RENTON TERMINAL - apps.ecology.wa.gov

SPILL PREVENTION, CONTROL AND

COUNTERMEASURE (SPCC) PLAN

RENTON TERMINAL

Renton Terminal ii 09/29/2015

General Facility Information

Renton Terminal

(Facility Name)

2423 Lind Avenue S.W., Renton, Washington 98057 (King County) (Facility Address, County)

122o 14’07” W / 47o 27’45” N

(Facility Latitude/Longitude)

Phillips 66 Pipeline LLC (Operator)

2331 City West Blvd.

(Street Address)

Houston, TX 77042 (City, State, Zip)

Phillips 66 Pipeline LLC (Owner)

2331 City West Blvd.

(Street Address)

Houston, TX 77042 (City, Sate, Zip)

Spill Prevention, Control, and Countermeasure Plan

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Table of Contents

General Facility Information ............................................................................................................................ ii Table of Contents ............................................................................................................................................iii Appendices ....................................................................................................................................................... v

LOG OF PLAN AMENDMENTS .................................................................................................................. vi LOG OF PLAN REVIEW ............................................................................................................................. vii REGULATORY CROSS-REFERENCE (§112.7 1st Paragraph) .................................................................... x

1.0 GENERAL INFORMATION ................................................................................................................. 1

1.1 Management Approval (§112.7 1st Paragraph, WAC 173-180-630(1)) ................................................. 1

1.2 Professional Engineer Certification (§112.3(d)(1)) ................................................................................ 2

1.3 Substantial Harm Certification (§112 Appendix C-II)............................................................................ 3

1.4 Basic Applicability (§112.1(d)(2)(ii)) ..................................................................................................... 3

1.5 Facility Description, Layout and Diagram (§112.7(a)(3)) ...................................................................... 3

1.5.1 Description of Facility....................................................................................................................... 3

1.5.2 Facility Diagram................................................................................................................................ 4

1.5.3 Location of SPCC Plan (§112.3(e)) .................................................................................................. 4

1.6 Contact List and Phone Numbers (§112.20(g)(3)) .................................................................................. 5

1.7 Notification of Discharges (§112.4(a)) ................................................................................................... 5

1.7.1 Notification Data Sheet (§112.7(a)(4), §112 Appendix C 1.3.1) ...................................................... 5

1.8 Personnel, Training, and Discharge Prevention Procedures ................................................................... 5

1.8.1 Personnel Training (§112.7(f)(1)) ..................................................................................................... 5

1.8.2 Discharge Prevention Briefings (§112.7(f)(3)) ................................................................................. 6

1.8.3 Training Documentation (§112 Appendix F 1.8.3) ........................................................................... 6

1.9 Prevention, Detection, Response and Cleanup ....................................................................................... 6

1.9.1 Prevention of Discharges (§112.7(a)(3)(ii)) ...................................................................................... 6

1.9.2 Detection of Discharges (§112.7(a)(3)(iv))..................................................................................... 10

1.9.3 Countermeasures (§112.7(a)(3)(iv)) ............................................................................................... 11

1.9.4 Facility Response Plan (FRP) (§112.20, WAC 173-180-710) ........................................................ 11

1.9.5 Disposal of Release Cleanup Materials (§112.7(a)(3)(v)) .............................................................. 12

1.10 Alcohol and Drug Awareness Program (WAC 173-189-630(10)) ....................................................... 12

1.11 Impracticability of Secondary Containment (§112.7(d)) ...................................................................... 12

1.12 Deviations to Rule (§112.7(a)(2)) ......................................................................................................... 12

1.13 Plan Review and Updates (WAC 173-180-630(5)) .............................................................................. 12


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1.14 Conformance with Other Rules and Requirements (§112.7) ................................................................ 13

2.0 DETAILED FACILITY INFORMATION ........................................................................................... 16

2.1 Container and Potential Spill Sources Table (§112.7(a)(3)(i)&(iii), (b), (c)) ....................................... 16

2.2 Bulk Storage Containers ....................................................................................................................... 19

2.2.1 Completely Buried Tanks (§112.8(c)(4)) ........................................................................................ 19

2.2.1.1 Underground Storage Tanks (§112.1(d)(2)(i)) ..................................................................... 19

2.2.2 Partially Buried or Bunkered Tanks (§112.8(c)(5)) ........................................................................ 19

2.2.3 Mobile or Portable Oil Storage Containers (§112.8(c)(11)) ........................................................... 19

2.2.4 Internal Tank Heating Coils (§112.8(c)(7)) .................................................................................... 19

2.2.5 Container Overfill Fail Safe Precautions (§112.8(c)(8) WAC 173-180-330(2)) ............................ 20

2.2.5.1 Level Alarm Testing (§112.8(c)(8)(v)) ................................................................................ 20

2.3 Facility Containment, Drainage and Treatment .................................................................................... 21

2.3.1 Secondary Containment Systems (§112.7(c), §112.8(c)(2), (c)(3)) ............................................... 21

2.3.1.1 Active Containment Measures (§112.7(c)) .......................................................................... 25

2.3.2 Drainage from Diked Areas Routed to Surface Waters (§112.8(b)(1)&(2)) .................................. 26

2.3.2.1 Containment Drainage Inspections (§112.8(b)(1), (c)(3)(ii)&(iv)) ...................................... 26

2.3.3 Effluent Treatment System (§112.8(c)(3)&(9)), 112.8b5 ............................................................... 26

2.3.3.1 Drainage from Tank Dikes Through Effluent Treatment System (§112.8(c)(3)) ................ 27

2.3.4 Drainage from Facility Undiked Areas to Surface Waters (§112.7(c), §112.8(b)(3)) .................... 27

2.3.5 Oil-Filled Operational Equipment (§112.7(k)) ............................................................................... 28

2.4 Facility Transfer Operations, Pumping and Facility Processes (§112.8(d)) ......................................... 28

2.4.1 Facility Below Ground Piping (§112.8(d)(1)) ................................................................................ 28

2.4.2 Out of Service Piping (§112.8(d)(2)) .............................................................................................. 28

2.4.3 Pipe Supports (§112.8(d)(3)) .......................................................................................................... 28

2.4.4 Vehicle Warnings (§112.8(d)(5)) .................................................................................................... 29

2.5 Tank Car & Tank Truck Loading/Unloading Rack(s)(§112.7(h)) ........................................................ 29

2.5.1 Tank Car & Tank Truck Containment Systems for Loading/Unloading Rack(s) (§112.7(h)(1)) .. 29

2.5.2 Prevention of Premature Vehicular Departure from Truck Rack (§112.7(h)(2)) ........................... 29

2.5.3 Prevention of Premature Movement of Rail Tank Cars (§112.7(h)(2)) .......................................... 30

2.5.4 Drain and Outlet Inspection for Rack(s) (§112.7(h)(3)) ................................................................. 30

2.6 Tank Car and Tank Truck Loading/Unloading Area(s) (§112.7(c)) ..................................................... 30

2.6.1 Tank Car & Tank Truck Containment Systems for Loading/Unloading Area(s) ........................... 30

2.7 Security (§112.7(g)) .............................................................................................................................. 30

2.7.1 Perimeter Security Measures .......................................................................................................... 30

2.7.2 Master Flow and Drain Valve Security ........................................................................................... 31


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2.7.3 Access to Pumps and Starter Controls ............................................................................................ 31

2.7.4 Out-of-Service Loading/Unloading Piping Connections ................................................................ 31

2.7.5 Security Lighting ............................................................................................................................. 31

2.8 Inspections, Tests and Records (§112.7(e)) .......................................................................................... 31

2.8.1 Container Testing and Inspections .................................................................................................. 31

2.8.1.1 Above Ground Tanks (§112.8(c)(6)) .................................................................................... 31

2.8.1.2 Below Ground Metallic Containers (§112.8(c)(4)) .............................................................. 32

2.8.2 Facility Piping Testing and Inspection ............................................................................................ 32

2.8.2.1 Buried Piping Integrity and Leak Testing (§112.8(d)(1)) .......................................................... 32

2.8.2.2 Aboveground Piping Examination (§112.8(d)(4)) ..................................................................... 32

2.8.3 Secondary Containment System Integrity Inspections (§112 Attachment F 1.8.1.3, WAC 173-180-320(1)(h)) ................................................................................................................................................... 33

2.8.4 Other Applicable Inspections (§112.7(e)) ....................................................................................... 33

2.8.5 Documentation (§112 Attachment F 1.8.1)..................................................................................... 33

Appendices

Notification ........................................................................................................................... A-1

Logs ........................................................................................................................................ B-1

Facility Diagram §112.7(a)(3) ................................................................................................. C-1

Oil Spill Contingency Plan §112.7(d)(1) .................................................................................. D-1 Containment Volume Calculations §112.7(h)(1), §112.8(c)(3) ................................................ E-1 Company Maintenance, Inspection and Integrity Standards §112.7(e), §112.8(c)(6), (d)(4) .. F-1 Example Personnel Training Schedule ................................................................................... G-1


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LOG OF PLAN AMENDMENTS NON TECHNICAL AMENDMENTS

• Non-technical amendments are not certified by a Professional Engineer.

• Examples of changes include, but are not limited to, phone numbers, name changes, or any non-technical text change(s).

TECHNICAL AMENDMENTS

• Technical amendments are certified by a Professional Engineer (§112.5(c)). • Examples of changes include, but are not limited to, commissioning or decommissioning containers;

replacement, reconstruction, or movement of containers; reconstruction, replacements, or installation of piping systems; construction or demolition that might alter secondary containment structures; changes of product or service; or addition/deletion of standard operation or maintenance procedures related to discharge prevention measures. It is the responsibility of the facility to determine, and confirm with the regulatory authority as necessary, what constitutes a technical amendment. The rule requires a technical amendment only “when there is a change that materially affects the facility’s potential to discharge oil”. (§112.5(a))

• An amendment made under this section will be prepared within six (6) months of the change and

implemented as soon as possible but not later than six (6) months following preparation of the amendment.

• Technical Amendments affecting various pages within the plan can be PE certified on those pages, certifying those amendments only, and will be documented on the log form below.

Amend Date

Signature* (Specify)

Amend Plan (will/will not)

Description of Amendment

Affected Page(s)

P.E. Certification

(Y/N) 02/18/03 Engineer Will not New SPCC format All Y

05/19/06 Engineer Will Added Tank 12 All Y

04/06/09 Engineer Will Review and revise plan as necessary

All Y

11/07/12 Engineer Will Review and revise plan as necessary

All Y

11/2013 Engineer Will Revise secondary containment calculations and plan text as necessary

All Y

09/29/15 Engineer Will Incorporate new groundwater remediation system and plan template

All Y

* Typically signed by Manager, Professional Engineer or plan reviewer. .

Plan Based on API Bulletin D-16, Fifth Edition, April 2011. Template Version 2, July 2015


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LOG OF PLAN REVIEW MANAGEMENT REVIEW

• Management will review this SPCC Plan at least each five (5) years and document the review on the form below (§112.5(b)).

• By signature below, signor confirms that management has completed a review and evaluation of this SPCC Plan.

Review/Amend Date

Signature* (Specify)

Amend Plan (will/will not)

Description of Review/Amendment

Affected Page(s)

P.E. Certification

(Y/N) 2/18/03 Manager Will not Review and adopt new

SPCC format All Y

5/19/06 Manager Will Review and add Tank 12 All Y

3/26/08 Facility Supervisor Will not Review and revise figures (curbing, ball valves and tank nos.), Added text to 2A.3.1, 2A.3.2 and 2A.3.5

Appendix C, Pages 2A-4 through 2A-6, Table P1, 2A-12

N

04/06/09 Facility Supervisor Will Review and revise plan as necessary

All Y

03/11/11 Facility Supervisor Will not Add forms Appendix B N

11/07/12 Facility Supervisor Will Review and revise plan as necessary

All Y

12/7/15 Bob Ayers Will Review and revise plan as necessary

All N

08/09/16 Environmental Coordinator

Will Updated language to accommodate 24/7 off-loading of ethanol

9 N


Will Deletion of description of 2-in drain valve on east curbing behind remediation system.

22 N


Will Found that the PE license on Certification page had Feb 2015 expiration. Consultation with PE determined it was a “typo” and amended Certification page provided with Feb 2018 date.

2 N


Will Added inspection protocol language to the piping discussion in Sec 1.9.1.

6 N

Updated Section 1.10 Impracticability, to state that no general containment issues are present based on reassessment of piping near tank dike

11 N


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Added Section 1.9.4 to provide information on facility response plan. Renumbered previous 1.9.4 to 1.9.5

11 N

Updated Section 1.11 Deviations to Rule due to removal of any Impracticabilities.

12-13 N

Section 2.1. Updated table to indicate the inspection protocol for each tank. Noted T-13 as permanently OOS.

16 N

Section 2.1. Added ethanol offloading scenarios.

17 ?

Updated TSP-9401 to TSD-9401 to account for document standardization.

19 N

Section 2.2.5.1 Updated language for the change of TPO-4001 to GPL-6023.

20 N

Section 2.8.1.1 Updated language to include STI-SP001 program for small tanks.

32 N

12/08/17 Senior Environmental Consultant

Will Section 1.8.1 Added details on who/when training is required

5 N

Section 1.9.1 Specific reference to API 570 added

7 N

Inspection/testing: Updated containment inspections (2.8.3) to monthly and clarified that rectifiers are bi-annually tested

8 and 32 N

Section 1.9.4 – Clarified that only approval signature page of ICP in Appendix D.

11 N

New section 1.10 – Drug/Alcohol Awareness Policies

12 N


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New section 1.13 details when plan is to be updated.

12 N

Section 1.14 added reference to WA regulations.

13 N

Section 2.2.5.1 clarified frequency of high level alarm testing.

19 N

Section 2.3.1 added table listing site soil types and infiltration rates.

24 N

Appendix A: Updated notification log

Appendix A N

Appendix D: Clearly notes that only the ICP plan approval page in Appendix and full ICP is not included.

Appendix D N

New Appendix G: Example Training Matrix

Appendix G N


Will Corrected spelling error 5 N

Corrected retention of training documents from 3-yrs to 5-yrs

6 N

Added text for on-the- job training and remedial training

1.8.3 6

N

Added regulatory language from WAC 173-180-630(5)

12 N


Will Updated material stored in Tank 13. New terminal supervisor.

Page 1, Table 2.1 (p15 and 18, Figures rent-ev-0001 and 0002

N

* Typically signed by Manager, Professional Engineer or plan reviewer.


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REGULATORY CROSS-REFERENCE (§112.7 1st Paragraph) Citation Description Section §112.1(d)(2)(i) General Applicability – Underground Storage 2.2.1.1 §112.1(d)(2)(ii) General Applicability – Aboveground Storage 1.4 §112.3 1st Para. Requirement to prepare written plan N/A

§112.3(a)(1) Timing for amendment of plan for a non-production facility in operation prior to August 16, 2002 and deadline to develop a plan for facilities placed in operation after November 10, 2011

N/A

§112.3(a)(2) Timing for amendment of plan for a production facility in operation prior to August 16, 2002 and deadline to develop a plan for facilities placed in operation after November 10, 2010

N/A

§112.3(b) [Reserved] N/A §112.3(d)&(d)(1) Professional Engineer Certification 1.2 §112.3(e) Location of SPCC plan 1.5.3 §112.3(f) Qualified facilities N/A

§112.4(a) Amendment of plan by regional administrator, notification of qualified discharges 1.7

§112.5(a) Amendment of plan for material changes Log of plan review and amendments

§112.5(b) Management of Five Year Review Log of plan review and amendments, 1.1

§112.6 Qualified facilities plan requirements N/A §112.7 General Requirements §112.7 1st Para. Management approval of resources, plan layout and cross-reference 1.1, ICP Annex 1 §112.7(a) General requirements ------ §112.7(a)(1) Conformance with requirements 1.14 §112.7(a)(2) Deviation from or nonconformance with requirements 1.12 §112.7(a)(3) Physical description of facility layout and facility diagram 1.5 §112.7(a)(3)(i) Container type and storage capacity 2.1 §112.7(a)(3)(ii) Discharge prevention measures 1.9.1

§112.7(a)(3)(iii) Discharge drainage controls 2.1 2.3.2, 2.5, 2.6, 2.8.3

§112.7(a)(3)(iv) Countermeasures 1.9.2, 1.9.3, ICP §112.7(a)(3)(v) Disposal of recovered materials 1.9.4 §112.7(a)(3)(vi) Contact lists 1.6, ICP Annex 6.3 §112.7(a)(4) Release reporting for sites without a §112.20 response plan 1.7.1, ICP §112.7(a)(5) Response procedures for sites without a §112.20 response plan ICP §112.7(b) Reasonable potential for equipment failure 2.1

§112.7(c) General secondary containment 2.1 2.3.1, 2.3.5, 2.6.1

§112.7(d) Impracticability of containment 1.11 §112.7(d)(1) Oil spill contingency plan ICP

§112.7(d)(2) Written commitment of resources ICP Core Section I and Annex 1.1

§112.7(e) Inspections, tests, and records 2.8, 2.8.4, App. F §112.7(f) Employee training and discharge prevention procedures 1.8.1, 1.8.3 §112.7(f)(1) Training requirements 1.8.1 §112.7(f)(2) Discharge prevention designated person 1.1 §112.7(f)(3) Scheduled briefings 1.8.2 §112.7(g) Security (excluding oil production facilities) 2.7


