standard Operating Procedure

SPCC - Spill Prevention Control and Countermeasures

SSC - Scientific Support Coordinator (NOAA)

STEL - Short Term Exposure Limits

SUPSALV - United States Navy Supervisor of Salvage

SWD - Salt Water Disposal

TLV - Threshold Limit Value

TSCA - Toxic Substances Control Act

TSDF - Treatment, Storage or Disposal Facility

UCS - Unified Command System

U.S. - United States

USACOE - U.S. Army Corps of Engineers

U.S.C. - United States Code

USCG - U.S. Coast Guard

USDA - U.S. Department of Agriculture

USDL - U.S. Department of Labor

USDOD - U.S. Department of Defense

USDOE - U.S. Department of Energy

USDW - Underground Source of Drinking Water

USFWS - U. S. Fish and Wildlife Services

USGS - U. S. Geological Survey

USPCI - United States Pollution Control, Incorporated

UST - Underground Storage Tank

WCD - Worst Case Discharge

WT - Water Tight


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15 REGULATORY CROSS REFERENCE

49 CFR 194

§ 194.105

BRIEF DESCRIPTION

LOCATION

(a) ... determine the worst case discharge ... provide methodology, including calculations, used to arrive at the volume.

App. A

(b) The worst case discharge is the largest volume, in barrels, of the following: -----

(b)(1) ... maximum release time in hours, plus the maximum shutdown response time in hours, multiplied by the maximum flow rate expressed in barrels per hour, plus the largest line drainage volume after shutdown of the line section(s) ...; or

App. A

(b)(2) The largest foreseeable discharge for the line section(s) within a response zone, expressed in barrels, based on the maximum historic discharge, if one exists, adjusted for any subsequent corrective or preventative action taken; or

N/A (App A)

(b)(3) If the response zone contains one or more breakout tanks, the capacity of the single largest tank or battery of tanks within a single secondary containment system, adjusted for the capacity or size of the secondary containment system, expressed in barrels.

N.A (App A)

(b)(4) Operators may claim prevention credits for breakout tank secondary containment and other specific spill prevention measures as follows:…

App A

§ 194.107

BRIEF DESCRIPTION

LOCATION

(a) Each response plan must plan for resources for responding, to the maximum extent practicable, to a worst case discharge, and to a substantial threat of such a discharge.

App A

(b) An operator must certify in the plan … reviewed NCP and each applicable ACP…

Foreword

(b)(1) As a minimum to be consistent with the NCP as a facility response plan must: -----

(b)(1)(i) Demonstrate an operator’s clear understanding of the function of the Federal response structure…

§ 4

(b)(1)(ii) Establish provisions to ensure the protection of safety at the response site; and

§ 5.2, ICS Forms § 5.0

(b)(1)(iii) Identify the procedures to obtain any required Federal and State permissions for using alternative response strategies such as in-situ burning and dispersants…

§ 6.8

(b)(2) As a minimum, to be consistent with the applicable ACP the plan must: -----

(b)(2)(i) Address the removal of a worst case discharge and the mitigation or prevention of a substantial threat of a worst case discharge;

§ 3.0, App E

(b)(2)(ii) Identify environmentally and economically sensitive areas; § 6.0

(b)(2)(iii) Describe the responsibilities of the operator and operator and of Federal, State and local agencies in removing a discharge and in mitigating or preventing a substantial threat of a discharge; and

§ 4.0

(b)(2)(iv) Establish the procedures for obtaining an expedited decision on use of dispersants or other chemicals.

§ 6.8

(c) Each response plan must include: ----

(c)(1) A core plan consisting of … ----

(c)(1)(i) An information summary as required in § 194.113, Fig 1.1

(c)(1)(ii) Immediate notification procedures, § 2.0

(c)(1)(iii) Spill detection and mitigation procedures, § 3.0


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(c)(1)(iv) The name, address, and telephone number of the oil spill response organization, if appropriate,

Fig. 1.1

(c)(1)(v) Response activities and response resources, § 3.0, App E

(c)(1)(vi) Names and telephone numbers of Federal, state, and local agencies which the operator expects to have pollution control responsibilities or support,

Fig 2.5

(c)(1)(vii) Training procedures, App. E

§ 194.107

BRIEF DESCRIPTION

LOCATION (c)(1)(viii) Equipment testing, App. B and E

(c)(1)(ix) Drill program – an operator will satisfy the requirement for a drill program by following the National Preparedness for Response Exercise Program (PREP) guidelines. An operator choosing not to follow PREP guidelines must have a drill program that is equivalent to PREP. The operator must describe the drill program in the response plan and OPS will determine if the program is equivalent to PREP.

App. B

(c)(1)(x) Plan review and update procedures; § 1.4

(c)(2) An appendix for each response zone that includes the information required in paragraph (c)(1)(i)-(ix) of this section and the worst case discharge calculations that are specific to that response zone. An operator submitting a response plan for a single response zone does not need to have a core plan and a response zone appendix. The operator of a single response zone onshore pipeline shall have a single summary in the plan that contains the required information in § 194.113.7; and.

N/A

(c)(3) A description of the operator’s response management system including the functional areas of finance, logistics, operations, planning, and command. The plan must demonstrate that the operator’s response management system uses common terminology and has a manageable span of control, a clearly defined chain of command, and sufficient trained personnel to fill each position.

§ 4.0

§ 194.111

BRIEF DESCRIPTION

LOCATION (a) Each operator shall maintain relevant portions of its response plan at the

operator’s headquarters and at other locations from which response activities may be conducted, for example, in field offices, supervisor’s vehicles, or spill response trailers.

Foreword Distribution List

§ 194.113

BRIEF DESCRIPTION

LOCATION

(a) The information summary for the core plan, required by § 194.107, must include:

----

(a)(1) The name and address of the operator. Fig 1.1

(a)(2) For each response zone which contains one or more line sections that meet the criteria for determining significant and substantial harm as described in § 194.103, a listing and description of the response zones, including county(s) and state(s).

Fig 1.1

(b) The information summary for the response zone appendix, required in § 194.107, must include:

----

(b)(1) The information summary for the core plan. Fig 1.1

(b)(2) The names or titles and 24-hour telephone numbers of the qualified individual(s) and at least one alternate qualified individual(s);

Fig 1.1

(b)(3) The description of the response zone, including county(s) and state(s), for those zones in which a worst case discharge could cause substantial harm to the environment.

Fig 1.1

(b)(4) A list of line sections for each pipeline contained in the response zone, identified by milepost or survey station number, or other operator designation.

Fig 1.1


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(b)(5) The basis for the operator's determination of significant and substantial harm. Fig 1.1

(b)(6) The type of oil and volume of the worst case discharge. Fig 1.1

§ 194.115

BRIEF DESCRIPTION

LOCATION

(a) Each operator shall identify and ensure, by contract or other approved means, the resources necessary to remove, to the maximum extent practicable, a worst case discharge and to mitigate or prevent a substantial threat of a worst case discharge.

App. E

(b) An operator shall identify in the response plan the response resources which are available to respond within the time specified, after discovery of a worst case discharge, or to mitigate the substantial threat of such a discharge.

App. E

§ 194.117

BRIEF DESCRIPTION

LOCATION (a) Each operator shall conduct training to ensure that: -----

(a)(1) All personnel know -- -----

(a)(1)(I) Their responsibilities under the response plan § 4.8

(a)(1)(ii) The name and address of, and the procedure for contacting, the operator on a 24-hour basis

§ 2.0, Fig 2.2

(a)(1)(iii) The name of, and procedures for contacting, the qualified individual on a 24- hour basis

Fig 1.1, Fig. 2.2, § 2.0,

(a)(2) Reporting personnel know -- -----

(a)(2)(I) The content of the information summary of the response plan. Fig 1.1

(a)(2)(ii) The toll-free telephone number of the National Response Center Fig 2.4, Fig. 2.5

(a)(2)(iii) The notification process § 2.0, Fig. 2.4

(a)(3) Personnel engaged in response activities know -- -----

(a)(3)(I) The characteristics and hazards of the oil discharged § 3.0

a)(3)(ii) The conditions that are likely to worsen emergencies, including the consequences of facility malfunctions or failures, and the appropriate corrective actions.