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REGULATORY CROSS-REFERENCE (§112.7 1st Paragraph) §112.7(h)(1) Loading/unloading rack containment 2.5.1 §112.7(h)(2) Loading/unloading rack vehicle interlock systems 2.5.2 §112.7(h)(3) Loading/unloading rack inspection of tank car drains and outlets 2.5.4 §112.7(i) Brittle fracture evaluation requirements 2.8.1.1 §112.7(j) Conformance with State requirements 1.12 §112.7(k) Qualified oil-filled operational equipment 2.3.5 §112.7(k)(1) Qualification criteria N/A §112.7(k)(2) Alternative requirements to general secondary containment N/A §112.8 Detail Facility Information §112.8(a) General and specific requirements N/A §112.8(b) Facility drainage 2.3.2 §112.8(b)(1) Containment area discharge 2.3.2, 2.8.3.1 §112.8(b)(2) Containment area drain valves 2.3.2 §112.8(b)(3) Drainage from undiked areas 2.3.4 §112.8(b)(4) Drainage diversion systems §112.8(b)(5) Drainage treatment systems 2.3.5 §112.8(c) Bulk storage containers ----- §112.8(c)(1) Construction materials compatibility 1.9.1 §112.8(c)(2) Secondary containment 2.3.1 §112.8(c)(3) Drainage of accumulated rainwater 2.3.2, 2.3.1, 2.3.3.1 §112.8(c)(4) Buried metallic tanks installed on/after January 10, 1974 2.2.1 §112.8(c)(5) Partially buried or bunkered metallic tanks 2.2.2 §112.8(c)(6) Testing and inspection of aboveground containers 2.8.1.1 §112.8(c)(7) Internal heating coils 2.2.4 §112.8(c)(8) Container level alarms 2.2.5 §112.8(c)(9) Effluent treatment systems 2.3.3 §112.8(c)(10) Repair of visible leaks from container and associated equipment 2.3.1 §112.8(c)(11) Mobile and portable containers 2.2.3 §112.8(d) Facility transfer operations, pumping, and facility process ----- §112.8(d)(1) Buried piping corrosion protection 2.4.1 §112.8(d)(2) Out-of-service piping 2.4.2 §112.8(d)(3) Pipe support design 2.4.3 §112.8(d)(4) Above ground piping inspections 2.8.2.2 §112.8(d)(5) Vehicle warnings 2.4.4 §112.9 Requirements for onshore production facilities N/A §112.10 Requirements for onshore oil drilling and workover facilities N/A §112.11 Requirements for offshore oil drilling, production, or workover facilities N/A §112.12 Requirements for onshore non-petroleum based oils N/A §112.13 – 15 [Reserved] N/A §112.20 Facility response plans ICP §112.20(g)(3) Information about emergency response, facility contacts 1.6, ICP Annex 6 §112.21 Facility response training and drills/exercises ICP Core Section III §112 App C Substantial Harm Criteria 1.3, ICP Annex 1 §112 App C 1.3.1 Spill Notification Form 1.7.1, ICP Annex 6 §112 App F 1.8.1 Inspection recordkeeping 2.8.5 §112 App F 1.8.1.3 Containment inspections 2.8.3 §112 App F 1.8.3 Documentation of training 1.8.3 WAC173-180-630 (5) Plan review and updates 1.13 WAC173-180-630 (10) Alcohol and Drug Awareness Program 1.10


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SECTION ONE

General Information


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1.3 Substantial Harm Certification (§112 Appendix C-II)

The substantial harm determination and certification is located in Annex 1 of the Washington State facilities Integrated Contingency Plan (ICP).

1.4 Basic Applicability (§112.1(d)(2)(ii)) As noted in section 1.5.1, the facility has a total aboveground oil storage capacity greater than 1,320-gallons (31.5 bbls). This volume includes all containers greater than or equal to 55 gallons in size. This facility is in part subject to U.S. Department of Transportation jurisdiction. (§112.1(d)(1).

1.5 Facility Description, Layout and Diagram (§112.7(a)(3))

1.5.1 Description of Facility

The Renton Terminal is a light refined petroleum products storage and distribution facility that handles diesel, gasoline, fuel additives, and ethanol. Gasoline and diesel products are received by pipeline and are distributed by tank trucks. Ethanol and fuel additives are delivered and distributed only by tank trucks. The majority of the petroleum products are received through the Olympic Pipeline located adjacent to the terminal. The Olympic Pipeline products are received through the pump station, located along the north side of Tank Farm within the approximate center of the facility. Petroleum products are pumped directly into aboveground storage tanks (ASTs), and delivered out of the terminal in trucks and trailers through the Truck Loading Rack that is equipped with a vapor recovery unit (VRU). The VRU returns the stripped vapor back to the product ASTs. Petroleum product is moved between the pipeline, the ASTs and the Truck Loading Rack through aboveground steel piping. All tanks, except the additive tanks, are equipped with alarms that register high level conditions in the office and sound an alarm in the yard. The Renton Terminal is fully secured by galvanized fencing with locked/gated entrances. Fuel delivery drivers have key-card access to the terminal 24 hours per day, 365 days a year for loading. The Renton Terminal is usually staffed 16 hours a day Monday through Friday, with occasional weekend coverage during pipeline receipts. The terminal’s petroleum storage consists of eleven (11) ASTs ranging in nominal capacity from 6,392 gallons to 2,590,875 gallons. The majority of ASTs are located on the west side of Lind Ave. within a level, earthen containment area (Tank Farm). Concrete block sub-dikes surround each of the large ASTs (Tanks #1 through #7) to enable localized containment of small spills. Tank #12 is only petroleum AST located outside the Tank Farm with dedicated secondary containment (i.e., concrete walls and floor). A soil berm surrounds the terminal’s only Tank Farm at the terminal, as well as. The soil berm is designed to provide adequate capacity in case of a spill or tank rupture at the terminal. The floor of the tank farm is covered with gravel. Permeability of the tank farm berm and floor is low and stormwater runoff generally pools and stands in low points within each sub-diked area. Stormwater within each sub-dike area ultimately drains to a common collection area.

The VRU and process water treatment area is surrounded by concrete curbing and slab that provide secondary containment for each area. A concrete drive slab and curbing exists around the edge of Truck Loading Rack to prevent the runoff or loss of spilled product. Asphalt pavement and concrete



curbing direct stormwater to the nearest catch basin throughout the terminal’s driveway and vehicle parking areas. Drums and/or totes are periodically stored on site for temporary storage of petroleum products, additives, and wastes. There are two intermodal containers (e.g., Connex) that are used for equipment and drum storage; one to the south of the office and one to the north of the Truck Loading Rack. Drums and/or totes are also stored within the containment area of the two groundwater treatment equipment compounds, as well as, within the Truck Loading Rack containment area. There have not been any major spills or leaks reported for the facility the past 10 years. Ecology records show that on November 13, 2002, Tosco Corporation (who was leasing the facility at the time) had a release of 14,800 gallons of super-unleaded gasoline, resulting from a bulk tank bottom failure in the bulk storage tank designated as Tank No. 2 at the south half of the property. Under an Agreed Order with Ecology, Phillips 66 has been remediating residual petroleum hydrocarbons in soil and groundwater that resulted from the 2002 gasoline release, plus a separate gasoline and diesel release discovered in the late 1980’s when ExxonMobil was the terminal owner/operator. The ExxonMobil release is located north of the Tank No. 2 release and is near the facility’s existing Truck Loading Rack. Extraction wells are being used to remediate soil and groundwater beneath the terminal and one multi-phase remediation unit is currently located at the facility to remediate both areas. The remediation unit (a.k.a., Phillips 66 soil vapor/groundwater treatment compound) is located east of the Truck Loading Rack and its equipment (vapor treatment, oil/water separation, particulate filtration and granular activated carbon polishing) is currently used to treat soil vapor and groundwater recovered from dual phase extraction (DPE) wells located throughout the facility. Additional details on the size/contents of containers and other facility equipment are presented in Section 2.1, Container and Potential Spills Table (§112.7(a)(3)(i)).

1.5.2 Facility Diagram A diagram of the facility is located in Appendix C. The details and location of the following are noted on the facility diagram(s): • Process equipment, operating equipment, electrical equipment. • Truck loading/unloading racks. • Truck loading/unloading areas. • Fixed aboveground storage containers. • Transfer stations and connecting lines. • Completely buried and/or bunkered tanks • Sumps and oil/water separators • Mobile and portable container storage areas. Due to the inherent complexity of the facility, some of the information required above cannot be presented on the facility diagram. Additional details are provided on engineering drawings at the terminal office or can be viewed using the Falcon SVP program link on the Terminals or Pipelines home page.

1.5.3 Location of SPCC Plan (§112.3(e))

A complete copy of the SPCC Plan is maintained in the facility office. The plan can also be accessed in Livelink within the facilities Environmental, Water Quality folder.



1.6 Contact List and Phone Numbers (§112.20(g)(3))

A contact list and phone number reference for the facility is provided in the Emergency Notification Phone List provided in Annex 6.3 of the ICP.

1.7 Notification of Discharges (§112.4(a))

In the event this facility experiences a reportable spill of 1,000 gallons or more, or two (2) reportable spills of greater than 42 gallons each within any 12-month period, an Agency Notification to Regional Administrator for Qualified Discharge(s) will be submitted to the Regional Administrator (EPA Region 10) within 60 days. If, upon review of the release information, the Administrator requires the amendment of the this plan, the Company will amend the plan within the 30-day, or other specified timeframe (§112.4(d),(e),(f)). A listing of all reportable spills for the facility is located in Annex 1 of the ICP (§112.7(k)(1). The company also requires that all releases be recorded within the Company’s IMPACT system.

1.7.1 Notification Data Sheet (§112.7(a)(4), §112 Appendix C 1.3.1)

A Notification Data Sheet is provided in Annex 6.7 of the facility ICP and a copy located in Appendix A.

1.8 Personnel, Training, and Discharge Prevention Procedures

1.8.1 Personnel Training (§112.7(f)(1)) All employees are required to take a training cover a broad range of topics and formats. Most training is performed using computer based training modules. Other training must be conducted in a classroom setting based on applicable company and regulatory requirements. The training requirements for the Terminal personnel are detailed in the example training matrix located in Appendix G. The Facility provides the following SPCC specific training to oil-handling personnel prior to assignment of job responsibilities:

• Operation and maintenance of equipment to prevent oil discharges; • Oil discharge procedure protocols; • Applicable oil spill prevention (State & Federal) laws, rules, and regulations; • General facility operations; and, • The contents of the facility SPCC Plan and applicable pollution control laws, rules, and

regulations. New operations employees receive training on these subjects within six months of the first day of employment. In addition to the above list, annual spill response exercises are conducted as recommended by the Core Section III if the ICP and Incident Command System training on an as needed basis.



1.8.2 Discharge Prevention Briefings (§112.7(f)(3)) The facility conducts prevention briefings for oil-handling personnel at least once a year to assure adequate understanding of the SPCC Plan for the facility. These briefings include a discussion of potential or known discharges, component failures, and precautionary measures. SPCC training may also be conducted at any of the monthly safety meetings, during the annual spill exercise or by computer based training through Learning Express.

1.8.3 Training Documentation (§112 Appendix F 1.8.3) Documentation of these Personnel, Training, and Discharge Prevention Briefing programs is maintained in the Learning Management System and retained for a minimum of five (5) years. These records are accessible from the Division Office or Corporate Headquarters. Prior to being allowed to work independently all new employees must complete approximately 80 hours of On the Job Training (OJT) working with an experienced employee. This training goes hand in hand with class room, Company CBT and local operating procedures training. Training for local operating procedures (LOP) is tracked to completion on the Terminal Operator Qualifications and Training Guide (Guide). This guide covers operation and maintenance procedures for all process and water treatment systems/equipment. As the employee passes a section of LOP training, trainee operator, trainer and supervisor sign the specific section completed on Guide. This document is placed in the employee’s training file. In the event an employee is clearly responsible for or suspected for causing a release and said employee is not discharged for their actions, remedial training shall be given. Remedial training shall be decided at the time of the spill by the Division Manager or their designee. Remedial training shall not be less than 48 hours in duration and consist of fuel transfer operations specifically related to determining volume and capacities of receipts and storage vessels being used to store products and valve line procedures for the individual storage tanks. Additional training will be given as necessary to address the initial incident cause and mitigation of future events. Documentation of remedial training shall be placed in the employee’s training file.

1.9 Prevention, Detection, Response and Cleanup

1.9.1 Prevention of Discharges (§112.7(a)(3)(ii))

The facility employs various discharge prevention measures, including procedures for routine handling of products (loading, unloading, facility transfers, etc.), routine monitoring, inspection, and testing as described below: Equipment Design

Fixed aboveground containers: At a minimum, all field-constructed aboveground containers are designed, operated and maintained in accordance with API-650, API-12A, API-12C, 12F or UL-142 standards. The



materials for and construction of bulk storage containers are compatible with the material stored and conditions of storage such as pressure and temperature (§112.8(c)(1)). The storage tanks are also equipped with gauging and level alarm systems.

Piping and associated appurtenances: At a minimum, the piping at the facility is designed, operated and maintained in accordance with ASME B31.4 industry code. Cathodic protection systems and coatings and/or wraps are used to protect the piping once installed. Oil temperatures are normally at or below atmospheric and operating pressure cycles are well below the design pressure of the piping systems. Knowledgeable personnel internally inspect the piping at the facility whenever it is open for maintenance or modification. All above ground piping is visually inspected by qualified operations personnel and ultrasonically tested according to API 570 requirements by a qualified equipment inspector at the intervals specified in MPR 6008 and MI 0410.

Pressure relief devices: Thermal pressure relief devices are present at the facility and are used to protect piping and equipment from overpressure, which could occur if liquids in an isolated area become heated. Thermal pressure devices are routed to sumps, tankage or other containment to prevent the release of oil to the environment. Standard maintenance procedures at the facility include performing a pop test when installed and during major repairs of the equipment or pipe being protected. Thermal relief devices are visually inspected and tested by knowledgeable personnel at the intervals specified in Appendix A of MPR-4226. (MI 0610 and MI 0620) Overpressure relief devices are present at the facility to protect piping and equipment from damage in the event of pressure transients in the system. These devices, including transmitters, controllers, control valves, etc., have been installed to limit process pressures. Pressure relieving devices, such as relief valves, are also installed according to good engineering practice to prevent pressure buildup due to process excursions and surges in tanks, vessels, piping and pipelines. Spring-loaded relief valves and rupture disks are included in this category. Pressure-relief valves and spring-loaded valves on piping and pipelines are pop tested and inspected by knowledgeable personnel at the intervals specified in Appendix A of MPR-4218. (MI 0620, MI 0630 and MI 0640)

Automated Tank Overfill Prevention The bulk storage tanks at the facility are equipped with automated high and independent high-high level monitoring equipment. If the liquid in a tank reaches preset levels, an audible alarm is sounded to alert operations personnel within the facility grounds, as well as a visual and audible signal in the facility control room (e.g., RSView® system) of a potential overfill and automatic shutdowns are initiated to prevent overfilling the tank. The level alarms are also monitored 24/7 at the Company’s Main Control Center. Product Loss/Gain The quantity of products stored at the facility are routinely determined and validated following the loss/gain procedures detailed in the Operations Measurement Manual. Measures include the following; automated and manual tank gauging, receipt and discharge meters and load receipts. Any discrepancies are investigated to determine if a leak may be responsible for a loss.



Calibration of Measurement Equipment Tank level gauges and product flow meters are key monitoring and measurement devices and require regular calibration to insure the accuracy of the measurement data.

Tank Gauging All product storage tanks are equipped with automatic tank gauging systems that constantly monitor liquid levels. Manual tank gauging is conducted regularly to verify the accuracy of the automatic gauging system. Gauging procedures are detailed in Section 100 of the Operations Measurement Manual.

Meter Proving There are flow meters at the facility located within the receipt/discharge manifold(s) and at the loading rack. These meters are regularly tested using fixed and/or portable provers at the loading/unloading facilities (rack meters) and a fixed prover for the pipeline receipt/discharge meters. Proving is regularly performed per the requirements presented in Section 300 of the Operations Measurement Manual.

Inspections and Testing

Secondary Containment Inspections Formal inspections of all secondary containment structures are conducted monthly as detailed in Section 2.8.3. Equipment Testing Knowledgeable employees conduct regularly scheduled external and internal inspections and testing of facility equipment in accordance with Company policies and practices and recognized industry standards such as API 653. Inspection and testing of storage tanks and facility piping are discussed in more detail in Section 2 of this plan. Cathodic protection systems are routinely tested and inspected according to MI 500. These systems are inspected per the specifications and frequency in MPR 6018, with rectifiers and other critical protection devices electrically checked six (6) times per year following MPR 6015 and 6016 guidelines. Additional Self Inspection Numerous self-inspections are regularly performed of the tanks and equipment at the facility. There are written procedures detailing how and when to inspect the various types of equipment. A listing of the applicable Company standards and testing/inspection programs/procedures is presented in Appendix F.



Routine Material Handling Procedures

Truck Loading Rack Gasoline and distillate loading of tanker trucks occurs within the Truck Loading Rack containment area under the direct supervision of trained drivers and/or terminal office. The covered Truck Loading Rack area is completely paved with concrete, with curbed edges and sloped towards low-point strip drains that gravity drain to a buried 15,000-gallon double-walled fiberglass containment tank. All product conveyance hose connections occur within the containment area. All product loading is accomplished using preset meters equipped with overfill sensors that are designed to automatically close the meter set/stop control valve before overfill of the truck container can occur. In addition, the drivers and/or facility staff are trained on the location of nearby emergency shutdown switches. To prevent premature vehicle departure, truck and trailers are equipped with an air switch that locks the truck brakes until the vapor hose is disconnected. Unloading Areas The unloading area for fuel additives and ethanol is subject to the requirements of 112.7(c) for general secondary containment via active measures. Facility personnel are trained in spill response during safety meetings and annual drills. The specific measures for the designated additive and ethanol unloading area is described below.

Transfer Station for Additives & Ethanol Transfers of fuel additives and ethanol from delivery trucks to storage tanks occur within the southern end of the Truck Loading Rack containment area (Lane 4) and are performed by means of a transfer hose from the truck to tank connection. The hose connections to the tanks are located inside the dedicated additive containment wall or earthen berm surrounding the Tank Farm. The product tanker trucks park within the concrete curbed and paved containment area of the Truck Loading Rack during transfers. Therefore, all hose and piping connections are inside secondary containment areas. The unloading operations pose a minimal risk for a release with the most likely source being a leak at the hose connections. In addition to secondary containment provided by concrete curbing, flooring, and low-point drains connected to a buried spill containment tank, the following active measures are used during all routine and non-routine product transfers: 1. Additive and ethanol unloading are performed only by truck drivers trained in this operation. 2. Driver places a bucket or drip pan under the hose connections before unloading begins, and

remains present throughout the procedure to stop the operation if a spill or leak occurs. 3. Additive and ethanol unloading occur on concrete pavement which is contiguous and

equipped with low-point drains that are connected to a buried 15,000-gallon spill containment tank.

4. Transfer operations of fuel additives are scheduled and occur only during daylight hours and when facility personnel are onsite. Ethanol deliveries can be received and off-loaded outside of normal business hours.



1.9.2 Detection of Discharges (§112.7(a)(3)(iv))

Detection by Personnel The most likely method for the detection of any leak or potential discharges is by facility personnel during performance of their normal duties and rounds. Transport trucks load and/or unload throughout the day at the facility with product loading and ethanol off-loading are conducted 24/7. Any leaks or potential leaks at or in the vicinity of the load/unloading racks/areas would be observed by the transport drivers. Prior to receiving authorization to load/off-load at the facility, the truck drivers are provided training on the facility and operation of the rack, including the location of any Emergency Shut Down switches (ESDs) and emergency contact numbers. This training requires them to activate the ESD if deemed appropriate and notify the facility Supervisor immediately if they discover a leak or spill while at the facility. Emergency contact numbers are posted at the rack, office, and remediation equipment compounds.

Unloading of additives only takes place during normal business hours and the transfer process is fully manned. Drivers are given facility orientation training prior to being allowed to offload at the facility. This training includes instructions on how to contact operations personnel in case of leaks/spill during off-loading. Control Room This facility has an onsite control room that is manned 16 hrs. a day (Monday – Friday) for monitoring and controlling of operations. Transfer operations are also monitored and/or controlled from the Company Main Control Center in coordination with facility personnel. After Hours Operations The facility is fully staffed during normal business hours (6 am to 6 pm), Monday thru Friday with occasional weekend coverage during pipeline receipts. Product transport trucks can load at the terminal 24/7 using driver/trailer access card systems. This means that any leaks or potential leaks around the rack could be observed by the transport truck drivers during after hour periods. Prior to receiving the vend card and authorization to load at the terminal, the truck drivers are provided training on the facility and rack operations, including the location of ESDs and emergency contact numbers. This training requires them to activate the ESD and notify the Terminal Supervisor or Terminal Attendant immediately if they discover a leak or spill during loading. Emergency contact numbers are posted in the loading rack area. Automated Discharge Detection and Alarm Systems

Storage Tanks: As noted earlier, all atmospheric product tanks are equipped with automated high-level and high-high level alarms. If, during the receipt or delivery into a tank, the level of the product reaches the preset high-level position in the tank, a warning alarm will be sounded to inform operators (either the on-site control or main control center) to immediately stop the flow of product into the



tank. If the level of product reaches the preset high-high level position, a warning alarm would be activated and product flow will shut down automatically and/or product flow diverted to another tank. Whenever a high or high-high level alarm is sounded the terminal controller in the field and/or control room would initiate an investigation to determine the cause of the alarm. Truck Loading Rack: The Truck Loading Rack is equipped with a Scully® grounding systems, that include automatic overfill detection systems in conjunction with the terminals loading control system. All trucks loading at the terminal must have compartment level sensors that are compatible with Company equipment. Also, all the information on each trailer (number of compartments and compartment sizes) are loaded into loading rack control system. If the truck compartment high level sensor is triggered, the Scully cable will carry the overfill signal to rack loading controller that will automatically shut down loading pumps. Should truck sensors fail, the driver would activate one of the emergency shutdown (ESD) buttons present within each rack. Pressing the ESD button will shut-down all loading at the rack.

1.9.3 Countermeasures (§112.7(a)(3)(iv)) The Company’s discharge response priorities are as follows:

• Ensure the Safety of Citizens and Response Personnel • Control the Source of the Spill • Manage a Coordinated Response Effort • Maximize Protection of Environmentally-Sensitive Areas • Contain and Recover Spilled Material • Recover and Rehabilitate Injured Wildlife • Remove Oil from Impacted Areas • Minimize Economic Impacts • Keep Stakeholders and Public Informed of Response Activities Full details on the response to a release, as well as the contract resources available to the facility for discharge cleanup are provided in the ICP. Response Equipment Inspections There are on-site control measures (e.g., sorbent pads) and equipment at this facility at the following locations: Connex containers south of the office and north of the Truck Loading Rack; as well as 55-gallon drum “spill kits” in the southeast and southwest corners of the facility, and inside the groundwater remediation system compound. This equipment is regularly inspected per the schedule in Annex 6.4 of the ICP to ensure its functionality and that proper inventories are maintained. Refer to Section 2.3.1.1 for additional containment measures.

1.9.4 Facility Response Plan (FRP) (§112.20, WAC 173-180-710)

The Facility has an agency approved Integrated Contingency Plan (ICP) that describes protection measures to minimize the impact of a discharge, and remediation measures that would mitigate any



impacts. The ICP designates a Facility response team and identifies contracted oil spill response organizations that are available to respond to incidents at the Facility. The ICP also contains written internal and external notification procedures, response procedures, and documented training and exercise programs. Further, the ICP contains a written commitment of manpower, equipment and materials required to expeditiously control and remove any quantity of discharged oil. A copy of the most current agency approval letter is located in Appendix D.

1.9.5 Disposal of Release Cleanup Materials (§112.7(a)(3)(v))

The Company has well established methods for the proper sampling, characterization and disposal of recovered materials that are compliant with all applicable local, state, tribal and federal requirements. These methods and procedures are detailed in Core Section II.8 of the ICP.

1.10 Alcohol and Drug Awareness Program (WAC 173-189-630(10))

In order to ensure the safety of employees and the prevention of releases due to equipment damage the Company implemented a robust substance abuse policy and program that applies to all employees. Testing is conducted pre-employment, on random/periodic schedules, post-incident and for reasonable suspicion/cause. Employees are also required to participate in annual awareness training.

1.11 Impracticability of Secondary Containment (§112.7(d))

There are no impracticability’s for containment and/or diversionary structures or equipment to prevent a discharge from all areas of the facility.

1.12 Deviations to Rule (§112.7(a)(2))

The facility has no deviation(s) from the rule.

1.13 Plan Review and Updates (WAC 173-180-630(5))

The plan is reviewed with facility personnel during the annual briefing to determine if there are any non-technical updates (e.g., contact phone numbers) need to be made. Any physical changes (i.e., technical changes) to the facility are evaluated to determine if any updates are required and if the changes need to be reviewed and certified by a P.E. The plan is fully reviewed by the Terminal supervisor, environmental and P.E. every 5-years. During the review, the plan is updated for any changes not incorporated in the annual reviews. The P.E. typical recertifies the plan during the 5-year review. The following process is to be followed when making any changes to the plan. Ecology must be notified in writing as soon as possible and prior to completion of any significant change which could affect the plan. If the change will reduce the facility's ability to implement the plan, the plan holder must also provide a schedule for the return of the plan to full implementation capability.



A significant change includes, but is not limited to:

• A change in the owner or operator of the facility; • A change in the types of oil handled at the facility; • A five percent (5%) or greater change in the facility's oil handling capacity; • Noncompliance with the Federal Oil Pollution Act of 1990; • Noncompliance with state financial responsibility requirements developed under chapter

88.40 RCW; and • A substantial change in oil spill prevention technology installed at the facility, or other

substantial changes to facility equipment, operations, personnel procedures, or any other change, including compliance with amended or new rules adopted by ecology, which substantially affects the level of risk described pursuant to WAC 173-180-630.

Changes which are not considered significant include, but are not limited to, minor variations (less than 5%) in oil handling capacity, maintenance schedules, and operating procedures, provided that none of these changes will increase the risk of a spill. The facility must update the plan's list of discharges, as required by WAC 173-180-630, within thirty calendar days after an oil discharge by the facility in excess of 25-barrels (1,050 gallons) A listing of these discharges are located in Annex 1 of the ICP. A facsimile will be considered written notice for the purposes of this subsection. Failure to notify ecology of significant changes must be considered noncompliance with this chapter and subject to enforcement provisions of chapter 90.56 RCW. If ecology finds that, as a result of the change, the plan no longer meets approval criteria pursuant to WAC 173-180-650, ecology may, at its discretion, place conditions on approval or revoke approval in accordance with WAC 173-180-650. Ecology may also require the plan holder to amend its plan to incorporate the change. Within thirty (30) calendar days of making a change to the prevention plan, the facility owner or operator must distribute the amended page(s) of the plan to ecology and other plan holders. Plans must be reviewed by ecology at least every five (5) years pursuant to WAC 173-180-650. Plans must be submitted for reapproval unless the plan holder submits a letter requesting that ecology review the plan already in ecology's possession. The plan holder must submit the plan or such a letter at least sixty-five calendar days in advance of the plan expiration date. Ecology may require a new review and approval process for a prevention plan following any spill at the facility.

1.14 Conformance with Other Rules and Requirements (§112.7)

Conformance with other applicable requirements and effective discharge prevention and containment procedures (as applicable) in-place at the facility are as follows: 1. This plan incorporates response planning requirements of the Oil Pollution Act (OPA).

Established under the authority of section 311(j) (1) (c) of the Clean Water Act, the Federal Oil Pollution Prevention Program is designed to prevent the discharge of oil to navigable waters and



to contain such discharges when they occur. These requirements are detailed in 40 CFR 112 Appendix F.

2. The requirements for an Emergency Contingency Plan under the U.S. Coast Guard Regulations

33 CFR 154. 3. The requirements of an emergency contingency plan under the Resource Conservation and

Recovery Act (RCRA) 40 CFR Parts 265, Subparts C and D. 4. The emergency procedures required by the Department of Transportation (DOT) as identified in

49 CFR 192.615, 195.402 and similar regulations issued by the state agencies. 5. The Occupational Safety and Health Act requirements for an employee emergency plan and fire

prevention plan as described in 29 CFR 1910.38 and the emergency planning and response requirements according to 29 CFR 1910.119(n) and 29 CFR 1910.120.

6. The Spill Prevention Countermeasures and Control Plan (SPCCP) content requirements for

Class 1 Facilities in Washington as described under Washington Administrative Code, Title 173, Chapter 173-180, Section 173-180-630 (Part F), including the federal requirements under 33 CFR 154, 33 CFR 156, 40 CFR 109, and 40 CFR 112.



SECTION TWO

Detailed Facility Information



2.0 DETAILED FACILITY INFORMATION 2.1 Container and Potential Spill Sources Table (§112.7(a)(3)(i)&(iii), (b), (c))

The potential spills sources (inclusive of containers 55 gallons or more) at the facility are summarized in the following table:

Source (inspection) Contents

Source Capacity

(Bbls) Potential Failure

Rate of Flow

(Bbls/hr) Direction of

Flow Containment System(s)**

Aboveground Fixed Containers (Capacity = Shell volume) Tank No. 1 (API 653)

Gasoline 61,688 Rupture or overfill

61,688 Radial inside secondary containment

Tank farm dike includes an earthen berm and interior cinderblock sub-dike walls with gravel floor.

Tank No. 2 (API 653)




Diesel 9,870 Rupture or overfill



Diesel 35,810 Rupture or overfill


Tank No. 5 (API653)

Ethanol 15,130 Rupture or overfill








Tank No. 9 (STI-SP-001)

Gasoline Additive

266 Rupture or overfill

266 Radial inside secondary containment


Gasoline Additive




Diesel Additive



Concrete containment slab and walls


Gasoline recovered

from Groundwater



Metal containment box within tank farm.

Completely and Partially Buried Tanks / Sumps (Not Covered by 40 CFR Parts 280/281) 15,000-gal spill

containment for Truck

Loading Rack

Stormwater and

potentially gasoline,

ethanol, and diesel.

15,000 gal Leak or rupture

15,000 gal N/A Double-walled tank



Source Contents

Source Capacity

(Bbls) Potential Failure

Rate of Flow

(Bbls/hr) Direction of

Flow Containment System(s)**

Mobile and Portable Containers or Storage Areas Tote Red dye 8 (350

gallons) Rupture or

leakage 8 (350 gal) Radial inside

secondary containment

Tote located inside metal shed with built-in secondary containment in the bottom.

Waste Storage Inside Truck

Loading Rack Area, Connex Container, and Remediation

Systems

Glycol, recovered

product (gas and diesel)

55-gal drum Rupture or spill

55 gal Radial inside secondary

containment

Truck Loading Rack Area: Concrete floor and curbing and strip drains connected to 15,000-gal buried spill containment tank. Connex Container: steel floor and walls. P66 remediation systems: concrete floor and walls.

Oil-Filled Operational Equipment (Transformers, Hydraulic Equipment, etc.) (§112.7(k)) Puget Sound Energy (PSE)-owned Electrical Transformers

Mineral Oil 150 gallons Leakage 150 gallons

Radial on concrete

support pad toward

adjacent unpaved

areas

Secondary containment is not required for PSE transformers and equipment as PSE has a contingency plan which includes an oil response team to quickly respond to their equipment failures. If a leak is identified, the terminal staff shall contact the PSE outage number (888) 225-5773.

Oil-Filled Manufacturing Equipment (Flow-Through Process Equipment) None

Truck or Rail Loading/Unloading Rack Truck Loading

Rack Gasoline,

ethanol, and diesel

400-600 GPM per arm

Overfill or spill

5,000 gal (max truck tanker size)

Toward low-point drains to

spill containment

tank

Sloped concrete curbing with strip connected to a 15,000-gal buried spill containment tank.

Truck or Rail Loading/Unloading Areas Pump-Off Stations

Gasoline, diesel, and

ethanol

200-300 GPM

Hose rupture or

valve failure

300 GPM (600 gal

assume 2 minutes for shutdown)

Toward low-point drains

connected to spill

containment tank

Asphalt and/or concrete pavement and curbing sloped toward low-point drains with valves that are normally closed. When valve is opened, drain is connected to the 15,000-gal spill containment tank.

Additive Unloading

Area

Gasoline Additives

200 -300 GPM (max

rate)

Overflow or spill

600 gallons (assume 2 minutes for shutdown)

Radial inside secondary

containment

Concrete floor and walls with low-point drain with valve that is normally closed. When opened, drain is connected to 15,000-gallon spill containment tank.



Other Potential Spill Sources (Piping, Surface Impoundments, etc.) Olympic Pipeline

Manifolds

Gasoline and diesel

2,400 GPM (max rate)

Overflow or leakage

2,400 gallons

(assume 1 minute for shutdown)

Toward low-point drains

inside secondary

containment

Inside concrete floor and walls with low-point drain with valve that is normally closed. When valve is opened, drain is connected to the 15,000-gallon spill containment tank.

East Ethanol Off-loading

Area

De-Natured Ethanol

17 gallons Valve, flange or

seal leakage

10 gallons Into containment

Curbed concrete pad connected to Olympic Pipeline Manifolds.

West Ethanol Off-loading

Area

De-Natured Ethanol

40 gallons Valve, flange or

seal leakage

15 gallons Into containment

Curbed concrete pad.

Vapor Recovery Unit

Gasoline 50 GPM (max rate)

Rupture or leakage

100 gal (assume 2 minutes for shutdown)


containment

Concrete floor and walls. Low-point drain normally closed.

RM System Equalization

Tank

Process Groundwater with dissolved

product

3,000 gallons Leakage, rupture or overflow

30 gallons influent, 50

gallons effluent


containment

Concrete floor and secondary containment berm.

RM System Fuel Storage

Tankage

Recovered product

150 gallons Leakage or overflow

NA NA Tank is double walled with leak indicator. The tank sits within a concrete floor and secondary containment berm.

197 bbls 25 gallons Into containment

Metal containment box located with main tank farm.

RM System Oil/Water Separator

Process Groundwater with dissolved product and recovered free phase

product

120 gallons Leakage or overflow

25 gallons Radial inside secondary

containment

Concrete floor and secondary containment berm.

Pump Bay Pad Gasoline and diesel

400-600 GPM

Valve failure

1,200 gallons

(assume 2 minutes for shutdown)

Toward low-point drain

inside secondary

containment

Concrete floor and curbing sloped toward low-point drain with valve that is normally closed. When opened, drain is connected to 15,000-gallon spill containment tank

Notes: **See Sec. 2.3.1 for further details on containment systems.