§ 3.0

(a)(3)(iii) The steps necessary to control any accidental discharge of oil and to minimize the potential for fire, explosion, toxicity, or environmental damage

§ 3.0

(a)(3)(iv) The proper firefighting procedures and use of equipment, fire suits, and breathing apparatus

§ 3.0

(b) Each operator shall maintain a training record for each individual that has been trained as required by this section. These records must be maintained in the following manner as long as the individual is assigned duties under the response plan

-----

(b)(1) Records for operator personnel must be maintained at the operator's headquarters

App. B

(b)(2) Records for personnel engaged in response, other than operator personnel, shall be maintained as determined by the operator.

App. B

(b)(3) Nothing in this section relieves an operator from the responsibility to ensure that all response personnel are trained to meet the OSHA standards for emergency response operations in 29 CFR 1910.120 ...

App. B


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§ 194.119

BRIEF DESCRIPTION

LOCATION

(a) Each owner shall submit two copies... Distribution

(b) ...PHMSA will notify the operator of any alleged deficiencies... -----

(c) The operator...may petition PHMSA for reconsideration within 30 days... -----

(d) ...PHMSA will approve the Response Plan... -----

(e) ...The operator may submit a certification to PHMSA...that the operator has obtained, through contract or other approved means, the necessary private personnel and equipment to record, to the maximum extent practicable, to a worst case discharge...

Foreword (Operator’s Statement)

(f) ...PHMSA may require an operator to provide a copy of the response plan to the OSC...

-----

California Code of Regulations

22 CCR §66264.52 and §66264.53

A Large Quantity Generator (LQG) must comply with the requirements of 22 CCR §66264.52

and §66264.53. Specifically, this part, titled “Contingency Plan and Emergency Procedures”,

requires that generators have a written contingency plan to minimize hazards to human health

or the environment from fires, explosions, or any unplanned sudden or non-sudden releases of

hazardous waste or hazardous waste constituents to air, soil, or surface water. The provisions

of the Plan must be carried out immediately whenever there is a fire, explosion, or release of

hazardous waste or hazardous waste constituents that could threaten human health or the

environment.

Contents of Contingency Plan

Regulatory Citation Regulatory Requirement Location 22 CCR §66264.52(a) A description of the actions that Facility personnel must

take to respond to hazards to human health or the environment from fires, explosions, or any unplanned sudden or non-sudden release of hazardous waste or hazardous waste constituents to the air, soil, or surface water.

Section 3.0 (all)

22 CCR §66264.52(b) If the owner or operator has already prepared a Spill Prevention, Control, and Countermeasure (SPCC) Plan in accordance with Title 40 CFR Part 112, or Part 1510, or some other emergency or contingency plan, the owner or operator need only amend that plan to incorporate hazardous waste management provisions that are sufficient to comply with the requirements of this chapter.

Appendix A Cross Reference


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22 CCR §66264.52(c) Arrangements agreed to by local police departments, fire departments, hospitals, contractors, and State and local emergency response teams to coordinate emergency services and to indicate whether State or local authorities decline to enter into such arrangements.

Foreword – Distribution List

(Arrangements Pending)

22 CCR §66264.52(d) A listing of names, addresses, and phone numbers (office and home) of all persons qualified to act as an emergency coordinator. The list must be kept up to date.

Section 1.0 – Figure 1.3 Section 2.0 – Figure 2.2

22 CCR §66264.52(e) A list of all emergency equipment at the Facility (such as fire extinguishing systems, spill control equipment, communications and alarm systems and decontamination equipment) where this equipment is required. The list must be kept up to date. The Contingency Plan must include the location and a physical description of each item on the list, and a brief outline of its capabilities.

Section 3.0 - §3.7.5 Appendix E – Evacuation Diagram

22 CCR §66264.52(f) An evacuation plan for Facility personnel where there is a possibility that evacuation could be necessary. The Plan must include signals to be used to begin evacuation, evacuation routes, and alternate evacuation routes.

Appendix D (all)

22 CCR §66264.52(g) The plan shall include the current telephone number of the State Office of Emergency Services.

Section 2.0 – Figure 2.5

22 CCR §66264.53(a) A copy of the contingency plan and all revisions to

the plan shall be:

-----

22 CCR

§66264.53(a)(1)

Maintained at the facility; and Foreword –

Distribution List

22 CCR

§66264.53(a)(2)

Submitted to all local police departments, fire

departments, hospitals, and State and local

emergency response teams that may be called upon

to provide emergency services

Foreword –

Distribution List

22 CCR §66264.53(b) The contingency plan shall be submitted to the

Department with Part B of the permit application under

Chapter 20, of this division and, after modification or

approval, will become a condition of any permit issued.

Submitted

independent of this

Plan


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CALIFORNIA CODE OF REGULATIONS CHAPTER 2, SUBCHAPTER 3,

CONTINGENCY PLANS FACILITY CONTINGENCY PLANS

817 Brief Description Location

817.02(a)(1)(A-E) Each Plan shall provide the following information;

(A) Name and address of marine facility, mailing address, name and address on title page of c-plan

(B) Name and address of owner operator of marine facility (C) Name, address and phone number to send

correspondence (D) Certification statement signed (E) COFRS

A) P.71 B) P.71 C) P.71 D) P.5 E) P.7

817.02(a)(2) QI and any alternates + relief process P.5, P.80

817.02(a)(3) Each plan shall provide the name, address, telephone number and facsimile number of an agent for service of process designated to receive legal documents on behalf of the plan holder. If the plan holder contracts for this service, documentation that the agent for service of process acknowledges this capacity shall be included in the plan. Such agent shall be located in California

P.71

817.02(a)(4) Each plan shall identify a Spill Management Team (as defined in Section 815.05(p) of this subchapter). If the plan holder contracts for this service, documentation that the Spill Management Team acknowledges this capacity shall be included in the plan.

P.66

817.02(a)(5) Each plan shall contain a copy of the contract or other approved means (as defined in Section 815.05(b) of this subchapter) verifying that any oil spill response organization(s) that are named in the plan will provide the requisite equipment and personnel in the event of an oil spill. This requirement can be met by a copy of the basic written agreement with an abstract of the recovery and/or clean-up capacities covered by the contract. Plan holders shall only contract with an OSRO(s) that has received a Rating by OSPR (as specified in Section 819 of this subchapter) for the booming, on-water recovery and storage, and shoreline protection services required.

P.209

817.02(b)(1) Each plan shall describe the marine facility's design and operations with specific attention to those areas from which an oil spill could occur. This description shall include, at a minimum, the following information:

P.72


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817.02(b)(1)(A) A piping and instrumentation diagram, and a tank diagram including the location of pumps, valves, vents and lines; the number, and oil storage capacity of each structure covered under the plan and its age, design, construction and general condition; the range of oil products normally stored in each structure; the presence or absence of containment structures and equipment; and the location of mooring areas, oil transfer locations, control stations, safety equipment, drip pans and the drainage for drip pans;

Pg.72-77

817.02(b)(1)(B) A description of the types, physical properties, health and safety hazards, maximum storage or handling capacity and current normal daily throughput of oil handled. A material safety data sheet (SDS) or equivalent will meet some of these requirements and can be maintained separately at the facility providing the plan identifies its location;

P.72-73, SDS on P.261

817.02(b)(1)(C) A description of the normal procedures for transferring oil from or to a pipeline, tanker, barge or other vessel, or storage tank, and the amount, frequency and duration of oil transfers;

P.72

817.02(b)(1)(D) Marine facility's normal hours of operation; and P.73

817.02(b)(1)(E) for an exploration or production facility, a complete description of those sections of the oil or gas lease field, gathering lines, storage tanks and processing facilities, under the control of the owner/operator, a spill from which could reasonably be expected to impact the marine waters of California.