2.2 Bulk Storage Containers 2.2.1 Completely Buried Tanks (§112.8(c)(4))

The facility does not have completely buried metallic storage tanks that were installed on or after January 10, 1974. However, the facility does have one completely buried 15,000-gallon fiberglass spill containment tank near the Truck Loading Rack. The spill containment tank is constructed of double-walled fiberglass, and is designed to hold stormwater that enters the covered areas, as well as product spills that occur within the curbed Truck Loading Rack area. The completely buried tanks are regularly leak tested under the Company’s deadleg program (MI 417).

2.2.1.1 Underground Storage Tanks (§112.1(d)(2)(i))

The facility does not have regulated underground storage tanks (USTs) that are covered by 40 CFR Parts 280/281.

2.2.2 Partially Buried or Bunkered Tanks (§112.8(c)(5))

The facility does not have partially buried or bunkered metallic tanks.

2.2.3 Mobile or Portable Oil Storage Containers (§112.8(c)(11))

Mobile or portable oil storage containers, such as 55-gallon drums and totes, are located at the facility. Designated temporary drum storage areas are inside the Connex container north of the Truck Loading Rack, within the covered and curbed containment area of the Truck Loading Rack, and inside designated containment surrounding the Phillips 66 groundwater remediation system. The primary red dye tote (350 gallons) is located within a dedicated shed (equipped with secondary containment) near the south end of the Truck Loading Rack. The locations of drums and tote are denoted with a “D” symbol on the facility diagrams in Appendix C. Secondary containment for these containers is provided, and is adequately sized to contain the largest single container. If not stored within a covered structure, the containment has sufficient freeboard for precipitation (See Appendix E for calculations). See Sec. 2.1 and 2.3.1 for additional details. Mobile refuelers and other non-transportation-related tank trucks are not present or used at this facility.

2.2.4 Internal Tank Heating Coils (§112.8(c)(7))

The facility does not utilize internal heating coils.



2.2.5 Container Overfill Fail Safe Precautions (§112.8(c)(8) WAC 173-180-330(2))

All bulk atmospheric storage containers are engineered and equipped with the following level monitoring and alarm devices. These systems are designed and installed per design package TSD-9401. The set points for all alarms are determined using the process described in MPR-6023. Product transfers through pipelines at the terminal (e.g., Olympic Pipeline) are monitored via electronic systems measuring flow and alarms to alert facility personnel of any variance. The high liquid level alarm systems are designed to send audible and/or visual signals to the facility control room and/or central control center. Operations personnel will immediately take steps to stop flow into the container. (§112.8(c)(8)(i)) The independent high-high level alarm systems are designed to send audible and/or visual signals to the facility control room and/or central control center and will automatically send a command that immediately will shut-down of the fill/delivery receipt pump(s). (§112.8(c)(8)(ii)) For product transfers within the Truck Loading Rack containment area and/or the adjacent West pump off station, direct audible, light or code signal communication is used between the container gauger and the pumping station. (§112.8(c)(8)(iii)) • Gasoline and distillate loading of tanker trucks within the covered and curbed Truck Loading

Rack area is accomplished by the driver using preset meters. A fiber-optic overfill sensor is provided for each truck compartment to automatically close the meter set/stop control valve before overfill of the truck container can occur.

• Fast response systems are in place terminal for determining the liquid level of each bulk storage

container (i.e. digital computer, telepulse, direct vision gauge). Small loading/unloading operations (e.g., truck loading, product pump off, additive/ethanol unloading) are monitored by the drivers and/or terminal office and can be halted by pushing one of several emergency shutdown switches. (§112.8(c)(8)(iv)).

2.2.5.1 Level Alarm Testing (§112.8(c)(8)(v))

The high and high-high level alarms are tested quarterly in accordance with and the frequencies specified in MPR-6023 that incorporates API RP 2350. These tests are documented on GPL-6023 and maintained on site in accordance with the corporate records management policy.



2.3 Facility Containment, Drainage and Treatment

2.3.1 Secondary Containment Systems (§112.7(c), §112.8(c)(2), (c)(3))

Containment ID

Drainage Method Type of Containment and Material of Construction and/or Active Measure(s)

Containment System Capacity (bbls)

Aboveground Fixed Containers §112.8(c)(2) Tank Farm Manually controlled

gravity drainage to low point collection system and stormwater treatment system.

The Tank Farm is surrounded by an earthen dike or berm wall that provides secondary containment, as well as concrete block sub-dikes around each of the large tanks to enable localized containment of small spills. The floor of the Tank Farm is covered with gravel. Permeability of the tank farm floor is low and stormwater runoff generally pools and stands in low points within each sub-diked area. Stormwater within each sub-dike area ultimately drains to a common collection area. A manually operated valve located just outside the tank farm wall controls gravity flow of stormwater from within the tank farm to a holding tank for storage before discharge through an oil/water separator. The valves are normally closed. Any standing water inside the Tank Farm is visually inspected for the presence of petroleum hydrocarbons. If petroleum hydrocarbons are not detected, the water is allowed to evaporate or drain to the stormwater treatment system (oil/water separator, particulate filters, and carbon polishing). In the event of a spill, the product would be pumped out of the tank farm using portable pumps or vacuum trucks and removed offsite for recycling or proper disposal.

106,036

Tank No. 12 Manually controlled gravity drainage to the spill containment tank.

This tank is surrounded by a concrete wall and slab that provides secondary containment. A manually operated valve located just outside the containment wall controls gravity flow of stormwater to a 15,000-gallon buried spill containment tank on the west end of the Truck Loading Rack. The valve is normally closed and locked. Any standing water inside the containment is visually inspected for the presence of petroleum hydrocarbons. If petroleum hydrocarbons are not detected, the water is allowed to evaporate. In the event of a spill, the product would be pumped out of containment using portable pumps or vacuum truck and removed offsite for recycling or proper disposal.

118

Completely and Partially Buried Tanks (Not otherwise Exempted by Part 112) Spill Containment Tank

Not applicable Buried double-walled fiberglass storage tank with liquid level sensors and high-level alarm.

357



Containment ID



Mobile and Portable Containers or Storage Areas §112.7(c) Drum storage inside Phillips 66 groundwater remediation system

Not applicable Drums are stored on concrete pad inside curbed area and covered with a canopy.

106.9

Red Dye tote storage shed

Not applicable Drums are stored inside dedicated metal shed with built-in secondary containment reservoir.

5.9

RM System Equalization Tank, Fuel Storage Tank, Oil/Water Separator

Float controlled transfer pump

Tank is stored inside of a concrete secondary containment pad.

119.5

Operational Equipment (Transformers, Hydraulic Equipment, etc.) §112.7(c) Vapor Recovery Unit Area

Manually controlled gravity drainage to the stormwater treatment system

Secondary containment for the Vapor Recovery Unit Area is provided by a concrete pad and curbed containment area with a low-point drain that is normally closed. In the event of a spill, the product would be removed by vacuum truck. Any standing water inside containment is visually inspected for the presence of petroleum hydrocarbons. If petroleum hydrocarbons are not detected, the water is allowed to evaporator and/or drain to the water treatment system (oil/water separator, particulate filters, and carbon polishing).

264

PSE-owned Transformers (three)

Not applicable Secondary containment is not required as PSE has a contingency plan to quickly respond to their equipment failures. Call outage number (888) 225-5773. Transformers sit on level concrete pads or are mounted on a pole. Surrounding areas generally consist of flat unpaved areas.

3.6

Oil-Filled Manufacturing Equipment (Flow-Through Process Equipment) Truck or Rail Loading/Unloading Rack §112.8(h)(1)



Containment ID



Truck Loading Rack

Gravity drainage to the buried spill containment tank

The loading rack is covered which limits exposure to precipitation or runoff. Secondary containment is provided by concrete pad and curb with low-point drains that are piped to a 15,000-gallon buried spill containment tank. Any stormwater that gets inside the truck loading rack area will drain to the containment tank. The water from the spill containment tank is either removed by vacuum trucks for offsite treatment/disposal or treated onsite using the air stripper and discharged to the sanitary sewer under the facility's approved wastewater discharge permit to King County Metro Publicly Owned Treatment Works (POTW).

818

Truck or Rail Loading/Unloading Areas §112.7(c) West Pump-off Station

Manually controlled gravity drainage to the buried spill containment tank

Secondary containment for the West Pump-off Station is provided by a concrete slab and asphalt containment berm. The bermed area is graded to direct spills towards the pump containment area and catch basin that drains to the 15,000-gallon spill containment tank. The valves are normally closed. In the event of a spill, the product would be pumped out of the containment area using a portable pump or vacuum truck. Any standing water inside the secondary containment is visually inspected for the presence of petroleum hydrocarbons. If petroleum hydrocarbons are not detected, the water is allowed to evaporate or drain to the 15,000-gallon containment tank. In the event of a spill, the product would be pumped out of the containment using portable pumps or vacuum trucks and removed offsite for recycling or proper disposal.

357

Loading Rack Lane #4 Pump-off Station and Fuel Additive Tank Unloading Area

Gravity drainage to the buried spill containment tank

The loading rack is covered which limits exposure to precipitation or runoff. Secondary containment is provided by concrete pad and curb with low-point drains that are piped to a 15,000-gallon buried spill containment tank. Any stormwater that gets inside the truck loading rack area will drain to the containment tank. The water from the spill containment tank is either removed by vacuum trucks for offsite treatment/disposal or treated onsite using the air stripper and discharged to the sanitary sewer under the facility's approved wastewater discharge permit to King County Metro POTW.

461



Containment ID



Other Potential Spill Sources (Piping, Surface Impoundments, etc.) §112.7(c) Pump Bay Pad Manually controlled

gravity drainage to the buried spill containment tank

Secondary containment for the Pump Bay Pad is provided by a concrete slab and curbing. The bermed area is graded to direct spills towards the pump containment area and catch basin that drains to the 15,000-gallon spill containment tank. The valves are normally closed. In the event of a spill, the product would be pumped out of the containment area using a portable pump or vacuum truck. Any standing water inside the secondary containment is visually inspected for the presence of petroleum hydrocarbons. If petroleum hydrocarbons are not detected, the water is allowed to evaporate or drain to the 15,000-gallon containment tank. In the event of a spill, the product would be pumped out of the containment area using portable pumps or vacuum trucks and removed offsite for recycling or proper disposal.

357

Olympic Pipeline Manifold

Manually controlled gravity drainage to the buried spill containment tank

Secondary containment for the Olympic pipeline manifold is provided by a concrete slab and curbing. The pipeline manifold is covered by a canopy which limits exposure to precipitation or runoff. Any stormwater that gets inside the secondary containment area either evaporates or drains to a low-point collection area. This covered bermed area is graded to direct spills towards the pump containment area and catch basin that drains to the 15,000-gallon spill containment tank. The valves are normally closed. In the event of a spill, the product would be pumped out of the containment area using a portable pump or vacuum truck. Any standing water inside the secondary containment is visually inspected for the presence of petroleum hydrocarbons. If petroleum hydrocarbons are not detected, the water is allowed to evaporate or drain to the 15,000-gallon containment tank. In the event of a spill, the product would be pumped out of the containment area using portable pumps or vacuum trucks and removed offsite for recycling or proper disposal.

357

All bulk storage containers are equipped with secondary containment that will hold the entire capacity of the largest single container with sufficient freeboard to contain precipitation (§112.8(c)(2), WAC173-180-320(4)). See Appendix E for containment volume calculations.



Containment areas (e.g. dikes, containment curbs, catchment basin) are sufficiently impervious to contain discharged oil before cleanup activities begin (§112.8(c)(2), §112.7(c)). Visible discharges which result in a loss of product from containers will be promptly corrected and any accumulations of oil in the containment area(s) will be promptly removed (§112.8(c)(10)). The soils underlying the tank farm consist of silty loam to silty clay loam. Infiltration rates are slow to very slow when the soil is wet. The following table summarizes the USGS Hydrologic information.

Soil Unit Area (%) Type Name Rating*

Pu Puget silty clay loam C/D 13 So Snohomish silt loam C/D 15 Wo Woodinville silt loam C/D 72

* C = Slow, D = Very slow 2.3.1.1 Active Containment Measures (§112.7(c))

Facility: Spill kits are located in the Connex containers near the Truck Loading Rack and Office, near product transfer areas, as well as inside the remediation unit containment area. Each kit can handle an oil spill of 21 gallons. This equipment is regularly inspected per the schedule in Annex 6.4 of the ICP to ensure its functionality and that proper inventories are maintained. Piping: Most facility piping is within secondary containment (inside tank dikes or the loading rack bays) or underground. Flow through the piping is monitored at the facility control room at all times, and piping that is above ground piping is readily visible to facility personnel during normal working day activities. A release from the piping would be addressed immediately by closing valves to the section of pipe that found to be leaking, to minimize the amount released. The piping is not near property boundaries, minimizing the potential for an offsite release. Transfer Areas: Additive and ethanol unloading operations pose a minimal risk as a spill source with the most likely source being a leak at the hose connections. Transport drivers place a bucket or drip pan under the hose connections before unloading begins, and remain present throughout the procedure to stop the operation if a spill or leak occurs. Transformers and Switches: This facility has some electrical transformers on above-ground concrete pads and inside below-ground concrete vaults. The locations of the oil-containing transformers are shown on a figure in Appendix C. Releases from the transformers would flow on to the surrounding flat grass-covered area. There are also some pole mounted transformers inside the facility. Pole-mounted transformers typically contain small quantities of oil (less than 55 gallons). Secondary containment is not required for third party owned (Puget Sound Energy [PSE]) transformers and equipment since PSE has a contingency plan which includes an oil response team to quickly respond to their equipment failures. If an oil leak from an electrical transformer is identified, the terminal staff shall contact the PSE outage



number 1-888-225-5773. Terminal staff may need to use absorbents in nearby spill kits to contain small spills until PSE’s oil response team can respond.

2.3.2 Drainage from Diked Areas Routed to Surface Waters (§112.8(b)(1)&(2))

2.3.2.1 Containment Drainage Inspections (§112.8(b)(1), (c)(3)(ii)&(iv))

Drainage from diked containment areas is controlled by manually operated valves that are normally kept closed. These valves are closed and locked/resealed following drainage. Drainage process for water not directed to treatment system: Prior to discharge of stormwater collected within a dike/containment area, operations personnel observe the water surface for visible sheen or other signs that hydrocarbons may be present. If evidence of oil is observed, the water is not discharged until all sheen/hydrocarbons are removed by use of absorbent materials. In cases where this method is not feasible to remove the contamination on site, the water would be removed for off-site treatment/disposal. When no signs of oil observed and once any sheen/oil has been removed, the valve is opened and the discharge periodically monitored by operations personnel. Once the draining is complete, the drain valve is closed and locked/resealed. Stormwater that collects in a 1,200-gallon stormwater sump located immediately west of the Company’s groundwater treatment equipment compound is controlled by float activated pump that discharges water into the Tank Farm containment area. All discharge events are recorded on the GPL form 565 Secondary Containment Drainage Log.

2.3.3 Effluent Treatment System (§112.8(c)(3)&(9)), 112.8b5

The facility does have a system to treat accumulated rainwater prior to discharge off site. The stormwater treatment system includes the following components: a) underground grit chamber; b) coalescing plate oil/water separator; c) detention basin; d) particulate filters (50 and 100 micron); e) granular activated carbon (GAC) vessels; and f) concrete holding tank. Once in the final concrete holding tank, stormwater is inspected for sheen and foam, and tested for the chemical constitutes listed on the Terminal’s National Pollutant Discharge Elimination System (NPDES) stormwater permit. Upon receipt of test results below the permitted NPDES discharge benchmarks, stormwater is drained from the final concrete holding tank (Outfall #001) to the Spring Brook Creek Wetland, which is a tributary to the Black River located west of the Terminal. The location and direction of flow through the underground stormwater features and conveyance piping is illustrated in blue on the Site Drainage Plan. The contents of the rack spill containment tank (referred to as “process water”) are either removed by vacuum truck and transported off site for treatment/recycling or pumped to a poly-storage tank (slop tank) and treated on site using the air stripper and discharged to the sanitary sewer under the facility's wastewater discharge permit with King County. Samples of process water are collected to ensure compliance with the municipal wastewater discharge permit. The location and direction of flow through the underground process water collection features and conveyance piping are illustrated in red on the Site Drainage Plan.



Bypass valves around the stormwater treatment system are present in event rainfall exceeds the design storm event (25-year, 24-hour storm event). In accordance with the NPDES permit, the terminal O&M manual contains a Stormwater Treatment System Operating Plan (TSOP) that includes the following information:

1. A baseline operating condition, which describes the operating parameters and procedures, used to meet the effluent limits set in Section 1 of the NPDES permit at the production levels used in developing these limits.

2. In the event of production rates, which are below the baseline levels used to establish permit

limits, the TSOP describes the operating procedures and conditions needed to maintain design treatment efficiency.

3. In the event of an upset, due to stormwater treatment system maintenance activities, severe

storm events, startup or shut downs, or other causes, the TSOP describes the operating procedures and conditions employed to mitigate the upset.

4. A description of any regularly scheduled maintenance or repair activity at the terminal which

would affect the volume or character of the wastes discharged at the stormwater treatment system and a plan for monitoring and treating/controlling the discharge of maintenance-related materials (such as cleaners, degreasers, solvents, etc.)

5. Bypass procedures.

2.3.3.1 Drainage from Tank Dikes Through Effluent Treatment System (§112.8(c)(3)) Manually operated valves inside secondary containment systems are always kept closed unless a terminal employee is draining water from the containment system and has visually inspected the accumulated water for evidence of petroleum impact. Any film or oily sheen on the water surface or discoloration is removed by skimming or absorbent pads. The discharge is periodically monitored for sheen or discoloration during the release and the drain valve is closed upon completion. Stormwater is again visually inspected and tested after passing through the stormwater treatment system. If visual inspection or testing results indicate that permit limitations may not be satisfied after passing through the treatment system, the stormwater can be diverted back through carbon canisters for additional polishing. An operator must be present to control operation of the stormwater management system.

2.3.4 Drainage from Facility Undiked Areas to Surface Waters (§112.7(c), §112.8(b)(3))

This facility has the potential to discharge from undiked areas. Containment of such discharges is provided by one or more of the following systems.

• Curbing and low-point drains to spill containment tank. • Sumps and collection systems. • Curbing, gutters, and catch basins connected to the stormwater treatment system.

The above systems were selected based on typical failures and most likely release volume. They are also designed and constructed in such are manner as to contain such a discharge on site before cleanup is initiated.



Stormwater drainage from the Truck Loading Rack and the paved area immediately adjacent to and west of the loading rack is directed to catch basins which ultimately drain to the underground spill containment tank. The contents of the spill containment tank are either removed by vacuum truck and transported off site for treatment/recycling or treated on site using the air stripper and discharged to the sanitary sewer under the facility's wastewater discharge permit. Samples are collected to ensure compliance with permitted effluent limitations. Stormwater drainage from the paved area further to the west of the loading rack is controlled by curbing installed at the southwest corner of the facility’s paved area. Stormwater drainage from the paved area to the east of the loading racks is controlled by curbing and secondary containment wall of the RM treatment system. In the southeast corner, water is directed to a stormwater sump equipped with a submersible sump pump. The pump is normally left off. A visual inspection is completed before pumping the water to a splash pad in the tank dike area. In the event of a spill, a vacuum truck would be used to drain these areas. Additionally, 55-gallon drum spill kits are positioned in the southeast and southwest corners of the facility to control migration in the event of a spill to these areas. Lastly, stormwater drainage from non-transfer/storage areas located in the north side of the facility’s paved area flows to catch basins and then into the municipal storm sewer system. The terminal has a SWPPP and pollution prevention team with specific duties for implementing the following best management practices that include locating spill kits near stationary fueling/fuel transfer stations.

2.3.5 Oil-Filled Operational Equipment (§112.7(k))

The facility does have oil-filled operational equipment, as defined by §112.3. Refer to Section 2.1 for a listing of this equipment and Section 2.3.1.1 for active spill response measures.

2.4 Facility Transfer Operations, Pumping and Facility Processes (§112.8(d))

2.4.1 Facility Below Ground Piping (§112.8(d)(1))

There is a substantial amount of buried piping at the facility. Below ground piping whether coated/wrapped or bare is cathodically protected from corrosion per 40 CFR Part 280 or 281. All below ground piping, new or replacement, installed after August 16, 2002 was coated and/or wrapped (refer to TSP 8002 for coating standard).

2.4.2 Out of Service Piping (§112.8(d)(2)) All out-of-service piping or piping in stand-by/idle for an extended period is capped or blank/blind-flanged.

2.4.3 Pipe Supports (§112.8(d)(3)) All pipe supports are designed in accordance with ASME B31.4 to minimize abrasion and corrosion and to allow free movement for expansion and contraction.



2.4.4 Vehicle Warnings (§112.8(d)(5)) A majority of the above ground piping at the facility is either located within tank dikes, below grade or located outside of normal driving areas. Nevertheless, all vehicle drivers are warned orally by operations personnel before being granted permission to drive in the facility. Within the facility various methods (e.g., bollards signage and barriers) are utilized ensure that no vehicle will endanger aboveground piping or other oil transfer equipment. Spotters are required to direct all vehicles while backing or driving though congested areas.

2.5 Tank Car & Tank Truck Loading/Unloading Rack(s)(§112.7(h)) The Facility does have a tank truck loading/unloading rack.

2.5.1 Tank Car & Tank Truck Containment Systems for Loading/Unloading Rack(s) (§112.7(h)(1))

Loading/unloading rack drainage does flow into a buried 15,000-gallon spill containment tank designed to handle discharges.

The containment system does hold the maximum capacity of any single compartment of a tank truck loaded or unloaded at the rack. The tank truck load/unloading rack containment system is concrete. The perimeter is curbed and trucks drive over speed bumps to load/unload. The entire tank truck load/unloading rack, including Lane 4 pump-off station and additive unloading area, is covered by a roof that prevents precipitation from accumulating within the curbed drainage area. Any leakage or spills occurring within this area would flow by gravity through the settling boxes to the buried fiberglass spill containment tank. The spill containment tank provides 15,000 gallons of containment capacity. The truck rack curbed area adds an additional containment capacity of approximately 19,355 gallons. The total containment volume is approximately 34,355 gallons, which exceeds the 5,000-gallon maximum capacity of any single compartment of a tank truck loaded or unloaded at the Facility.

Refer to the Container and Potential Spills Table in Section 2A.1 for additional details.

2.5.2 Prevention of Premature Vehicular Departure from Truck Rack (§112.7(h)(2)) The methods, procedures, and/or equipment used to prevent premature vehicular departure include:

• Interlocked warning lights • Physical barrier systems • Warning signs • Wheel chocks • Vehicle brake interlock systems

In addition to the above measures, all transport drivers are given site orientation and loading rack training prior to being authorized to load at the facility. Warning signs are posted reminding drivers to disconnect prior to departure.



2.5.3 Prevention of Premature Movement of Rail Tank Cars (§112.7(h)(2)) Tank car (rail) loading/unloading does not occur at the facility.

2.5.4 Drain and Outlet Inspection for Rack(s) (§112.7(h)(3)) Drains and outlets on tank trucks are checked for leakage by truck drivers and/or operations personnel before loading/unloading or departure and, if necessary, are tightened, adjusted or replaced.

2.6 Tank Car and Tank Truck Loading/Unloading Area(s) (§112.7(c)) Tank truck loading/unloading does occur at the facility. Tank car (rail) loading/unloading does not occur at the facility.

2.6.1 Tank Car & Tank Truck Containment Systems for Loading/Unloading Area(s)

The containment system is capable of holding the release volume from the typical failure (Load/unload hose leak) on site. The following measures are part of the containment system:

• Curbing and low-point drains. • Spill containment tank.

Description of Loading/Unloading area operation and controls: Unloading of fuel additives and ethanol occurs within the Lane 4 of the covered and curbed Truck Loading Rack. Unloading or pump-off of product occurs in either Lane 4 of the Truck Loading Rack or within the West Pump-off Station. These infrequent operations are conducted under the direct supervision of terminal staff during normal business hours. Secondary containment is provided concrete pads and curbing and drainage to the buried 15,000-gallon spill containment tank. Refer to the Container and Potential Spills Table in Section 2.1 for additional details.

2.7 Security (§112.7(g)) 2.7.1 Perimeter Security Measures

The facility is fully enclosed by a chain-link fence topped with barbed wire that prevents unauthorized access. Vehicle and personnel access to the facility is limited to the card key controlled gate(s) at all times. Access for visitors is managed through a voice intercom system. All other vehicle gates at the facility are chained and locked. Personnel “crash bar” exit gates are also provided at key points in the perimeter fencing. Security cameras are located throughout the facility and are monitored in the main office/control room.



2.7.2 Master Flow and Drain Valve Security

Both manual and automated valves are present in the facility manifold(s). Operation of the automated valves is monitored and controlled from the facility control room. Valves leading to pressure relieve devices are locked/car-sealed open to prevent leaks due to over pressuring of lines. Valves leading to and from equipment are closed and locked when not in use for an extended period.

All valves at the loading/unloading rack/area not directly handled by transport drives are locked/car-sealed in the appropriate position.

2.7.3 Access to Pumps and Starter Controls

Only qualified operations personnel operate feed/discharge pumps at the facility. All motor starter controls are secured and only accessible by site personnel. Operation of the pumps is monitored within the facility control room and/or MCC. Loading rack and tank pumps are operated automatically through the Accuload® and facility automation systems.

2.7.4 Out-of-Service Loading/Unloading Piping Connections

All loading/unloading connects at the facility are secured by closing/locking valves, locking cap or by installation blind flanges when not in service.

2.7.5 Security Lighting

Lighting is provided throughout the facility, especially at the loading rack and tank farm. Lights are mounted on poles, structures and buildings. Operation of the lighting is controlled through automated timers. The lighting is sufficient deter vandalism and to allow site personnel to directly or indirectly through security cameras to detect discharges

2.8 Inspections, Tests and Records (§112.7(e))

2.8.1 Container Testing and Inspections

2.8.1.1 Above Ground Tanks (§112.8(c)(6))

The Company has a comprehensive Tank/Container Mechanical Integrity Program that follows API653, STI-SP0001 and other appropriate industry standard maintenance inspection processes and schedules. This document and associated maintenance procedures are accessible from the Terminals / Pipelines home page.



All above ground storage tanks are inspected as specified in MI-0310 for all large tanks (≥50,000 gals) and per section 7.3 of MI-325 for smaller tanks. All inspections are performed by qualified operations personnel or qualified equipment inspectors as specified in the above referenced documents. Refer to the Tank Inspection Schedule and Tank Database for specific details on past and future inspection dates. These files can be accessed from the Engineering and Projects / Tank Integrity homepage. Brittle Fracture Evaluation (§112.7(i)) Whenever field-constructed aboveground container subject to API-650, API-12A or API-12C standards undergoes major repairs or alterations per API-653, is reconstruction, or has change in service from hydrocarbons, the container will be evaluated for the risk of discharge or failure due to brittle fracture or other catastrophe. The procedures laid out in MPR 6202 are to be followed for these tests. In addition all tanks storing gasoline are subject to NSPS Kb and/or equivalent State tank inspection regulations. The regulations require routine visual in service inspections and up-close inspections each time a tank is emptied and degassed.

2.8.1.2 Below Ground Metallic Containers (§112.8(c)(4))

As noted in section 2.1, the facility does not have completely / partially buried metallic containers (non-UST’s). The facility does have a completely buried fiberglass spill containment tank. This tank is equipped with liquid level sensors, including high level alarms and an automatic level controlled pump.

2.8.2 Facility Piping Testing and Inspection

Numerous inspection and integrity procedures for piping systems are detailed in the MI-0400 Piping and Pipelines program. All piping systems are evaluated for usage per MI 0417 to determine if any lines are underutilized or that are deadlegs in the system. These classifications indicate piping that is at an elevated risk of internal corrosion. When such piping is found, the mitigation procedures in MI 0417 are followed.

2.8.2.1 Buried Piping Integrity and Leak Testing (§112.8(d)(1))

Integrity and leak testing of the buried piping is performed at the time of installation, modification, construction, relocation, or replacement. All underground piping is tested for leaks as specified in and according to the schedules noted in MI 0415. In addition, any below ground piping is inspected for signs of corrosion by knowledgeable personnel whenever it is uncovered for any reason. The inspection protocols for below ground pipe are provided in MPR 6013 or MPR 6110.

2.8.2.2 Aboveground Piping Examination (§112.8(d)(4))

All aboveground valves and piping (including flange joints, expansion joints, valve glands and bodies, catch pans, pipe supports, locking of valves, and metal surfaces) are regularly examined as detailed below.



All above ground piping is visually inspected by qualified operations personnel and ultrasonically tested according to API 570 requirements by a qualified equipment inspector at the interval noted in MI 410 per the methods given in MPR 6005. These inspections are documented on GPL form 401. Any pipe (above or below ground) that is removed from the facility is internally inspected for evidence of corrosion. Inspection requirements are specified in MPR 6014. Over pressure relief systems are regularly inspected and tested according to MI 610 thru 640 methodologies. Block valves on lines leading to and from the facility and valves within the facility are routinely inspected following the process in MPR 6005 at least annual per MI 410 and documented on GPL-143.

2.8.3 Secondary Containment System Integrity Inspections (§112 Attachment F 1.8.1.3, WAC 173-180-320(1)(h))

Secondary containment inspections are performed monthly and documented on GPL forms 570a thru 570e. These inspections include the following: • Drain valves closed/locked and in good condition • Damage/cracks in walls • Piping penetrations

2.8.4 Other Applicable Inspections (§112.7(e))

A listing of other maintenance, integrity and inspection procedures for the facility are presented in Appendix F.

2.8.5 Documentation (§112 Attachment F 1.8.1)

Records of all inspections and tests (including those maintained under usual and customary business practices) are retained on file according to the Company File Plan. The records can either be viewed in the facility files or in Livelink.


Renton Terminal 09/29/2015

a

APPENDIX A

NOTIFICATION

• Refer to the Integrated Contingency Plan Annex 6 Facility Contacts Agency Contacts Response Contractors Incident Report Form

• Sample Notification Data Sheet • Sample Submittal of Information to Regional Administrator for Qualified Discharge(s)

Contact List and Phone Numbers All facility contacts, as well as, cleanup contractors, Federal, State and Local Agencies and other references are located within Annex 6 of the Integrated Contingency Plan.



a

EXAMPLE Notification Data Sheet



a

Example - Submittal of Information to Regional Administrator for Qualified Discharge(s)

In the event of a qualified discharge or discharges, this page can be utilized to provide official notification to the Regional Administrator. If the facility has had a discharge or discharges which meet one of the following two criteria, then this report must be submitted to the Regional Administrator within 60 days. (Check as appropriate)

This facility has experienced a reportable discharge as described in §112.1(b) of 1,000 gallons or more.

This facility has experienced two (2) reportable discharges (as described in §112.1(b) of greater than 42 gallons each within a 12-month period.

Facility name and location:

Facility contact person (Name, address/phone number):

Facility maximum storage or handling capacity:

Facility normal daily throughput:

Describe the corrective action and countermeasures taken (include description of equipment repairs and replacements): Describe the facility (attach maps, flow diagrams and topographical maps as necessary): Describe the cause of discharge (as described in §112.1(b)) including failure analysis of the system or subsystem in which the failure occurred:

Describe the additional preventive measures taken or contemplated to minimize the possibility of recurrence: Other pertinent information:

● A copy of this report is also to be sent to the appropriate state agency in charge of oil pollution control activities.



a

APPENDIX B

LOGS

The Following Inspection forms can be located on the Pipelines and Terminals Integrity and Reliability Governance Page External Inspection Checklist • Terminal and Station Piping, GPL-401 • Aboveground Storage Tanks (Atmospheric), Monthly Routine In-Service Inspection,

GPL-199 • Annual Tank Inspection Report, GPL-205 • Annual Secondary Containment Inspection logs, GPL-570a - e • Secondary Containment Drainage log, GPL-565 Additional testing and inspection logs are listed in Appendix F The following Training Roster can be located in Livelink: • TPTN – Information Library Document code 35900100 • Spill Prevention Briefing and SPCC Review http://livelink.phillips66.net/livelink.exe/open/35900100

http://livelink.phillips66.net/livelink.exe/open/35900100


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a

APPENDIX C

Facility Diagram §112.7(a)(3)



a

APPENDIX D

Oil Spill Contingency Plan §112.7(d)(1)

Current EPA Approval Letter

Refer to stand alone Integrated Contingency Plan (ICP) Binder



a

APPENDIX E

Containment Volume Calculations §112.7(h)(1), §112.8(c)(3)

Phillips 66 Renton TerminalSPCC Plan

APPENDIX ESECONDARY CONTAINMENT CALCULATIONS

By Kurt Harrington PEAmec Foster Wheeler

P66 Remediation System Product Holding Tank

1. Total Dike Volume

Concrete Containment Specifications: Volume of tankage: 3,270 gallonsl = 44 feet length

w = 30.5 feet width Tank #1 = 3000 gal water settling tankh = 0.5 feet wall height Tank #2 = 150 gal recovered fuel tank

Tank #3 = 120 gal oil/water separatorFormula: Containment Volume = l * w * h

Calculation: Reservoir Volume = 671.0 ft3

5,019.4 galLess Equipment Deductions = 3,940.0 gal

2. Proof

Question: Available Containment Volume : 3,940 gal > Volume of tankage: 3,270 gaL

Answer: Yes

Renton Terminal

Tank Number

Tank Contents

Tank Height(FT)

Tank Diameter (FT)

Tank Radius(FT)

Total Volume1

(Gal)Total Barrels2

(42 Gal/Barrel)1 Gasoline 40 105 53 2,590,875 61,688 2 Gasoline 40 93 47 2,032,515 48,393 3 Diesel #2 40 42.5 21 414,540 9,870 4 Diesel #2 40 80 40 1,504,000 35,810 5 Ethanol 40 52 26 635,440 15,130 6 Gasoline 40 70 35 1,151,500 27,417 7 Gasoline 40 95 48 2,120,875 50,497 9 Gasoline Additive 23.5 9 5 11,183 266 10 Gasoline Additive 17 8 4 6,392 152 12 Diesel Additive 12.17 7 4 3,503 83 13 Gasoline Recovered from Groundwater 22 8 4 8,272 197

1Conversion factor of 7.48 U.S. Gal/CF2Based on Gallons of Crude Oil Per Barrel CF = CFGal = GallonsFT = Feet

TABLE E-1Phillips 66 Renton Terminal

Refined Products Storage Tank Data

SourceContainer

IdentificationSubstance Stored/

Transferred Potential Modes of Failure Volume (gallons) or Rate of Flow (gpm) Direction of Flow Containment Systems

Tank Farm Storage Tank 1 Gasoline Rupture, Leak at Valve, or Overfill 2,590,875Storage Tank 2 Gasoline Rupture, Leak at Valve, or Overfill 2,032,515Storage Tank 3 Diesel #2 Rupture, Leak at Valve, or Overfill 414,540Storage Tank 4 Diesel #2 Rupture, Leak at Valve, or Overfill 1,504,000Storage Tank 5 Ethanol Rupture, Leak at Valve, or Overfill 635,440Storage Tank 6 Gasoline Rupture, Leak at Valve, or Overfill 1,151,500Storage Tank 7 Gasoline Rupture, Leak at Valve, or Overfill 2,120,875Storage Tank 9 Gasoline Additive Rupture, Leak at Valve, or Overfill 11,183Storage Tank 10 Gasoline Additive Rupture, Leak at Valve, or Overfill 6,392Storage Tank 13 Gasoline Recovered from GrounwaterRupture, Leak at Valve, or Overfill 8,272Tank No. 12Storage Tank 12 Diesel Additive Rupture or Overfill 3,500 Inside containment Secondary containment is provided by concrete wall (2.17 feet high) and slab

(square footage 302.54); total containment capacity is 4,952 gallons. Details of the available containment are provided on the attached worksheet.