N/A

817.02(b)(2) Each plan shall describe the marine facility site and surrounding area, including, where appropriate, the following information (note: where maps/diagrams are required they may be submitted on electronic media, in Portable Document Format (PDF)):

N/A

817.02(b)(2)(A) a map and description of site topography, including the drainage and diversion plans for the marine facility, such as sewers, storm drains, catchment, containment or diversion systems or basins, oil/water separators, and all watercourses into which surface runoff from the facility drains;

N/A

817.02(b)(2)(B) vicinity maps showing any vehicular or rail access to the marine facility, pipelines to and from the facility, nearby residential, commercial or other populous areas, and access to private land necessary to respond to a spill;

P. 78

Inserted Map Under P.78


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817.02(b)(2)(C) seasonal hydrographic and climatic conditions including wind speed and direction, air and water temperature, local tides, prevailing currents, and any local visibility problems;

P.74

817.02(b)(2)(D) physical geographic features, including ocean depths and local bathymetry; beach types and other geological conditions, including type of soil and terrain; operational conditions such as physical or navigation hazards, traffic patterns, permanent buoys, moorings and underwater structures or other site-specific factors; and any other physical feature or peculiarity of local waters that call for special precautionary measures that may affect spill response;

P.178

817.02(b)(2)(E) logistical resources within the geographic area covered by

the plan, including facilities for fire services, medical services, and accommodations for spill response personnel; and

P.89

817.02(b)(2)(F) shoreline access area, including piers, docks, boat launches and equipment and personnel staging areas. N/A

817.02(C) PREVENTIVE MEASURES P.74

817.02(C)(1) Each plan shall address prevention measures in order to reduce the possibility of an oil spill occurring as a result of the operation of the marine facility. The prevention measures must eliminate or mitigate all the hazards identified in the

Risk and Hazard Analysis.

P.176


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817.02(c)(1)(A) Each facility shall conduct a Risk and Hazard Analysis to identify the hazards associated with the operation of the facility, including: operator error, the use of the facility by various types of vessels, equipment failure, and external events likely to cause an oil spill.

The owner/operator may use one or more of the hazard evaluation methods identified by the American Institute of Chemical Engineers, or an equivalent method, including, but not limited to:

P.176

817.02(c)(1)(B) Plan must include information re-expertise of analyst; info appropriate to facility; O/O may found in violation analysis does not adequately;

P.176

817.02(c)(1)(B)(1) The plan must include information regarding the expertise of the working group that develops the analysis.

P.176

817.02(c)(1)(B)(2) The plan must include information that demonstrates to the Administrator that the analysis is appropriate to the marine facility and adequate according to the published procedures referenced in (B) above.

P.176

817.02(c)(1)(B)(3) An owner/operator may be found in violation of this section if the Risk and Hazard Analysis does not adequately address the risks posed by the marine facility.

P.176

817.02(c)(1)(B)(4) The Administrator may require that an analysis be updated if there are significant changes made to the marine facility. A significant change, as used in this paragraph, is one that would have an impact on the outcome of the Risk and Hazard Analysis.

P.176

817.02(c)(1)(B)(5) Additional information regarding the analysis method used or the working group that conducted the analysis shall be made available to the Administrator upon request.

P.176

817.02(c)(1)(C) Each plan shall include a summary of the results of the Risk and Hazard Analysis. The summary shall include the following: Each plan shall include a summary of the results of the Risk and Hazard Analysis. The summary shall include the following:

P.176


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817.02(c)(1)(C)(1) the hazard analysis method used, and a statement that the analysis is specific to the marine facility. If the analysis relies on a risk assessment at a similar facility, the summary shall specify how the two facilities are comparable;

P.176

817.02(c)(1)(C)(2) an inventory of the hazards identified, including the hazards that resulted in the historical spills;

P.206

817.02(c)(1)(C)(3) an analysis of the potential oil discharges, including the size, frequency, cause, duration and location of all significant spills from the marine facility as a result of each major type of hazard identified;

P.180

817.02(c)(1)(C)(4) the control measures that will be used to mitigate or eliminate the hazards identified. The plan shall include timeframes for implementing any control measures that cannot be functional immediately; and

P.180

817.02(c)(1)(C)(5) a prediction of the potential oil spills that might still be expected to occur after any mitigating controls have been implemented.

P.180

817.02(c)(2) Off-Site Consequence Analysis P.180

817.02(c)(2)(A) a trajectory, or series of trajectories (for pipelines, etc.), to determine the potential direction, rate of flow and time of travel of the reasonable worst case oil spill from the facility to marine waters and to the shorelines, including shallow-water environments, that may be impacted. For purposes of this requirement, a trajectory or trajectories (projected for a minimum of 72 hours) that determine the outer perimeter of a spill, based on regional extremes of climate, tides, currents and wind with consideration to seasonal differences, shall be sufficient;

P.180

817.02(c)(2)(B) for each probable shoreline that may be impacted, a discussion of the general toxicity effects and persistence of the discharge based on type of product; the effect of seasonal conditions on sensitivity of these areas; and an identification of which areas will be given priority attention if a spill occurs.

P.153

817.02(c)(3) Resources at Risk from Oil Spills

-----


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817.02(c)(3)(A) Based on the trajectory of the spilled oil as determined in the Off-Site Consequence Analysis, each plan shall identify the environmentally, economically and culturally sensitive sites that may be impacted. Each plan shall identify and provide a map of the locations of these areas. Some of the information required in this subsection may be drawn from the appropriate Area Contingency Plans, completed by the U.S. Coast Guard, State Agencies, and Local Governments pursuant to the Oil Pollution Act of 1990. (Note: where maps/diagrams are required they may be submitted on electronic media, in Portable Document Format (PDF)).

P.105

817.02(c)(3)(A) The map of environmentally sensitive sites shall include: P.180

817.02(c)(3)(A)(1) shoreline types and associated marine resources; p.164

817.02(c)(3)(A)(2) the presence of migratory and resident marine bird and mammal migration routes, and breeding, nursery, stopover, haul-out, and population concentration areas by season;

P.154-155

817.02(c)(3)(A)(3) the presence of aquatic resources including marine fish, invertebrates, and plants including important spawning, migratory, nursery and foraging areas;

P.154, P.180

817.02(c)(3)(A)(4) the presence of natural terrestrial animal and plant resources in marine-associated environments;

P.154, P.180

817.02(c)(3)(A)(5) the presence of state or federally-listed rare, threatened or endangered species;

P.154, P.180

817.02(c)(3)(A)(6) the presence of commercial and recreational fisheries including aquaculture sites, kelp leases and other harvest areas.

P.154, P.180

817.02(c)(3)(B) The map of the locations of economically and culturally sensitive sites shall include:

P.180

817.02(c)(3)(B)(1) public beaches, parks, marinas, boat ramps and diving areas;

P.180

817.02(c)(3)(B)(2) industrial and drinking water intakes, power plants, salt pond intakes, and other similarly situated underwater structures

P.180

817.02(c)(3)(B)(3) off-shore oil and gas leases and associated drilling/production platforms;

P.180

817.02(c)(3)(B)(4) known historical and archaeological sites. If a plan holder has access to any confidential archaeological information, it must be submitted as a separate item and will be handled as confidential information as outlined in Subsection 816.01(d);

P.180

817.02(c)(3)(B)(5) areas of cultural or economic significance to Native Americans; and

P.180


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817.02(c)(3)(B)(6) the major waterways and vessel traffic patterns that are likely to be impacted.

P.180

817.02(c)(4) Required Prevention Measures -------

817.02(c)(4)(A) Each marine facility shall take all prevention measures to reduce or mitigate the potential hazards identified in the Risk and Hazard Analysis, and the potential impact those hazards pose to the resources at risk. Each plan shall include the following:

P.176

817.02(c)(4)(A) schedules, methods and procedures for testing, maintaining and inspecting pipelines and other structures within or appurtenant to the marine facility that contain or handle oil which may impact marine waters if a failure occurs. Any information developed in compliance with Title 30 CFR, Part 250.153; Title 33 CFR, Part 154; Title 49 CFR, Part 195; and/or Title 5, Division 1, Part 1, Chapter 5.5, Sections 51010 through 51019.1 of the Government Code may be substituted for all or part of any comparable prevention measures required by this subsection.

P.75

817.02(c)(4)(B) methods to reduce spills during transfer and storage operations, including overfill prevention measures and immediate spill containment provisions. Any information developed in compliance with Title 2, CCR, Division 3, Chapter 1, Article 5, Sections 2300 through 2407; Title 30 CFR, Part 250.154; and/or Title 33 CFR, Parts 154 and 156 may be substituted for all or part of any comparable prevention measures required by this subsection.

N/A

817.02(c)(4)(C) procedures to assure clear communication among all the parties involved during transfer operations. Any information developed in compliance with Title 2, CCR, Division 3, Chapter 1, Article 5; Title 14, CCR, Division 1, Subdivision 4, Chapter 3, Subchapter 6; and/or Title 33 CFR, Parts 154 and 156 may be substituted for all or part of any comparable prevention measures required by this subsection;

N/A

817.02(c)(4)(D) protection measures for areas within the marine facility that are subject to flooding;

P.122

817.02(c)(4)(E) the plan holder shall provide additional relevant information to the Administrator upon request

P.68


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817.02(d) CONTAINMENT BOOMINGAND ON WATER RECOVERY ----

817.02(d)(1) Each plan holder must have a contract or other approved means for containment booming and on-water recovery response resources up to their Reasonable Worse Case Scenario Response Planning volume for all potential oil spills from the marine facility. To determine the amount of response resources for containment booming and on-water recovery, each plan holder must calculate a Response Planning Volume as outlined below:

P.184

817.02(d)(1) Reasonable Worst Case Spill P.184

To calculate the Response Planning Volume, it is first necessary to determine the reasonable worst case spill for each marine facility, as follows:

P.181-184

817.02(d)(1)(A) For marine facilities (except on-shore pipelines not subject to Chapter 6.67 (commencing with Section 25270) or Chapter 6.7 (commencing with Section 25280) of Division 20, Health and Safety Code) which are addressed in Subsection (B), offshore platforms which are addressed in Subsections (C) and (D), and offshore pipelines which are addressed in Subsection (E):

N/A

817.02(d)(1)(A)(1) the loss of the entire capacity of all in-line, break-out and portable storage tank(s), not subject to Chapter 6.67 (commencing with Section 25270) or Chapter 6.7 (commencing with Section 25280) of Division 20, Health and Safety Code, needed for the continuous operation of the pipelines used for the purposes of handling or transporting oil, taking into account the existence of volume limiting factors including, but not limited to, line pressure, gravity, and the availability and location of the emergency shut-off controls; plus

N/A

817.02(d)(1)(A)(2) the amount of additional spillage that could reasonably be expected to enter California marine waters during emergency shut-off, transfer or pumping operations if a hose(s) or pipeline(s) ruptures or becomes disconnected, or if some other incident occurs which could cause or increase the size of an oil spill. The spillage shall be calculated as follows: the maximum time to discover the release from the pipe or hose in hours, plus the maximum time to shut down flow from the pipe or hose in hours (based on historic discharge data or the best estimate in absence of historic discharge data for the marine facility) multiplied by the maximum flow rate expressed in barrels per hour (based on the maximum relief valve setting or maximum system pressure when relief valves are not provided) plus the total linefill drainage volume expressed in barrels.

N/A


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817.02(d)(1)(A)(3) The Administrator has the discretion to accept that a marine facility can operate only a limited number of the total pipelines at a time. In those circumstances, the reasonable worst case spill volume shall include the drainage volume from the piping normally not in use, in addition to the volume determined in (1) and (2), above.

N/A

817.02(d)(1)(B) For on-shore pipelines not subject to Chapter 6.67 (commencing with Section 25270) or Chapter 6.7 (commencing with Section 25280) of Division 20, Health and Safety Code, the largest volume in barrels, of the following:

-------

817.02(d)(1)(B)(1) The pipeline”s maximum release time in hours (i.e., the time between pipeline rupture and discovery), plus the maximum shut-down response time in hours (based on historic discharge data or in the absence of such historic data, the operator”s best estimate), multiplied by the maximum flow rate expressed in barrels per hour (based on the maximum daily capacity of the pipeline), plus the largest line drainage volume after shutdown of the line section(s) in the response zone expressed in barrels. (As used in this subsection: line section means a continuous run of pipe that is contained between adjacent pressure pump stations, between a pressure pump station and a terminal or break-out tank, between a pressures pump station and a block valve, or between adjacent block valves; response zone means a geographic area either along a length of pipeline or including multiple pipelines, containing one or more adjacent line sections, for which the operator must plan for the deployment of, and provide spill response capabilities. The size of the zone is determined by the operator after considering available capabilities, resources, and geographic characteristics); or

P.182

817.02(d)(1)(B)(2) The largest foreseeable discharge for the line section(s) within a response zone, expressed in barrels, based on the maximum historic discharge, if one exists, adjusted for any subsequent corrective or preventive action taken; or

P.182

817.02(d)(1)(B)(3) If the response zone contains one or more break-out tanks, the capacity of the single largest tank or battery of tanks within a single secondary containment system, adjusted for the capacity or size of the secondary containment system, expressed in barrels.

N/A

817.02(d)(1)(C) For offshore platforms (except those drilling a new well which are addressed in Subsection (D)): N/A

817.02(d)(1)(C)(1) total tank storage and flow line capacity; plus N/A


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817.02(d)(1)(C)(2) that portion of the total linefill capacity which could be lost during a spill, taking into account the availability and location of the emergency shut-off controls and the effect of hydrostatic pressure; plus N/A

817.02(d)(1)(C)(3) the amount of additional spillage that could reasonably be expected to enter marine waters during emergency shut-off, transfer or pumping operations if a hose or pipeline ruptures or becomes disconnected, or some other incident occurs which could cause or increase the size of an oil spill. The calculation may take into consideration other safety devices, emergency reaction times and maximum transfer rates; plus

N/A

817.02(d)(1)(C)(4) the daily production volume for seven days from an uncontrolled blowout of the highest capacity well associated with the marine facility. In determining the daily discharge rate, the reservoir characteristics, casing/production tubing sizes, and historical production and reservoir pressure data shall be taken into consideration.

N/A

817.02(d)(1)(D) For offshore platforms with active well drilling: ------

The owner/operator of a platform at which a new well is being drilled must submit a proposed reasonable worst case oil spill calculation for platform operations to the Administrator. The proposed worst case discharge is the daily volume possible for seven days from an uncontrolled blowout taking into consideration any known reservoir characteristics. The proposed calculation will be reviewed by the Administrator during the plan review and approval process to determine if it adequately addresses the oil spill potential of the new well system.

N/A

817.02(d)(1)(E) For offshore pipelines, the largest volume in barrels of the following calculation:

-------

817.02(d)(1)(E)(1) The pipeline system leak detection time, plus the shutdown response time, multiplied by the highest measured oil flow rate over the preceding 12-month period. For new pipelines, use the predicted oil flow rate. Add to this calculation the total volume of oil that would leak from the pipeline after it is shut in. This volume should be calculated by taking into account the effects of hydrostatic pressure, gravity, frictional wall forces, length of pipeline segment, tie-ins with other pipelines, and other factors.

N/A


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817.02(d)(1)(F) The calculations, and such parameters as flow rates, linefill capacities and emergency shutoff times, that are used to determine a marine facility's reasonable worst case spill shall be submitted as part of the plan. The Administrator may review and test these parameters as part of the drill conducted in accordance with Subsection 816.03(b).

N/A

817.02(d)(2) Persistence and Emulsification Factors

N/A

817.02(d)(2)(A) The reasonable worst case spill volume is then multiplied by a persistence factor relative to the most persistent type of oil that may be spilled by the marine facility. The persistence factors relative to the type of oil spilled, are specified below:

P.184

817.02(d)(2)(B) Emulsification Factors P.184

The volume determined from the calculation in Subparagraph (A) is then multiplied by one of the following emulsification factors, again, based on the type of oil.

P.184

817.02(d)(2)(C) Response Planning Volume -------

817.02(d)(2)(C)(1) The Response Planning Volume to be used to determine the amount of Response Equipment and Services that must be under contract or other approved means shall be the greater of the amount determined in Subsection 817.02(d)(1) and (2), or the Planning Volume for On-water Recovery calculated for the nearshore/inland environment in the marine facility's federal response plan pursuant to 33 CFR Part 154, Appendix C, Section 7. The Planning Volume for On-Water Recovery is the adjusted volume from the federal calculation determined prior to establishing the response tiers utilizing the mobilization factors.

P.184

817.02(d)(2)(C)(2) All calculations used to determine the Response Planning Volume shall be included in the plan.

P.184

817.02(d)(3) Response Capability Standards

--------


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The equipment and personnel necessary to address the Response Planning Volume is brought to the scene of the spill over a period of time. The timeframes are dependent upon the risk zone in which the marine facility is located and are specified in the tables in this section.