Truck Loading RackTruck Loading Rack N/A Gasoline and distillate Truck/trailer overfill 600 gpm (maximum) Maximum overvill volume

estiamted to be 600 gallons, assuming a 1 minute detection and shutdown time.

Inside containment

Compartment rupture Inside containmentTank Truck Pump-Off StationsLoading Rack Lane #4 Pump-off Station

N/A Gasoline additives and ethanol Hose rupture or valve failure 300 gpm (maximum); Maximum spill volume estiamted to be 600 gallons assuming a 2 minute detection and shutdown time.

Inside containment Gasoline additive and ethanol unloading occurs near the off-loading area near lane #4 of the Truck Loading Rack (i.e. loading rack lane #4 pump-off station). The loading rack lane #4 Pump-off station is equipped with a catch basin within the pump containment area that diverts drainage to the loading rack's 15,000-gallong underground spill containment tank. Spills at the station would be contained within the pump containment area and within the capacity to contain the largest forseable spill of 3,800 gallons.

Compartment rupture 3,800 gallons (maximum compartemnt size) Inside containmentWest Pump-off Station N/A Ethanol, diesel additive, and partial

loads of gasoline and distillatesHose rupture or valve failure 300 gpm (maximum); Maximum spill volume

estiamted to be 600 gallons, assuming a 2 minute detection and shutdown time.

Inside containment Unloading of ethanol, diesel additive, and partial loads at the West Pump-off station occurs within a concrete slab and asphalt containment berm. The bermed area is graded to direct spills towards the pump containment area and catch basin that drains to the Truck Loading Rack spill containment tank. The loading rack spill containmnet tank has enough capacity to contain the largest foreseeable spill of 3,800 gallons.

Compartment rupture 3,800 gallons (maximum compartemnt size) Inside containmentVapor Recovery Unit AreaVapor Recovery Unit Area N/A Gasoline Leak at Pump or Piping 50 gpm (maximum rate); maximum spill

estimated to be 100 gallons assuming a 2-minute detection/response/shut down time.

Inside containment Secondary containment is provided by a concrete wall (0.9 feet high) and slab (square footage 1,882.4); total containment capacity is 12,672 gallons. Details of the available secondary containment are provided on the attached worksheet.

Hazardous Waste Storage AreasDrum and Tote Storage N/A Hazardous and non-hazardous

wasteDrum failure 55 to 350 gallons See Figure RENT-EV-0001

Inside containmentDrums waste and totes of red dye are stored inside the truck loading rack containment area or portable storage units (ie., Conex shipping containers) located at various locations on the Terminal. The primary the red-dye tote is located inside a shed with built-in containment. Also, producting holding tanks associated with the groundwater remediation systems (BP system and P66 system) are located within designated concrete containment areas. Details of available secondary containment for the primary red-dye tote inside the shed, as well as the remediation system product holding tanks, are provided on the attached worksheets.

Olympic Pipeline ManifoldPipeline Leak or rupture N/A Gasoline and distillate Pipeline leak/rupture 2,400 gpm (maximum transfer rate); spill

volume variableInside containment The majority of piping at the Renton Terminal is aboveround except where pipelines

run underground to the pipeline manifold. The pipeline manifold is surrounded by concrete curbing and slab, with low-point drains that are connected to a 15,000-gallon spill containment tank. All aboveground piping is protected from corrosion by periodic painting. Underground piping is protected from corrosion by plastic coating. Pipe supports are designed to minimize abrasion and corrosion and to allow for expansion and contraction. Pipelines are supported by earthquake braces. Pipe and connections are capped or blind-flanged and if the line is not in service or is on standby for extended periods. Piping and associated equpment is visually inpsected daily for weeps and leaks during the normal course of operations. Any deficiencies found are corrected as soon as possible.

TABLE E-2Phillips 66 Renton Terminal

Spill Scenarios and Containment Systems

Tank farm earthen dike (7.2 feet high); total containment capacity of the tank farm (total area inside tank farm dike minus the total areas of all the tanks except the largest) equals 106,036 barrells (Bbls). Details of available secondary containment are provided on the attached worksheet.

5,000 gallons (maximum load setting for a compartment load); 3,800 gallons (maximum compartemnt size)

Secondary containment at the Truck Loading Rack is provided by concrete curbing and slab and low-point strip drians that are connected to a 15,000-gallon spill containment tank. Gasoline and disitillate loading is accomplished by the driver using preset meters. A fiber-optic overfill sensor is provided for each truck compartment to automatically close the meter set/stop valve for each truck compartment to automatically close the meters set/stop valve before an overflow can occur. To prevent premature vehicle departure, trucks are equipped with an air switch that locks the trucks brakes until the vapor hose is disconnected. Drains and outlets on the tank trucks are checked for leakage before loading and departure. Loading oeprations can be halted by pushing one of several emergency shutdown switches. Drivers are trained prior to being allowed to load and are present throughout all loading operation. Loading operations are monitred by the terminal office and can also be shutdown or halted from the terminal office. Details of the available secondary containment are provided on the attached worksheet.

See Figure RENT-EV-0002Inside containment



By Kurt Harrington, PEAmec Foster Wheeler

AmecFW Project Number 561M122133 Page 4 of 9 10/14/2015

Tank Farm

1. Total Area within Containment Berm if No Tanks are PresentThe area is broken up into two rectangular areas and two triangular areas, as follows,Area 1: Rectangle

Berm Length (lu) = 390 FT Wall Lengths measured on 2/1/12Berm Width (wu) = 240 FT Average Length of Front Slope Face, Measured at Corners

Formula: Total Area (A u )= (l u * w u )

Calculation: Au = 93,600 SF

Area 2: RectangleBerm Length (lv) = 95 FT Wall Lengths measured on 2/1/12Berm Width (wv) = 165 FT Average Length of Front Slope Face, Measured at Corners

Formula: Total Area (A v )= (l v * w v )

Calculation: AV = 15,675 SF

Area 3: TriangleBerm Length (lw) = 95 FT Wall Lengths measured on 2/1/12Berm Width (ww) = 70 FT Average Length of Front Slope Face, Measured at Corners

Formula: Total Area (A w )= (1/2 * l w * w w )


Area 4: RectangularBerm Length (lx) = 60 FT Wall Lengths measured on 2/1/12Area Width (wx) = 50 FT Average Length of Front Slope Face, Measured at Corners

Formula: Total Area (A x )= (1/2 * l x * w x )


TOTAL OVERAL AREA INSIDE BERM Total Area (A T )= (A u + A v + A w + A x )

A T = 114,100 SF

2. Total Volume Available Inside Berm (Ignoring Slope Face)

Berm Height (hw1 = (l2 - w

2)1/2) = 7.2 FT Based on Front Face Length and Width of Slope = Width (w) in FT 4.5 Face Length (l) in FT = 8.5

Formula:

Calculation: Volume Unocupied (Vo) = AT * hw1

Volume Unoccupied (Vo) = 822,787 CF

3. Berm Occupied Volume Inside Berm

Berm Height (hw1 = (l2 - w

2)1/2) = 7.2 FT Based on Front Face Length and Width of Slope = Width (w) in FT 4.5 Face Length (l) in FT = 8.5

Formula: l Cross-Sectional Area of Berm (A c )= (1/2 * hw1 * w)

Calculation: Ab = 16 SF

Total Berm Length (lb) = 1,470 LF

Volume Occupied by Berm Face (Vb) = 23,851 CF

4. Total Available Volume within Containment Wall (Including Occupied Berm Volume)

Formula: Unoccupied Volume (V u )= (V o ) - (V b )

Calculation: Vu = 798,936 CF

5. Volume Within Containment Wall Covered By Tanks, Under Scenario #1





Tank Base Areas Within Containment Wall:Tank Number

Tank #1 (A1) 105 FT 8659.0 SF See Table E-1 Largest Tank, Not Included in Total Area BelowTank #2 (A2) 93 FT 6792.9 SF See Table E-1Tank #3 (A3) 42.5 FT 1418.6 SF See Table E-1Tank #4 (A4) 80 FT 5026.5 SF See Table E-1Tank #5 (A5) 52 FT 2123.7 SF See Table E-1Tank #6 (A6) 70 FT 3848.5 SF See Table E-1Tank #7 (A7) 95 FT 7088.2 SF See Table E-1Tank #9 (A8) 9 FT 63.6 SF See Table E-1Tank #10 (A9) 8 FT 50.3 SF See Table E-1

Tank #13 (A10) 8 FT 50.3 SF See Table E-1

Scenario #1: Assumes Largest Tank, Tank #1 Ruptures, All Other Tanks Remain IntactFormula: (A 2 +A 3 +A 4 + A 5 + A 6 + A 7 + A 8 + A 9 + A 10 ) * ((h w1 + hw2) /2)

Calculation: Total Tank Base Area = 26,463 SF Note: Does Not Include Tank #1 (Largest)Vt= 190,825 CF

6. Rainfall Captured Within Containment Wall

Formula: Rainfall Volume = (A u ) * (Maximum Rainfall)where:

Calculation: Rainfall Volume = 12,168 CF

7. Total Volume Removed from Storage with Addition of Rock Base

673.5 CF

Assumption: 0.15

Formula: V IR * (1 - n)

Calculation: 572 CF

8. Available Volume Within Containment Wall

Formula: Available Containment Volume in CF (V a )= V u - (V t + Rainfall Volume + V R )Available Containment Volume in Bbls (V a1 )= V a * 0.1781 Bbls/CF

Calculation: Va = 595,371 CFVa1= 106,036 Bbls

9. Proof

Question: IsAvailable Containment Volume (Va1) : 106,036 Bbls

>Volume of largest tank (Tank#1) : 61,688 Bbls

Answer: YesAmount of Extra Capacity Under Scenario #1: 44,348 Bbls

Tank Base Diameter Tank Base Area

Volume Ocuppied by Additional Rock Base (V R ) =

Volume of Imported Rock (VIR) =

Porosity (n) =

VR =

Total Tank Base Volume Remaining Within Containment Wall (V t ) =

Maximum Rainfall = 1.61 IN or 0.13 FT2-Year, 24-Hour Rainfall Amount for USGS station; Stormwater Management Manual for Western Washington





Tank No. 12The area is composed of a rectangular area1. Total AreaArea 1: Area is Rectangular

Wall Length (lw1) = 22.6 FTWall Width (ww1) = 13.5 FT

Average Curb Height (hw1) = 2.2 FT Assumes 2-ft curbed storage height available across the pavement

2. Total Storage Capacity within Pump-Off Area

Formula: Total Volume (V u )= (l w1 * w w1 * h w1 )

Calculation: Vu = 662 CFVu = 4,952 Gallons

3. Max Volume Assumed to be spilled within containment

Tank No. 12 3,500 Gallons

Total Spill Volume: 83 Bbls

4. Proof

Question: IsAvailable Containment Volume (Va1) : 118 Bbls

>Volume of largest tank (Tank#12) : 83 Bbls

Answer: YesAmount of Needed Capacity Under Scenario #1: 35 Bbls

Secondary containment is equipped with a low-point drain that is connected to the 15,000-gallon spill containment tank.





Truck Loading RackThe Fuel Rack Composed of Four Lanes1. Total Area within Containment WallArea is broken up into 4 zones: All measurements collected Lane 1: Area is Rectangular

Wall Length (lw1) = 90 FTWall Width (ww1) = 12 FT

Average Curb Height (hw1) = 0.7 FT

Lane 2: Area is RectangularWall Length (lw2) = 90 FTWall Width (ww2) = 12 FT

Average Wall Height (hw2) = 0.5 FT Depth varies across fueling bay and has a roll-over curb that is an average of 6 inches in depth.


Average Wall Height (hw3) = 0.5 FT Depth varies across fueling bay and has a roll-over curb that is an average of 6 inches in depth.


Average Wall Height (hw4) = 0.6 FT

2. Total Volume within Containment Wall

Formula: Total Volume (V u )= (l w1 * w w1 * h w1 ) + (l w2 * w w2 * h w2 ) + (l w3 * w w3 * h w3 ) + (lw 4 * ww 4 * hw 4 )

Calculation: Vu = 2,588 CFVu = 19,355 Gallons 34,354.5 818.0

3. Max Volume Assumed to be contained within the fuel rack area, Scenario #1

Maximum Tank Volume: 5,000 gallons See Table E-1

4. Proof


>Tanker truck tank volume (See Table E-1) : 119 Bbls

Answer: YesAmount of Extra Capacity Under Scenario #1: 342 Bbls

Depth varies across fueling bay and has a roll-over curb that is an average of 8 inches in depth in the center and 6-inch rollover curb.

Depth varies across fueling bay and has a roll-over curb that is an average of 8 inches in depth in the center and 6-inch rollover curb.





Vapor Recovery Unit (VRU) Containment AreaThe area is composed of a short walled, rectangular area1. Total AreaArea 1: Area is Rectangular

Wall Length (lw1) = 52 FTWall Width (ww1) = 36.2 FT

Average Curb Height (hw1) = 0.9 FT

2. Storage Capacity within VRU Area

Formula: Volume (V u )= (l w1 * w w1 * h w1 )

Calculation: Vu = 1,726 CFVu = 12,907 Gallons

3. Rainfall Captured Within Containment Wall

Formula: Rainfall Volume = (A u ) * (Maximum Rainfall)where:

Calculation: Rainfall Volume = 245 CF

4. Storage Capacity During Rain Event

Formula: Total Volume (V T )= (V u - Rainfall)

Calculation: Vu = 1,481 CFVu = 11,077 Gallons

5. Max Volume Assumed to be spilled within the VRU area, Scenario #1

Spill Response Time: 2 MinutesAverage Pump-off Rate: 50 Gallons Per MinuteTotal Spill Volume: 100 Gallons

6. Proof


>Volume Expected in Scenario #1 : 2 Bbls

Answer: YESAmount of Needed Capacity Under Scenario #1: 261 Bbls

Maximum Rainfall = 1.61 IN or 0.13 FT2-Year, 24-Hour Rainfall Amount for USGS station; Stormwater Management Manual for Western Washington




AMEC Project Number 561M122133 Page 9 of 9 10/14/2015

Red Dye Storage Shed

1. Total Dike Volume

Shed Specifications: Shed is Rectangular with Base Volume of tote: 250 gallonsl = 10 feet length 33.4 ft3

w = 4 feet widthh = 0.8 feet height of base reservoir

Formula: Reservoir Volume = l * w * h

Calculation: Reservoir Volume = 33.3 ft3

249.4 gal2. Proof

Question: Available Reservoir Volume : 33 ft3 > Volume of tote: 33 ft3

Answer: Yes Exactly the amount of the tote for capacity, however the Tote is contined in the Fuel Rack Area.