The standards set forth in this section are only planning standards and may not reflect the exigencies of actual spill response. However, these are the standards that must be used to determine the amount of equipment and personnel that must be under contract or other approved means. Response resources in addition to those under contract must be identified, and a call-out procedure in place to access this equipment, if the marine facility has a spill that exceeds the Response Planning Volumes. The owner/operator is ultimately responsible for addressing the entire volume of an actual spill regardless of the planning volume.

P.184 P.208

817.02(d)(3)(A) On-Water Daily Recovery Rates and Containment Boom Amounts

P.208

817.02(d)(3)(A)(1) The total amount of on-water recovery equipment and services required shall be the lesser of the amount necessary to address the Response Planning Volume determined in Section 817.02(d)(2)(C) or the Daily Recovery Rate established by this Section at 817.02(d)(3)(B) below.

P.208

817.02(d)(3)(A)(2) The amount of response resources and the timeframes for delivery are specified in Subsection 817.02(d)(3)(B) below. The barrels per day capability figure is the total amount of on- water recovery equipment that must be at the scene of the spill at the hour specified which is measured from the time of notification, as described in this subchapter. All on-water recovery response resources shall be capable of being deployed and operable within one hour of arrival at the scene of the spill or drill but no later than the designated timeframe for each risk zone.

P.208

817.02(d)(3)(A)(3) The timeframes for equipment delivery and deployment as specified in this subsection do not take into account the time required to conduct a health and safety assessment of the site as set forth in Subsection 817.02(f)(8), and as required by the California Occupational and Safety Administration. In addition, these timeframes do not account for delays that may occur due to weather or seastate. The actual time necessary to deliver and deploy equipment will be assessed at the time of an incident or a drill and will take into account the prevailing conditions of weather and seastate, as well as the site assessment requirements.

P.208


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817.02(d)(3)(B) Daily Recovery Rate P.184

817.02(d)(3)(B)(1) Facilities located in High-Volume Ports --------

817.02(d)(3)(B)(1)(i) in addition, the facility/transfer points within the High Volume Ports must have 3,125 barrels/day, or 10% of the reasonable worst case spill volume, whichever is less, of on-water recovery capability that can be mobilized and on-scene within two hours of notification;

N/A

817.02(d)(3)(B)(1)(ii) if a facility/transfer point within a High Volume Port maintains and can immediately deploy containment equipment for a 3,125 barrel spill, or 10% of the reasonable worst case spill volume, whichever is less, the initial on-water recovery capability can be on-scene within three hours rather than two hours.

N/A

817.02(d)(3)(B)(2) Facility/Transfer Areas and the Santa Barbara Channel Area N/A

817.02(d)(3)(B)(2)(i) in addition, facility/transfer points within a Facility/Transfer Area and the Santa Barbara Channel Area must have 3,125 barrels/day, or 10% of the reasonable worst case spill volume, whichever is less, of on-water recovery capability that can be mobilized and on-scene within two hours of notification;

N/A

817.02(d)(3)(B)(2)(ii) if a facility/transfer point within a Facility/Transfer Area or the Santa Barbara Channel Area maintains and can immediately deploy containment equipment for a 3,125 barrel spill, or 10% of the reasonable worst case spill volume, whichever is less, the initial on-water recovery capability can be on-scene within three hours rather than two hours;

N/A

817.02(d)(3)(B)(2)(iii) for those points where transfers occur infrequently, and where there is not permanent equipment present, the 3,125 barrel/day, or 10% of the reasonable worst case spill volume, whichever is less, on-water recovery capability shall be brought to the site at the time of transfer;

N/A

817.02(d)(3)(B)(2)(iv) for infrequent transfers of non-persistent oil, the initial response requirement may be waived by application to the Administrator. The application for waiver must include a justification based on such factors as the location of the marine facility, proximity to response equipment, additional equipment in the immediate area, and the relative environmental sensitivity of the potential spill sites.

N/A


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817.02(d)(3)(C) Sufficient containment equipment shall be brought to the scene of the spill to address the daily recovery rates as designated in Section 817.02(d)(3)(B).

P.208

817.02(d)(3)(D) The standards set forth in Subsection 817.02(d)(3)(B) were increased by a factor of 25% on July 1, 1997, and again on July 1, 2001. It was determined that this increase was feasible and necessary to meet the best achievable protection of the coast.

P.208

817.02(d)(3)(E) The standards set forth in Subsection 817.02(d)(3)(B) will be reviewed by the Administrator to determine if increases to these amounts are feasible and necessary in order to meet the best achievable protection of the coast. The Administrator shall conduct a review and hold a public hearing prior to confirming the new standards to solicit input regarding the necessity of the proposed increase and any credits that may be allowed.

P.208

817.02(d)(4) Movement of Response Resources §5, Appendix C

817.02(d)(4)(A) There may be times when it is necessary to move response equipment from one risk zone to another in order to respond to a catastrophic oil spill. However, the Administrator needs to ensure that sufficient response resources are available to address a reasonable risk within each zone. Therefore, when equipment is needed from one risk zone which may impact the plan holder’s on-water containment and recovery at the 6 hour level, the plan holder or OSRO shall make a request to the Administrator to temporarily reduce the Response Capability Standards set forth in (d)(3) above, before the equipment can be moved. The Administrator shall only grant such a request after determining that sufficient response resources are available to address a reasonable risk within the zone from where the response equipment is being considered for removal.

P.142

817.02(d)(5) On-Water Response Equipment and Services P.208

817.02(d)(5)(A) Each plan shall demonstrate that the marine facility owner/operator has under contract or other approved means (as defined in Section 815.05(b) of this subchapter), access to all the necessary response resources to comply with the Response Capability Standards established in Subsection 817.02(d)(3). The amount of response equipment required shall take into account the effective daily recovery capacity (EDRC, as defined in Chapter 1, Section 790 of this subdivision) of the equipment.

P.208


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817.02(d)(5)(B) The equipment identified for a specific area must be appropriate for use in that area given the limitations of the geography, bathymetry, water depths, tides, currents and other local environmental conditions. For those areas that require shallow-water response capability (refer to the relevant Area Contingency Plan), the plan shall provide for an adequate number of shallow-draft vessels (as defined in Section 815.05 of this subchapter) and for adequate booming and other shoreline protective resources to be owned or under contract or other approved means and available to provide shoreline protection of all sensitive sites identified in the trajectory analysis conducted as part of the Off-site Consequence Analysis. Additionally, the equipment identified shall also be appropriate for use on the type of oil identified. To the extent that the following information is provided by a Rated OSRO, evidence of a contract or other approved means with a Rated OSRO will suffice:

P.208

817.02(d)(5)(B)(1) the location, inventory and ownership of the equipment to be used to fulfill the response requirements of this subchapter;

P.208

817.02(d)(5)(B)(2) a complete inventory of any nonmechanical response equipment and supplies, including the type and toxicity of each chemical agent, with procedures for storage and maintenance;

P.208

817.02(d)(5)(B)(3) the type and capacity of storage and transfer equipment matched to the skimming capacity of the recovery systems;

P.208

817.02(d)(5)(B)(4) the manufacturer's rated capacities and the operational characteristics for each major item of oil recovery equipment;

P.208

817.02(d)(5)(B)(5) the effective daily recovery capacity (as defined in Chapter 1, Section 790 of this subdivision) for each major piece of on- water recovery equipment listed, as well as the effective daily recovery capacity for the skimming systems as a whole.

P.208

817.02(d)(5)(B)(5)(i) A request may be submitted to the Administrator to review the effective daily recovery capacity for a piece of equipment if it can be shown that the equipment has a different capacity than the derating factor allows.

P.208

817.02(d)(5)(B)(5)(ii) The Administrator's decision regarding a change in the effective daily recovery capacity for a piece of equipment will be issued as soon as administratively feasible.

P.208

817.02(d)(5)(B)(6) vessels designated for oil recovery operations, including skimmer vessels and vessels designed to tow and deploy boom, and availability of shallow-draft vessels; P.208


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817.02(d)(5)(B)(7) vessels of opportunity reasonably available for oil spill recovery operations, including availability of shallow-draft vessels, procedures to equip the vessels, inventory all equipment, and train personnel;

P.208

817.02(d)(5)(B)(8) procedures for storage, maintenance, inspection and testing of spill response equipment under the immediate control of the operator;

P.208

817.02(d)(5)(B)(9) sufficient equipment to track the movement of discharged oil, including aerial surveillance sufficient to direct skimming operations,.

P.208

817.02(d)(5)(B)(10) Each plan shall describe the personnel available to respond to an oil spill, including: P.141

817.02(d)(5)(B)(10)(i) a list by job category including a job description for each type of spill response position needed as indicated in the spill response organization scheme;

P.146-151

817.02(d)(5)(B)(10)(ii) a match between personnel by job category, and the equipment proposed for use (including equipment appropriate for shallow-water environments), including the plan for mobilization of such personnel;

P.146-151

817.02(d)(5)(B)(10)(iii) sufficient personnel to maintain a response effort of at least 14 days. P.146

817.02(d)(5)(B)(11) Each plan shall describe procedures for the transport of required equipment, personnel and other resources to the spill site. The description shall include plans for alternative procedures during adverse environmental conditions. Adverse environmental conditions to be considered shall include:

P.127

817.02(d)(5)(B)(11)(i) adverse weather; P.75, P.118

817.02(d)(5)(B)(11)(ii) sea states, tides, winds and currents; P.75, P.157

817.02(d)(5)(B)(11)(iii) presence of debris or other obstacles; and P.105, P.164-180

817.02(d)(5)(B)(11)(iv) any other known environmental conditions that could restrict response efforts.

P.154, P.155, P.180

817.02(d)(5)(C) A list of the marine facility's spill management personnel (and company name if applicable) and their spill response qualifications including a discussion of spill response training and experience, regulatory awareness and compliance, and supervision.

P.66


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817.02(d)(5)(D) Any equipment and personnel identified in the plan must be available for response. Any necessary maintenance for the equipment, vacation periods for response personnel, or other eventuality must be taken into account in relying upon these resources.

P.208

817.02(d)(5)(D)(1) The equipment owner must notify the Administrator when major equipment is removed from service for a period of 24 hours or more for maintenance or repair. Major equipment is that which, if removed, would affect timely implementation of the plan. Notification must be made prior to removing equipment for regularly scheduled maintenance, and within 24 hours of removing equipment for unscheduled repairs.

P.208

817.02(d)(5)(D)(2) The equipment owner must demonstrate that backup equipment is available during the time that the primary response equipment is out of service. Backup equipment may be provided from the owner's own inventory, or may be made available from another responder.

P.208

817.02(d)(5)(D)(3) A plan shall remain valid during the time that equipment has been removed from service for maintenance or repair.

P.208

817.02(d)(5)(E) Group 5 Oils --------

Marine facilities that handle Group 5 oils must contract with one or more Rated OSRO(s) to address the marine facility's Response Planning Volume. Such equipment shall include, but is not limited to the following:

N/A

817.02(d)(5)(E)(1) sonar, sampling equipment, or other methods for locating the oil on the bottom or suspended in the water column;

N/A

817.02(d)(5)(E)(2) containment boom, sorbent boom, silt curtains, or other methods to reduce spreading on the bottom; N/A

817.02(d)(5)(E)(3) dredges, pumps, or other equipment necessary to recover oil from the bottom; N/A

817.02(d)(5)(E)(4) equipment necessary to assess the impact of such discharges; and

N/A

817.02(d)(5)(E)(5) any other appropriate equipment necessary to respond to a discharge involving a Group 5 oil.

N/A


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817.02(d)(5)(F) The plan holder may propose the use of non-mechanical methods for response operations which may include dispersants, in-situ burning, coagulants, bioremediants, or other chemical agents. The use of any non-mechanical method for response must be done in accordance with provisions of the California Oil Spill Contingency Plan, the National Contingency Plan, the applicable federal Area Contingency Plan and all applicable State laws and regulations. If a non-mechanical method of response is proposed, the plan shall include:

N/A

817.02(d)(5)(F)(1) methods of deployment or application; N/A

817.02(d)(5)(F)(2) for use of a chemical agent, a description of the specific mechanisms in place to assess the environmental consequences of the chemical agent. This shall include the mechanism for continuous monitoring of environmental effects for the first three days after initial application, and periodic monitoring thereafter until the agent is inert or no longer operative;

N/A

817.02(d)(5)(F)(3) identification of all permits, approvals or authorizations needed to allow the use of chemical agents or non- mechanical methods, and the timeline for obtaining them;

N/A

817.02(d)(5)(F)(4) a plan for protecting resources at risk, areas of public concern and the public from any adverse effects of the non- mechanical method used;

N/A

817.02(d)(5)(F)(5) the projected efficacy of each type of non-mechanical method proposed for use taking into account the type of spilled material and the projected environmental conditions of the potential spill site; and

N/A

817.02(d)(5)(F)(6) upon request, the plan holder shall provide any test results known to the plan holder which assess the environmental impacts of applying these methods in the marine environment.

N/A

817.02(d)(5)(G) The plan shall describe methods for tracking the movement of the discharged oil; and N/A

817.02(d)(5)(H) The plan shall list the location of the weather stations to be used for observations of winds, currents and other data at the time of a spill that may assist in making real-time projections of spill movement.

P.75

817.02(e) Shoreline Protection Each plan must provide for shoreline protection of all potential spills from the marine facility.

P.160 - 174

817.02(e)(1) Shoreline Response Planning Volume P.184


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817.02(e)(1) Each plan shall demonstrate that the marine facility has access to all necessary equipment and services to address the response strategies appropriate to each shoreline that could potentially be impacted by a spill from the facility.

P.208

817.02(e)(1)(A) To determine the amount of equipment and services necessary a Response Planning Volume must be calculated as outlined below: Multiply the reasonable worst case spill for the marine facility, as calculated in Subsection 817.02(d)(1), by the appropriate persistence factor from the chart below for the most persistent type of oil that may be spilled:

P.184

817.02(e)(1)(B) Emulsification Factors P.184

The volume determined from the calculation above is then multiplied by one of the following emulsification factors, again, based on the type of oil:

P.184

817.02(e)(1)(C) Total Shoreline Equipment Required P.208

The total determined by this calculation is a Response Planning Volume. P.184

817.02(e)(1)(C)(1) The Response Planning Volume to be used to determine the amount of Response Equipment and Services that must be under contract shall be the greater of the amount determined in Subsection 817.02(e)(1), or the adjusted Planning Volume for onshore recovery calculated for the nearshore/inland environment in the facility's federal response plan pursuant to 33 CFR Part 154., Appendix C, Section 7.

P.184

817.02(e)(1)(C)(2) All calculations used to determine the Response Planning Volume shall be included in the plan.

P.184

817.02(e)(2) Shoreline Protection Equipment and Services

P.208


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Each plan must identify, and ensure availability through a contract or other approved means (as defined in Section 815.05(b) of this subchapter), the capability of effecting shoreline protection strategies. Such protection strategies must be commensurate with the Response Planning Volume calculated for potential shoreline impact, and must be capable of addressing all appropriate protection, and response strategies. The specific areas where equipment and services must be available for use shall be identified in the Off-Site Consequence Analysis.

P.208

817.02(e)(2)(A) The equipment identified for a specific area must be appropriate for use in that area given the limitations of the bathymetry, geomorphology, shoreline types and other local environmental conditions. Additionally, the equipment identified shall be appropriate for use on the type of oil identified. To the extent that the following information is provided by a Rated OSRO, evidence of a contract or other approved means with a Rated OSRO will suffice:

P.208

817.02(e)(2)(A)(1) the amounts of all protective booming, shallow-draft vessels, and shoreline protection equipment necessary to address the specific types of shorelines that may be impacted;

P.208

817.02(e)(2)(A)(2) the location, inventory and ownership of the equipment to be used to fulfill the response requirements; P.209

817.02(e)(2)(A)(3) the procedures for storage, maintenance, inspection and testing of spill response equipment under the immediate control of the operator.

P.208

817.02(e)(2)(B) Each plan shall have under contract or other approved means sufficient trained personnel to respond to all oil spills up to the calculated Response Planning Volume, which are to remain on scene until demobilized by the State Incident Command or the Unified Command. For planning purposes, this shall include procedures to obtain sufficient personnel to maintain a response effort of at least 14 days.