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APPENDIX F

Maintenance, Inspection and Integrity Standards

§112.7(e), §112.8(c)(6), §112.8(d)(4)



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List of Inspection and Integrity Standards

The following is a list of inspection/integrity standards that are applicable to all Terminals and applicable Stations. These documents are amended and updated regularly. During these updates, changes to ID numbers or Titles are rare, but possible. The full text of the current version of the standards can be accessed on the Policies, Manuals and Forms section of the Pipelines or Terminals Home Pages. Coatings and Corrosion: MI 0500 – Corrosion MPR 4105 – Cleaning and Coating of Buried Pipe MPR 7003 – External Corrosion

TSP 8004 – External Protective Paint Coatings for On Shore Above-Grade Tanks, Vessels, Piping, Standard Equipment & Structural Steel

Cathodic Protection: MPR 6015 – Inspection: Rectifier Inspection, Testing and Installation

MPR 6016 – Inspection: Interference Bonds, Reverse Current Switches, Diodes, Electrical Insulators

MPR 6018 – Inspection: Annual Cathodic Protection Testing MPR 6019 – Inspection: Inspection of Bare Pipe Without Cathodic Protection

MPR 7002 – Corrosion Control – Cathodic Protection Requirements Mechanical Integrity: Tankage: MI 0310 – Atmospheric Storage Tank Program MI 0325 – Small Atmospheric Storage Tank Program GPL-6101 – Annual Small Tank Inspection Report

GPL-6102 – Small Aboveground Storage Tanks (Atmospheric) – Monthly Routine In-Service Inspection Report

MPR 6008 – Inspection and Testing, Aboveground Storage Tanks, Pressure Vessels, and Piping Inspection Schedules

MPR 6203 – Aboveground Atmospheric Storage Tanks Visual Inspection GPL-199 – Monthly Above Ground Storage Tank Inspection Report GPL-205 – Annual Above Ground Tank Inspection Report and instructions MPR 6023 – Inspection and Testing, Overfill Protection Systems GPL-6023 – Inspection and Testing Report MPR 6202 – Hydrostatic Testing – Atmospheric Storage Tanks GPL-357 – Atmospheric Storage Tank – Hydotest Report Piping and Appurtenances: MI 0410 – Piping and Pipelines, Piping for Hydrocarbons MI 0415 – Buried Piping Assessment Program

MPR 6013 – Inspection and Testing – Buried Pipe Inspection



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eForm 3933 – Pipeline Maintenance and Leak Report MI 0417 – Deadleg and Underutilized Piping Program MI 600 - Pressure Control Devices MPR-4226 – Thermal Pressure Device Installation and Maintenance GPL-122B – Inspection form for Thermal Pressure Devices MPR-4218 – Installation and Maintenance – Pressure Relieving Devices

MPR-4225 – Inspection and Maintenance of Pressure Regulation Systems GPL-122 – Pressure Control Device Inspection Form MPR 6005 – Inspection and Testing – Block Valve Inspection GPL-143 – Valve Inspection Record MPR-6110 – Leak Testing – Low-Stress Facility Piping Systems

MPR 6013 – Inspection and Testing – Buried Pipe Inspection eForm 3933 – Pipeline Maintenance and Leak Report

MPR 6014 – Inspection and Testing – Internal Inspection on Removed Pipe eForm 3933 – Pipeline Maintenance and Leak Report

MPR 6020 – Inspection and Testing, Inspection of Spans and Above Ground Piping

GPL-401 – External Inspection Checklist for Terminal and Station Piping Form 15597N – Span and Exposed Piping Inspection Report

TPO 3002 – Sump Level Alarm Policy

GPL-511 - Sump Level Alarm Inspection and Testing Report



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Brief Description of

Inspection and Integrity Standards Coatings and Corrosion: MI-0500 – Corrosion Overview and description of Company corrosion (internal and external) prevention and control processes and measures for piping and tankage. Brief details on each procedure/process are provided along with MPR document and GPL form numbers. MPR-4105 – Cleaning and Coating of Buried Pipe Describes to process of cleaning and preparation of new and existing piping prior to application of coatings on new and the repair of coatings existing pipe. MPR-7003 – External Corrosion Reference for the selection of the correct procedure for external inspections of piping and cathodic protection systems. The sections briefly describe the equipment to be inspected and the respective inspection procedure. TSP 8004 – External Protective Paint Coatings for On Shore Above-Grade Tanks, Vessels, Piping, Standard Equipment & Structural Steel Sets the coating specifications and standards for all above-grade surfaces Cathodic Protection: MPR-6015 – Rectifier Inspection, Testing and Installation Outlines the responsibilities, requirements and procedures for installation, inspection and maintenance of this key cathodic protection system component. MPR-6016 – Inspection and Testing of Interference Bonds, Reverse Current Switches, Diodes, Electrical Insulators Outlines responsibilities, requirements and procedure details for the Inspection and testing of interference bonds, reverse current switches, and diodes, as well as inspection and testing of electrical isolators. Inspection/maintenance frequencies for the various devices are given. MPR-6018 – Cathodic Protection Testing Outlines the frequency, responsibilities, and procedures for conducting annual cathodic protection system testing on pipelines and facilities. MPR-6019 – Inspection of Bare Pipe Without Cathodic Protection Outlines the frequency, responsibilities, and procedures for the inspection and evaluation of bare pipe. MPR-7002 – Corrosion Control – Cathodic Protection Requirements Provides the detailed processes and requirements for cathodicaly protecting buried facility piping, coated and uncoated.



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Mechanical Integrity: Tankage: MI-0310 – Atmospheric Storage Tank Program Company philosophy on tank integrity and description of external and internal inspection procedures for storage tanks. The inspection program meets the requirements of API-653. MI-0325 – Small Atmospheric Storage Tank Program Company philosophy on small tank (<50,000 gal) integrity and description of external inspection procedures. The inspection program meets the requirements of STI-SP0001. MPR-6008 – Inspection and Testing, Aboveground Storage Tanks, Pressure Vessels, and Piping Inspection Schedules Presents the inspection frequencies for equipment and the respective individual procedures, as well the qualifications and responsibilities of those performing the work. MPR 6203 – Aboveground Atmospheric Storage Tanks Visual Inspection Provides the instructions for performing and documenting the tank inspections on GPL-199, as well as the qualifications and responsibilities of those performing the work.

GPL-199 – Monthly Above Ground Storage Tank Inspection Report

GPL 205 – Annual tank inspection report and instructions for completing form GPL-205 - Annual Tank Inspection Report

MPR-6023 – Inspection and Testing, Overfill Protection Systems Outlines the procedures for inspecting the overfill protection systems on storage containers/vessels (HVL materials), as well as the qualifications and requirements of those performing the work. The inspections results are documented on TPO-4001.

GPL-6023 – Inspection and Testing Report

MPR-6202 – Hydrostatic Testing – Atmospheric Storage Tanks Describes the procedures and protocols for the non-destructive testing all storage tanks. The training, requirements and qualifications for those performing the work is also detailed. Testing results are documented on GPL-357.

GPL-357 – Atmospheric Storage Tank – Hydotest Report MPR-6023 – Atmospheric Storage Tank Level Alarm Policy Outlines the company policy for level monitoring and details the process by which tank levels are determined and the corresponding alarms are set for storage tanks. The document also describes the emergency shutdown systems triggered at high and high-high levels. Inspection frequencies and requirements are also presented. The results of the periodic testing and inspections are documented on Form GPL-6023

GPL-6023 – Inspection and Testing Report

TPO-4001 – Atmospheric Storage Tank Level Alarm Policy Outlines the company policy for level monitoring and details the process by which tank levels are determined and the corresponding alarms are set for storage tanks. The document also describes the



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emergency shutdown systems triggered at high and high-high levels. Inspection and Testing of the equipment is detailed in MPR-6023 and documented on GPL-6023.

GPL-6023 – Level Alarm Inspection and Testing Report

Piping and Appurtenances: MI-0410 – Piping and Pipelines, Piping for Hydrocarbons Describes the mechanical integrity program for all piping in hydrocarbon service. A brief description of the methods used to inspect above and below ground piping is given along the associated maintenance and inspection procedures.

MPR-6008 – Inspection and Testing, Aboveground Storage Tanks, Pressure Vessels, and Piping Inspection Schedules Presents the inspection frequencies for equipment and the respective individual procedures, as well the qualifications and responsibilities of those performing the work. GPL-401 – External Inspection Checklist for Terminal and Station Piping

MI-0415 – Facility Buried Piping Integrity Program Outlines the criteria used for assessing the integrity of buried piping within a facility based on established industrial practices and standards. MI-0417 – Deadleg and Underutilized Piping Program Outlines the process by which the integrity of underutilized and deadleg piping is assessed and the mitigation actions used to address these piping systems. This program is designed to locate and reduce the potential for releases from such piping. MI-0600 – Pressure Control Devices Pressure Control Devices – Thermal Pressure Relieving Devices Overview the company process around the installation and inspection of thermal pressure devices. MPR-4226 – Thermal Pressure Device Installation and Maintenance

Outlines the procedures for the inspection of and periodic maintenance on devices that relief excess pressure created by heating of the fluid contained in piping system. Details the requirements for and qualifications of those performing the inspections. These inspections are documented in GPL-122B.

GPL-122B – Inspection form for Thermal Pressure Devices

MPR-2817 – Instructions for completing GPL-122 (covers 122B) Pressure Control Devices – Pressure Relieving Devices and Control Systems Outlines the company maintenance and inspection requirements for pressure relief devices installed on atmospheric tanks, pressure vessels and piping systems. The respective maintenance/inspection procedures are briefly described. MPR-4218 – Installation and Maintenance – Pressure Relieving Devices

The document briefly describes the installation, inspection and testing frequencies, and testing and maintenance procedures for these devices. References to all relevant MPRs and respective inspection forms are presented in section 7 and Appendix A.



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MPR-4225 – Inspection and Maintenance of Pressure Regulation Systems Details the inspection of and maintenance on devices and systems that regulate pressure in pipelines and piping systems. Describes the maintenance and calibration of the devices as well as the requirements for and qualifications of those performing the work. The results if these inspections are documented on GPL-122.

MPR 6005 – Inspection and Testing – Block Valve Inspection Outlines the company maintenance and inspection requirements for DOT and Non-DOT block valves installed on company pipelines. Procedure also covers the inspection of critical vales within terminals and other Non-DOT facilities. The document details the requirements and qualifications for those performing in the work. Inspection details are recorded on GPL-143. MPR-6110 – Leak Testing – Low-Stress Facility Piping Systems Describes various methods used for leak testing of facility piping (above and below ground). Testing includes pump head, static tank head and hydrostatic pressure testing as well use of tracer gases. MPR 6013 – Inspection and Testing – Buried Pipe Inspection Details the inspection process performed whenever buried piping is exposed for any reason. Provided the prerequisites for the inspections and the requirements for and qualifications for those performing the work. The inspection results are documented on eForm 3933. MPR 6014 – Inspection and Testing – Internal Inspection on Removed Pipe Describes the process for the inspection of all pipe segments that have been removed from pipelines. References to associated procedures are given along with the requirements and training for and qualification of those performing the work. Results of the inspections are documented on eFrom 3993 MPR 6020 – Inspection and Testing, Inspection of Spans and Above Ground Piping Describes in detail numerous inspection processes to be performed on all above ground piping systems per defined inspection frequencies. The requirements and training for and qualifications of those performing the work are also provided. The inspections on facility piping are documented on GPL-401. For piping outside on a facility, form 15597N is used to document the inspections. GPL-401 – External Inspection Checklist for Terminal and Station Piping Form 15597N – Span and Exposed Piping Inspection Report TPO 3002 – Sump Level Alarm Policy Outlines the company policy for level monitoring and details the process by which below ground sumps and tank levels are determined and the corresponding alarms settings. The document also describes the emergency shutdown systems triggered at high and high-high levels. Inspection frequencies and requirements are also presented. The results of the periodic testing and inspections are documented on GPL-6023 Pressure Control Device – Pressure Alarm Devices States the company’s use of pressure alarm equipment to alert personnel of pressure transients in piping systems.

MPR-4216 – Installation and Maintenance – Calibration and Maintenance of Pressure Switches Details the inspection, maintenance and calibration requirements for pressure switches installed on pipelines and facility piping systems. Inspections and calibration data are recorded on GPL-122

MPR-2817 – Instructions for completing GPL-122



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APPENDIX G

Example Personnel Training Schedule

WAC 173-180-630(8)

SAMPLE ONLY

Current Training matrix available from Learning Management System Administrator by request.

New ID #

New Phillips 66 Covered Task

Content Owner

Priority High: 1st 2 MonthsMedium: 1st 4 MonthsLow: By end

CategoryRefresher Frequency

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LEGEND: REQ = Required (Pushed by Assignment Profile) IND = May be required of certain individuals (NOT Pushed by Assignment Profile) N/A = Not Applicable to this group

Assigned to ALL P&T Employees and Contractors in the LMS

MDSHAZWOPERIC MDS - HAZWOPER Incident Command System Emergency Response

High Emergency Response Initial REQ REQ

MDSHAZWOPERINI MDS - HAZWOPER Initial Emergency Response

High Emergency Response Changes REQ REQ

MDSHAZWOPERQIICMDS - HAZWOPER Qualified Individual (QI) and Incident Commander (IC) (Transportation ER)

Emergency Response

High Emergency Response Changes IND REQ

MDSHAZWOPERTECH

MDS - HAZWOPER Technician Level Initial Emergency Response

High Emergency Response Annual REQ REQ

MDSHAZWOPERTECHR

MDS - HAZWOPER Technician Level Refresher Emergency Response

High Emergency Response Annual REQ REQ

MDSHOTWORK MDS - Hot Work Permits Health & Safety High Job Specific Requirements Changes REQ REQ

MDSHYDRA MDS - Hydraulics Technical / Functional

Low Operations 3 Years REQ IND

MDSH2S MDS - Hydrogen Sulfide - H2S Health & Safety High Job Specific Requirements Changes IND IND

MDSINCIDENTNI MDS - Incident Notification and Investigation Health & Safety High Emergency Response Changes REQ REQ

MDSIONRAD MDS - Ionizing Radiation Health & Safety Medium Work Place Hazards Annual IND INDMDSLADDER MDS - Ladder Safety Health & Safety Medium Safe Work Practice Changes REQ REQ

MDSLEAD MDS - Lead Awareness Health & Safety High Job Specific Requirements Changes REQ REQ

MDSLIQUIDP MDS - Liquid Properties Technical / Functional

Low Operations 3 Years IND IND

MDSLOTO MDS - Lockout / Tagout (LOTO) Health & Safety High Safe Work Practice Changes REQ REQ

MDSAEDMDS - Medical Services & First Aid, Automated External Defibulator (AED), Annual

Health & Safety LowMedical Services and First

Aidper certification REQ REQ

MDSCPR MDS - Medical Services and First Aid - CPR Health & Safety LowMedical Services and First


MDSFIRSTAID MDS - Medical Services and First Aid - First Aid Health & Safety LowMedical Services and First


MDSNACE MDS - NACE Certificates Technical / Functional

Low Corrosion Control 3 Years IND IND

MDSNFPAIMDS - National Fire Protection Association (NFPA) 70e Initial

Technical / Functional

Before Performing Job Specific Requirements Changes REQ IND

MDSNFPARMDS - National Fire Protection Association (NFPA) 70e Refresher


Before Performing Job Specific Requirements 3 Years REQ IND

MDSNORMMDS - Naturally Occuring Radioactive Materials (NORM)

Health & Safety Low Job Specific Requirements Changes IND IND

MDSNPDESMDS - NPDES and Hydrostatic Test Discharge Procedures

Environmental Low EPA Changes IND IND

MDSNOISEAMDS - Occupational Noise Exposure / Hearing Protection (ABOVE an 8-hourTWA of 82 decibels (db), is Required Annually

Health & Safety High Work Place Hazards Annual IND IND

MDSNOISEBMDS - Occupational Noise Exposure / Hearing Protection (below an 8-hourTWA of 82 decibels (db)

Health & Safety High Work Place Hazards Changes REQ REQ

MDSONECALL MDS - One Call Technical / Functional

Medium Job Specific Requirements Annual IND IND

MDSHOIST MDS - Overhead Hoists & Gantry Cranes Health & Safety Low Job Specific Requirements Changes IND IND

MDSO2WELD MDS - Oxygen-Fuel Gas Welding and Cutting Health & Safety Low Job Specific Requirements Changes IND IND

MDSPPE MDS - Personal Protective Equipment Health & Safety High PPE Changes REQ REQ

MDSCONTROL MDS - Pipeline Control Technical / Functional


MDSFORKKAMDS - Powered Industrial Trucks / Materials Handling Equipment / Forklifts - Knowledge Assessment

Health & Safety Low Job Specific Requirements Changes REQ REQ

SAMPLE ONLY


New ID #


Content Owner



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MDSFORKSKILLMDS - Powered Industrial Trucks / Materials Handling Equipment / Forklifts - Skills Assessment

Health & Safety Low Job Specific Requirements 3 Years REQ REQ

MDSPSMMDS - Process Safety Management of Highly Hazardous Chemicals

Health & Safety High Safe Work Practice Annual IND IND

MDSPUMPREST MDS - Pump Restart Technical / Functional

High Job Specific Requirements 3 Years IND IND

MDSPUMPGRAD MDS - Pumping Gradients Technical / Functional


MDSRCRAMDS - RCRA - Personnel Training For Generators of Hazardous Waste Who Accumulate Waste On-Site

Environmental High Job Specific Requirements Annual REQ REQ

MDSDRM101 MDS - Records Management Basic - RM 101 Midstream Low Midstream 3 Years REQ REQMDSRESP MDS - Respiratory Protection Health & Safety Medium PPE Annual REQ REQ

MDSRIGSLING MDS - Rigging and Slings Health & Safety Low Job Specific Requirements Changes IND IND

MDSSAFESTARTI MDS - Safe Start Introduction or Refresher Health & Safety High TRANSPORTATION Changes REQ REQ

MDSHAZMATAIRMDS - Safe Transportation of Hazardous Materials - Air

DOT Low Job Specific Requirements 2 Years IND IND

MDSHAZMATGAMDS - Safe Transportation of Hazardous Materials - General Awareness

DOT High Job Specific Requirements 3 Years REQ REQ

MDSHAZMATRDMDS - Safe Transportation of Hazardous Materials - Highway


MDSHAZMATRAILMDS - Safe Transportation of Hazardous Materials - Rail


MDSHAZMATH2OMDS - Safe Transportation of Hazardous Materials - Water


MDSSCAFF MDS - Scaffolding Health & Safety Low Safe Work Practice Changes IND INDMDSSCBA MDS - SCBA Donning and Dofffing Health & Safety Low PPE Annual IND IND

MDSSECMFQD MDS - Security - Marine Facility Quarterly Drill Emergency Response

Medium Emergency Response Quarterly IND REQ

MDSSECFSOMDS - Security Training - Marine Facility Security Officer (FSO)

Emergency Response

High Emergency Response Changes IND REQ

MDSSPECMDS - Specifications for Accident Prevention Signs and Tags

Health & Safety Low Work Place Hazards Changes REQ REQ

MDSSPCCMDS - Spill Prevention Control and Countermeasure Plans (SPCC)