P.209

817.02(e)(2)(C) Any equipment and personnel identified to meet the planning standard requirements must be available for response. Any necessary maintenance for the equipment, vacation periods for response personnel, or other eventuality must be taken into account in relying upon these resources.

P.209


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817.02(e)(2)(C)(1) The equipment owner must notify the Administrator when major equipment is removed from service for a period of 24 hours or more for maintenance or repair. Major equipment is that which, if moved, would affect timely implementation of the plan. Notification must be made prior to removing equipment for regularly scheduled maintenance, and within 24 hours of removing equipment for unscheduled repairs.

P.209

817.02(e)(2)(C)(2) The equipment owner must demonstrate that backup equipment is available during the time that the primary response equipment is out of service. Backup equipment may be provided from the owner’s own inventory or may be made available from another responder.

P.208

817.02(e)(2)(C)(3) A plan shall remain valid during the time that equipment has been removed from service for maintenance or repair if the Administrator has not disapproved such removal within 24 hours of notification.

P.208

817.02(e)(2)(C)(4) The equipment owner shall notify the Administrator when the major equipment is back in service. P.209

817.02(e)(3) Reserved --------

817.02(e)(4) Shoreline Clean-up --------

817.02(e)(4)(A) Utilizing the equipment that must be under contract, each plan shall describe the methods that will be used to contain spilled oil and remove it from the environment. The equipment identified for a specific area must be appropriate for use in that area given the limitations of the bathymetry, geomorphology, shoreline types and other local environmental conditions. Additionally, the equipment identified shall be appropriate for use on the type of oil identified. The description shall include:

Section 6, P.208-209

817.02(e)(4)(A)(1) all shoreline clean up procedures and oil diversion and pooling procedures for the close-to-shore environment. These procedures shall include, where appropriate, methods for carrying out response operations and clean-up strategies in shallow-water environments, as identified in the trajectory analysis conducted as part of the Off-site Consequence Analysis;

P.164-174

817.02(e)(4)(A)(2) methods for shore side clean-up, including containment and removal of surface oil, subsurface oil and oiled debris and vegetation from all applicable shorelines, adjacent land and beach types.

P.157


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817.02(e)(4)(A)(3) measures to be taken to minimize damage to the environment from land operations during a spill response, such as impacts to sensitive shoreline habitat caused by heavy machinery or foot traffic.

P.157-174

817.02(e)(4)(B) Protection, response and clean-up strategies will be specific to the type of oil spilled, the expected spill sites as identified in the Off-Site Consequence Analysis, and the resources at risk at those spill sites.

P.156-174

817.02(e)(4)(C) Each plan must utilize all the strategies appropriate to the potential impact sites. P.156-174

817.02(e)(4)(D) Each plan shall have under contract or other approved means sufficient trained personnel to respond to all oil spills up to the Response Planning Volume, which are to remain on scene until demobilized by the State Incident Command or the Unified Command.

P.155

817.02(f) RESPONSE PROCEDURES -------

817.02(f)(1) Spill Response System and Management Team Organization Section 4 (P.140)

Each plan shall describe the organization of the marine facility's spill response system and management team. An organizational diagram depicting the chain of command shall also be included. Additionally, the plan shall describe the method to be used to interface the plan holder's organization into the State Incident Command System and/or the Unified Command Structure as required by Title 8, California Code of Regulations, Subsection 5192 (q)(3)(A).

P.140-151

817.02(f)(1)(A) The plan holder may utilize the procedures outlined in the appropriate Area Contingency Plan when describing how the marine facility's chain of command will interface with the State Incident Command System which utilizes the Unified Command.

P.180

817.02(f)(1)(B) Each plan shall describe the organization of the plan holder’s public information office, as it relates to an oil spill incident, and the method by which the Information Officer will be integrated into the State Incident Command System.

P.148-151


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817.02(f)(1)(C) Each plan shall describe the plan holder’s safety program as it relates to an oil spill incident and the method by which their Safety Officer will be integrated into the State Incident Command System.

P.148-151

817.02(f)(2) Each plan shall identify potential sites needed for spill response operations including location(s) for: ------

817.02(f)(2)(A) a central command post sufficient to accommodate the State Incident Command or Unified Command as well as the plan holder’s response organization;

P.126-127

817.02(f)(2)(B) a central communications post if located away from the command post; P.126-128

817.02(f)(2)(C) equipment and personnel staging areas. P.126-128

817.02(f)(3) Each plan shall include a checklist, flowchart or decision tree depicting the procession of each major stage of spill response operations from spill discovery to completion of clean up. The checklist, flowchart or decision tree shall describe the general order and priority in which key spill response activities are performed.

P.98

817.02(f)(4) Each plan shall describe how the plan holder will provide emergency services before the arrival of local, state or federal authorities on the scene, including:

P.101

817.02(f)(4)(A) procedures to control fires and explosions, and to rescue people or property threatened by fire or explosion;

P.107

817.02(f)(4)(B) procedures for emergency medical treatment and first aid; P.137

817.02(f)(4)(C) procedures to control ground, marine and air traffic which may interfere with spill response operations;

P.123

817.02(f)(4)(D) procedures to manage access to the spill response site and the designation of exclusion, decontamination and safe zones; and

P.136

817.02(f)(4)(E) procedures to provide the required personnel protective gear for responders.

P.137

817.02(f)(5) Each plan shall describe equipment and procedures to be used by marine facility personnel to minimize the magnitude of a spill and minimize structural damage which may increase the quantity of oil spilled.

P.128


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817.02(f)(5)(A) Spill mitigation procedures shall include immediate containment strategies, methods to stop the spill at the source, methods to slow or stop leaks, and methods to achieve immediate emergency shutdown.

P.128

817.02(f)(5)(B) For spill mitigation procedures the plan shall include prioritized procedures for marine facility personnel including specific procedures to shut down affected operations. Responsibilities of facility personnel should be identified by job title. A copy of these procedures should be maintained at the facility operations center. These procedures should address the following equipment and scenarios:

P.104

817.02(f)(5)(B)(1) failure of manifold and mechanical loading arm, other transfer equipment, or hoses, as appropriate;

P.102

817.02(f)(5)(B)(2) tank overfill; N/A

817.02(f)(5)(B)(3) tank failure; N/A

817.02(f)(5)(B)(4) pipe rupture; P.102

817.02(f)(5)(B)(5) pipe leak, both under pressure and not under pressure, if applicable;

P.102

817.02(f)(5)(B)(6) explosion and/or fire; and P.107

817.02(f)(5)(B)(7) other equipment failure (e.g. pumping system failure, relief valve failure, etc.).

P.102

817.02(f)(6) Each plan shall detail the lines of communications between the responsible party, the Qualified Individual and the on- scene coordinators, response teams, and local, state, and federal emergency and disaster responders, including:

P.146-152

817.02(f)(6)(A) communication procedures; P.126

817.02(f)(6)(B) the communication function (e.g., ground-to-air) assigned to each channel or frequency used;

P.123

817.02(f)(6)(C) the maximum broadcast range for each channel or frequency used; and

P.126

817.02(f)(6)(D) redundant and back-up systems. P.126

817.02(f)(7) Each plan shall describe the procedures to manage access to the spill response site, the designation of exclusion, decontamination and safe zones, and the decontamination of equipment and personnel during and after oil spill response operations, as required by the California Occupational Safety and Health Administration.

P.132-137


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817.02(f)(8) Prior to beginning spill response operations and/or cleanup activities, a Site Safety Plan must be completed. Each site safety plan shall include information as required pursuant to Title 8, Section 5192(b)(4)(B) of the California Code of Regulations including, but not limited to, a written respiratory protection program, written personal protective equipment program, written health and safety training program, written confined space program and permit forms, direct reading instrument calibration logs, and written exposure monitoring program.

P.133, P.153

817.02(f)(9) Site Safety Plan completed prior to response. P.153

817.02(g) NOTIFICATION PROCEDURES P.79

817.02(g)(1) Each plan shall include a list of contacts to call in the event of a drill, threatened discharge of oil, or discharge of oil. The plan shall:.