Environmental High Emergency Response Annual REQ REQ

MDSSPOTTERMDS - Spotters for Excavation, Overhead Lines & Equipment


Medium Safe Work Practice 3 Years REQ REQ

MDSSWPPPMDS - Storm Water Pollution Prevention Plan - SWPPP

Environmental Medium EPA Changes IND IND

MDSSWPPPPADMINMDS - Storm Water Pollution Prevention Plan (SWPPP) Administrator - Certified

Environmental High EPA 3 Years IND IND

MDSSULFUR MDS - Sulfur Analyzer Health & Safety Low Job Specific Requirements Annual IND IND

MDSSUPERCORE MDS - Supervisor Core Courses Midstream Low Job Specific Requirements Changes IND IND

MDSTSCAYRMDS - Toxic Substance Control Act (TSCA) and Your Responsibilities

Health & Safety High Work Place Hazards Annual REQ REQ

MDSTRENCHA MDS - Trenching and Excavation - Awareness Health & Safety Medium Job Specific Requirements Changes REQ REQ

MDSTRENCHCPMDS - Trenching and Excavation - Competent Person

Health & Safety Medium Job Specific Requirements Changes IND IND

MDSLIFTMDS - Vehicle Mounted Work Platforms (Aerial Lifts)

Health & Safety Low Safe Work Practice Changes REQ IND

MDSVARMDS - Volumetric Additive Reconciliation Requirements

Quality Control Medium Quality Control 3 Years IND REQ

MDSBCK MDSLCC - Backing Logistics Control Center

Medium Job Specific Requirements Cause REQ REQ

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MDSFATIGUE MDSLCC - Fatigue Management for Controllers Logistics Control Center

High Control Center Annual IND IND

MDSFATIGUE-S MDSLCC - Fatigue Management for Supervisors Logistics Control Center

High Control Center Annual IND REQ

MDSHYDRACENTR MDSLCC - Hydraulics: Centrifigal Pumps Logistics Control Center

Medium Control Center 3 Years REQ IND

MDSHYRAPIPE MDSLCC - Hydraulics: Pipeline Logistics Control Center


MDSHYDRAVALV MDSLCC - Hydraulics: Valves Logistics Control Center


MDSOQ0320MDSOQ0320 - Perform Routine Pressure Vessel Inspection

Operator Qualification

Before PerformingBreakout Tanks & Pump

Stations3 Years REQ IND

MDSOQ1.1MDSOQ1.1 - Measure Structure-to-Soil Potentials


Before Performing Corrosion Control 3 Years IND IND

MDSOQ1.2 MDSOQ1.2 - Conduct Close Interval Survey Operator Qualification


MDSOQ1.3 MDSOQ1.3 - Test to Detect Interference Operator Qualification

Before Performing Corrosion Control 3 Years REQ IND

MDSOQ1.4MDSOQ1.4 - Inspect and Perform Electrical Test of Bonds



MDSOQ1.5 MDSOQ1.5 - Inspect and Test Electrical Isolation Operator Qualification


MDSOQ10.1 MDSOQ10.1 - Insert and Remove Coupons Operator Qualification


MDSOQ10.2 MDSOQ10.2 - Monitor Probes (On-Line) Operator Qualification


MDSOQ19 MDSOQ19 - Perform Valve Maintenance Operator Qualification

Before Performing Valves 3 Years REQ IND

MDSOQ19.5MDSOQ19.5 - Inspect and Adjust Actuator/Operator, Electric


Before Performing Valves 3 Years REQ IND

MDSOQ21.2 - Disassemble/Reassemble Valves Operator Qualification

Before Performing Valves 3 Years IND IND

MDSOQ21.3MDSOQ21.3 - Perform Internal Inspection of Valves



MDSOQ21.4 - Repair Valve Actuator/Operator, Hydraulic



MDSOQ21.5 - Repair Valve Actuator/Operator, Electric



MDSOQ22.1MDSOQ22.1 - Inspect Tank Pressure/Vacuum Breakers




MDSOQ23.2 MDSOQ23.2a - Inspect and Test Relief Valves Operator Qualification



MDSOQ24.1MDSOQ24.1 -Maintain/Repair Pressure Limiting Devices



Stations3 Years IND IND

MDSOQ24.2MDSOQ24.2 - Inspect, Test and Calibrate Pressure Limiting Devices




MDSOQ25.1MDSOQ25.1 - Inspect, Test and Calibrate Pressure Switches




MDSOQ25.2MDSOQ25.2 - Inspect, Test and Calibrate Pressure Transmitters




MDSOQ3.0MDSOQ3.0 - Obtain a Voltage and Current Output Reading from a Rectifier to Verify Proper Performance



MDSOQ30 MDSOQ30 - Test Overfill Protective Devices Operator Qualification



MDSOQ31MDSOQ31 - Inspect and Calibrate Overfill Protective Devices




MDSOQ32aMDSOQ32a - Observe Excavation Activities - Competent Person


Before PerformingPipeline Repairs or

Relocation3 Years IND IND

MDSOQ32bMDSOQ32b - Observe Excavation Activities - Spotter




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MDSOQ38.3MDSOQ38.3 - Perform Visual Inspection of Welds


Before Performing Welding 3 Years IND IND

MDSOQ38.4MDSOQ38.4 - Perform NDT - Radiographic Testing



MDSOQ38.5MDSOQ38.5 - Perform NDT - Liquid Penetrate Testing



MDSOQ38.6MDSOQ38.6 - Perform NDT - Magnetic Particle Testing



MDSOQ38.7 MDSOQ38.7 - Perform NDT - Ultrasonic Testing Operator Qualification


MDSOQ38.7aMDSOQ38.7a - Perform NDT - Ultrasonic Testing - Thickness Only




MDSOQ39 MDSOQ39 - Perform Backfilling Operator Qualification



MDSOQ40.7MDSOQ40.7 - Install a Tap 2 Inches and Under on a Pipeline System




MDSOQ40.8MDSOQ40.8 - Install a Tap Larger than 2 Inches on a Pipeline System




MDSOQ40.9MDSOQ40.9 - Install and Remove Completion Plug on Pipelines Larger than 2 Inches




MDSOQ41 MDSOQ41 - Conduct Pressure Test Operator Qualification


Relocation3 Years REQ IND

MDSOQ4110 MDSOQ4110 - Purge a Pipeline Operator Qualification



MDSOQ4215.5MDSOQ4215.5 - Install and Monitor Mud Plug Vapor Barrier




MDSOQ4215.6MDSOQ4215.6 - Install and Monitor Dry Ice Vapor Barrier




MDSOQ4221 MDSOQ4221 - Bolt Flanged Pipe Joints Operator Qualification



MDSOQ4222 MDSOQ4222 - Install Threaded Pipe and Fittings Operator Qualification



MDSOQ4227MDSOQ4227 - Install and Maintain Process Tubing and Fittings




MDSOQ44.4 - Inspect, Test, and Perform Corrective and Preventative Maintenance of Tank Gauging for Leak Detection


Before Performing Field Operations of Pipeline 3 Years IND IND

MDSOQ44.5 - Prove Flow Meters for Hazardous Liquid Leak Detection


Before Performing Field Operations of Pipeline 3 Years IND IND

MDSOQ44.8 - Inspect, Test and Maintain Temperature Transmitters


Before Performing Field Operations of Pipeline 3 Years REQ IND

MDSOQ4601 - Perform Plastic Pipe Joining Operator Qualification



MDSOQ5.1MDSOQ5.1 - Examine for Mechanical Damage on Buried or Submerged Pipe



MDSOQ5.2MDSOQ5.2 - Examine for External Corrosion on Buried or Submerged Pipe



MDSOQ5.3MDSOQ5.3 - Inspect the Condition of External Coating on Buried or Submerged Pipe



MDSOQ6007 MDSOQ6007 - Inspect Gas Detectors Operator Qualification



MDSOQ6020 MDSOQ6020 - Inspect Span And Exposed Pipe Operator Qualification


MDSOQ6024MDSOQ6024 - Measure Pit Depth with Micrometer




MDSOQ7.1MDSOQ7.1 - Perform Visual Inspection of Atmospheric Coatings



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MDSOQ7.2MDSOQ7.2 - Prepare Surface for Coating Using Hand and Power Tools



MDSOQ7.3MDSOQ7.3 - Prepare Surface for Coating by Abrasive Water Blasting



MDSOQ7.4MDSOQ7.4 - Prepare Surface for Coating by Abrasive Blasting Methods Other Than Water



MDSOQ7.5aMDSOQ7.5a - Apply Coating to Buried Pipe Using Hand Application Methods



MDSOQ7.5bMDSOQ7.5b - Apply Coating To Transition Areas Using Hand Application Methods



MDSOQ7.5cMDSOQ7.5c - Apply Coating To Aboveground Pipe Using Hand Application Methods - Atmospheric Corrosion



MDSOQ7.6 - Apply Coating Using Spray Applications



MDSOQ7.7 MDSOQ7.7 - Perform Coating Inspection Operator Qualification



MDSOQ8.3 MDSOQ8.3 - Measure Corroded Area Operator Qualification


MDSOQ9.1 - Install Bonds Operator Qualification


MDSOQ9.2 - Install Galvanic Anodes Operator Qualification


MDSOQ9.3 MDSOQ9.3 - Install Rectifiers Operator Qualification


MDSOQ9.4MDSOQ9.4 - Install Impressed Current Ground Beds



MDSOQ9.5 MDSOQ9.5 - Repair Shorted Casings Operator Qualification


MDSOQ9.6a - Install Electrical Insulating Device - Flange/Isolation Joints



MDSOQ9.6b - Install Electrical Insulating Device - Electrical Isolation from Electrical Grounding



MDSOQ9.6c - Install Electrical Insulating Device - Aboveground Piping Isolation



MDSOQ9.6d - Install Electrical Insulating Device - Casing Isolation/Insulation



MDSOQ9001MDSOQ9001 – Perform Instrumented Natural Gas Pipeline Leak Surveys


Before Performing Right of Way 3 Years IND IND

LOP No. 10 Renton-Tacoma Terminal Operator Qualifications

and Training Guide

Page 1 of 7 Date Issued: 2009 Revised No.:

1

TANK GUAGING METHODS

1. Automatic gauges: a. Tank auto gauges b. Fuels Manager gauges

2. Hand gauges:

a. Inage Method b. Outage method c. Strapping charts and converting barrels to gallons

3. Read and understand all applicable ConocoPhillips SOP’s and Portland

Terminal LOP’s

OPERATOR _________________________________________DATE___________ TRAINER _________________________________________DATE___________ SUPERVISOR _________________________________________DATE___________ TANK SAMPLING METHODS:

1. Representative Sample 2. All-levels Sample 3. Running Sample 4. Spot Sample 5. Top Sample 6. Upper Sample 7. Middle Sample 8. Lower Sample 9. Bottom Sample 10. Drain Sample 11. Composite sample 12. RVP sample 13. Read and understand all applicable ConocoPhillips SOP’s and Tacoma

Terminal LOP’s 14. Ethanol testing (truck oversight) 15. B100 testing/sampling procedures 16. Flash tester operation 17. Sulfur analyzer operation 18. RVP conversion schedules/ RVP tank turn calculations

OPERATOR _________________________________________DATE___________ TRAINER _________________________________________DATE___________ SUPERVISOR _________________________________________DATE___________


and Training Guide


2

PRODUCT HANDLING

1. Loading rack a. Accuload recipe changes/ Approved NW blending requirements b. Trouble shooting operating system and driver problems c. Driver certifications d. Read and understand all applicable ConocoPhillips SOP’s and COP

Driver training policy e. Driver training procedures, conduct driver load training


2. Tank Transfers a. Keep the designated rack tank full. b. Transfer other products as needed to make room. c. Transfer tank 3675, 3676. (TACOMA) d. Hand and auto gauge for the above. e. Complete paper work for Stock Accounting. f. Read and understand all applicable ConocoPhillips SOP’s and

Terminal LOP’s. g. Shore tank reports



and Training Guide


3

3. Marine dock activity (TACOMA) a. Receipts:

i. Barges b. Vessel tie-ups c. Hand, auto gauge and sample for the above. d. Hose connections. e. Complete applicable tests and post. f. Complete paperwork for Stock Accounting. g. Read Coast Guard Manual and become familiar with USCG

Regulations and requirements (see “j.” below for training aids). h. Read and understand applicable ConocoPhillips Tacoma Operations

manual section applicable to marine operations, Safe and Effective weather threshold procedures, vessel pre-booming procedures. Qualify as PIC (PIC qualification card required).


4. Olympic Pipeline a. Be able to read and understand Olympic Pipeline schedules b. Know communication notification requirements and track pipelines c. Know required line clear/fill requirements. d. Know line set ups, gauging requirements and sampling requirements. e. Complete applicable test and post. f. Complete paperwork for accounting. g. Read and understand all applicable ConocoPhillips SOP’s.

OPERATOR __________________________________________DATE___________ TRAINER __________________________________________DATE___________ SUPERVISOR __________________________________________DATE___________ VAPOR RECOVERY SYSTEM TACOMA 1. Read and understand the Vapor Control System manual including the permit information and limitations. 2. Daily Yokogawa printouts and discrepancy notifications 3. CEMS unit calibration procedures 4. Continuous and instantaneous set points and alarm shutdown points 5. RS View screen navigation and alarm log viewer


and Training Guide


4

6. Troubleshooting and emergency shutdown procedures and call-out/ notification procedures. 7. Daily VRU/VCU logs 8. Glycol testing including adding glycol 9. Adding oil to VRU pumps and air system oilers 10. Truck backpressure testing 11. VRU/VCU maintenance plans 12. Supply & Return tank valve lineups OPERATOR __________________________________________DATE___________ TRAINER __________________________________________DATE___________ SUPERVISOR __________________________________________DATE___________ RENTON 1. Read and understand the Vapor Control System manual including the permit information. 2. Daily Yokogawa printouts and discrepancy notifications 3. CEMS unit calibration procedures 4. Continuous and instantaneous set points and alarm shutdown points 5. RS View screen navigation and alarm log viewer 6. Troubleshooting and emergency shutdown procedures and call-out/ notification procedures. 7. Daily VRU/VCU logs 8. Glycol testing including adding glycol 9. Adding oil to VRU pumps and air system oilers 10. Truck backpressure testing 11. VRU maintenance plan 12. Supply & Return tank valve lineups OPERATOR __________________________________________DATE___________ TRAINER __________________________________________DATE___________ SUPERVISOR __________________________________________DATE___________


and Training Guide


5

WASTE WATER MANAGEMENT TACOMA

1. North Storm water separator system a. Sampling requirements including permit parameters and limits b. Ph adjustments and field testing c. Skimming procedures and maintenance d. Release water procedures e. Reporting requirements f. System layout and configuration above ground storage tank g. Read and understand all applicable ConocoPhillips SOP’s and

Terminal storm water o & m procedures and manuals. OPERATOR __________________________________________DATE___________ TRAINER __________________________________________DATE___________ SUPERVISOR __________________________________________DATE___________

2. South Storm water separator system a. Sampling requirements including permit parameters and limits b. Ph adjustments and field testing c. Skimming procedures and maintenance d. Release water procedures e. System layout and configuration tank 4 and 5 holding tanks f. Reporting requirements. g. Read and understand all applicable ConocoPhillips SOP’s and

Terminal storm water o & m procedures and manuals. OPERATOR __________________________________________DATE___________ TRAINER __________________________________________DATE___________ SUPERVISOR __________________________________________DATE___________

3. South UST a. High level alarm testing, RS view monitor b. System layout and configuration c. Operating levels and when to make notifications for water removal

OPERATOR __________________________________________DATE___________ TRAINER __________________________________________DATE___________ SUPERVISOR __________________________________________DATE___________


and Training Guide


6

RENTON

1. Process Water (METRO) a. Test requirements including permit parameters and limits b. System layout and configuration including system operation c. Reporting requirements. d. Sampling procedure e. Read and understand all applicable ConocoPhillips SOP’s and

Terminal SWI’s. OPERATOR __________________________________________DATE___________ TRAINER __________________________________________DATE___________ SUPERVISOR __________________________________________DATE___________

2. Storm water (WETLANDS) a. Test requirements including permit parameters and limits b. System layout and configuration including system operation c. Reporting requirements d. Sampling procedures



and Training Guide


7

TERMINAL MAINTENANCE

1. Terminal appearance: a. Trash collection at end of shift and general clean up while on duty. b. Observations and notifications of problems c. Hosing down and steam cleaning areas when needed including load

rack d. Misc Painting and touchups e. PGI completion f. Read and understand all applicable ConocoPhillips SOP’s and

Terminal SWI’s. g. SAP maintenance notifications


2. Compliance checks. a. Weekly fire pump and monthly foam room checks. b. Monthly fire extinguisher checks c. Monthly cathodic protection checks (rectifiers) d. Monthly spill response trailer checks and inventories e. Weekly and monthly spill response boat checks (TACOMA) f. Monthly product quality over site samples. g. Ethanol over site testing h. Monthly Eyewash/shower checks i. Monthly emergency light checks j. Monthly ESD checks k. Ph meter monthly calibration l. VAR report m. Red dye compliance n. Oil water separator inspections o. Hazardous wasted storage area inspections p. Tank high level alarm checks q. Conductivity calibration r. Diesel monthly conductivity test s. Read and understand all applicable ConocoPhillips SOP’s and

Terminal SWI’s. OPERATOR __________________________________________DATE___________ TRAINER __________________________________________DATE___________ SUPERVISOR __________________________________________DATE___________

Documents

RENTON TERMINAL - apps.ecology.wa.gov