P.84-91

817.02(g)(1)(A) detail the procedures for reporting oil spills to all appropriate local, state, and federal agencies;

P.84-91

817.02(g)(1)(B) identify a central reporting office or individual who is responsible for initiating the notification process and is available on a 24-hour basis. The individual making this notification must be fluent in English. The following information must be provided:

P.79

817.02(g)(1)(B)(1) the individual or office to be contacted; P.80

817.02(g)(1)(B)(2) telephone number or other means of contact for any time of the day; and

P.80

817.02(g)(1)(B)(3) an alternate contact in the event the individual is unavailable. P.80

817.02(g)(1)(C) establish a clear order of priority for notification P.80

817.02(g)(2) Immediate notification P.81

Nothing in this section shall be construed as requiring notification before response.

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817.02(g)(2)(A) Each plan shall include a procedure for contacting the OSRO, or other initial response resources if an OSRO is not being used, immediately, but no longer than 30 minutes, after discovery of a discharge of oil or threatened discharge of oil.

P.81

817.02(g)(2)(B) Each plan shall include a procedure that ensures that the owner/operator or his/her designee will initiate contact with the Qualified Individual, the California Emergency Management Agency and the National Response Center immediately, but no longer than 30 minutes, after discovery of a discharge of oil or threatened discharge of oil.

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817.02(g)(2)(C) All phone numbers necessary to complete the immediate notification procedures must be included in the response manual.

P.81

817.02(g)(3) Each plan shall identify a call-out procedure to acquire the resources necessary to address spills that cannot be addressed by the equipment that the owner/operator is required to have under contract. Procedures must allow for initiation of the call-out within 24 hours of the incident and must begin as soon as a determination has been made that additional resources are necessary.

P.81

817.02(g)(4) Each plan shall provide a checklist of the information to be reported in the notification procedures, including but not limited to:

P.81

817.02(g)(4)(A) marine facility name and location; P.81

817.02(g)(4)(B) date and time of the incident; P.81

817.02(g)(4)(C) the cause and location of the spill; P.81

817.02(g)(4)(D) an estimate of the volume of oil spilled and the volume at immediate risk of spillage;

P.81

817.02(g)(4)(E) the type of oil spilled, and any inhalation hazards or explosive vapor hazards, if known;

P.81

817.02(g)(4)(F) the size and appearance of the slick; P.81

817.02(g)(4)(G) prevailing weather and sea conditions; P.81

817.02(g)(4)(H) actions taken or planned by personnel on scene; P.81

817.02(g)(4)(I) current condition of the marine facility; P.81

817.02(g)(4)(J) injuries and fatalities; and P.81

817.02(g)(4)(K) any other information as appropriate. P.81

817.02(g)(5) Reporting of a spill as required by Subsection 817.02(g)(2) shall not be delayed solely to gather all the information required by Subsection 817.02(g)(4).

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817.02(g)(6) An updated estimate of the volume of oil spilled and the volume at immediate risk of spillage shall be reported to the California Emergency Management Agency whenever a significant change in the amount reported occurs, but not less than every 12 hours within the first 48 hours of response. The State Incident Commander and/or the Federal On-Scene Coordinator through the Unified Command shall have the option of increasing or decreasing this timeframe, as needed. Updated spill volume information included in the Incident Action Plan developed through the Unified Command will meet the requirements of this subsection

P.81

817.02(h) TEMPORARY STORAGE AND WASTE MANAGEMENT P.132

817.02(h)(1) Identify sufficient temporary storage that is not less than 2 times the required daily recovery rate.

P.132

817.02(h)(1)(A) To meet the temporary storage requirement described in Subsection (1) above, the following amounts of storage shall be dedicated response resources (as defined in Section 815.05(c) of this subchapter) or OSRO-owned and controlled response resources (as defined in Section 815.05(k) of this subchapter), as applicable to the appropriate risk zone: Sufficient storage to support the skimming systems shall be brought to the scene of the spill during the first four hours of response: 520 barrels of storage, or 20% of the response planning volume, whichever is less, shall be brought to the scene of the spill within four hours of notification of a spill;

P.132

817.02(h)(1)(A) 12,000 barrels, or two times the response planning volume, whichever is less, shall be available at the scene of the spill within 6 hours of notification of a spill. The balance of the temporary storage requirement described in Subsection (1) above may be provided by non-dedicated storage resources. All skimming systems operating at the scene of a spill shall have adequate storage

P.132

817.02(h)(2) Each plan shall identify the party that shall maintain responsibility for recovered oil and oily waste for the purposes of temporary storage.

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817.02(h)(3) Each plan shall describe site criteria and methods used for temporary storage of recovered oil and oily wastes generated during response and clean-up operations, including sites available within the marine facility, or near the spill area.

P.132

817.02(h)(4) Each plan shall identify all applicable permits, and all federal, state and local agencies responsible for issuing those permits for transit, temporary storage and ultimate waste management of all wastes likely to result from an oil spill.

P.132

817.02(h)(5) Each plan shall include information which could expedite the state approval process for the use of temporary waste storage sites, including a list of appropriate contacts and a description of procedures to be followed for each approval process.

P.132

817.02(i) OILED WILDLIFE CARE REQUIREMENTS P.155

Each plan shall describe how oiled wildlife care will be provided by one of the following approved means

P.155

817.02(i)(1) Utilize the California Oiled Wildlife Care Network (OWCN) to meet oiled wildlife care requirements: or P.91

817.02(i)(2) describe procedures that clearly outline how oiled wildlife care will be provided. The equipment, facilities, and personnel necessary to implement these procedures must be identified and assured by contract for each Geographic Area covered by the plan. Standards and written protocols for wildlife care must comply with all applicable State and federal laws.

P.155

817.02(j) TRAINING P.185-190

817.02(j)(1) Each plan shall provide that all appropriate personnel employed by the marine facility shall receive training in the use and operation of oil spill response and clean-up equipment. The plan shall describe:

P.185-190

817.02(j)(1)(A) the type and frequency of training that each individual in a spill response position receives to achieve the level of qualification demanded by their job description;

P.185-190

817.02(j)(1)(B) the procedures, if any, to train and use volunteers or other additional personnel in spill response operations as necessary for the size of the spill.

P.185-190

817.02(j)(2) Each plan shall describe the type and frequency of personnel training on methods to reduce operational risks. The description of the training shall include, if applicable, the following:

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817.02(j)(2)(A) any established training objectives that address potential spill sources and causes that were identified in the Risk and Hazard Analysis. P.185-190

817.02(j)(2)(B) the means of achieving any established training objectives, such as:

P.185-190

817.02(j)(2)(B)(1) training programs for the positions involved with the various aspects of the marine facility's operation that could result in a spill (e.g., position responsible for facility inspections or transfers);

P.185-190

817.02(j)(2)(B)(2) a training schedule, including adequate frequency, (e.g., initial training upon hire and annual refresher training) and type of training (workshops, classroom, videotape, on-the-job training, etc.) for each position trained, by job classification;

P.185-190

817.02(j)(2)(C) any licenses, certifications or other prerequisites required to hold particular jobs.

P.185-190

817.02(j)(2)(D) A plan holder whose facility is subject to and in compliance with State Lands Commission training regulations, Title 2, Division 3, Chapter 1, Article 5.3, CCR Sections 2540 through 2548, shall be considered in compliance with the training provisions of this subsection.

P.185-190

817.02(j)(3) Each plan shall provide for safety training as required by state and federal health and safety laws for all personnel likely to be engaged in oil spill response, including a program for training non-permanent responders such as volunteers or temporary help.

P.185-190

817.02(j)(4) The marine facility owner/operator shall ensure that training records are maintained for 3 years. All such documentation must be made available to the Administrator upon request.

P.185-190

817.02(k) DRILLS AND EXERCISES P.185-190

817.02(k)(1) Each plan shall describe the marine facility’s drill and exercise program that meets the requirements of Section 820.01(a), to ensure that the elements of the plan will function in an emergency.

P.191

817.02(k)(2) Training sessions may constitute creditable drills and exercises if all requirements in Subsection 820.01 (a) are met.

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817.02(k)(3) A marine facility owner/operator shall ensure that all of the response resources identified in the plan participate in equipment deployment exercises at least once every three years.

P.185

817.02(k)(4) Drill contents P.190

817.02(k)(5) Maintain drill and exercise records P.190

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