Statement of Work - Propane Piping.pdf

STATEMENT OF WORK

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STATEMENT OF WORK (SOW)

FOR

INSPECTION, TESTING, AND MECHANICAL INTEGRITY EVALUATION OF PROPANE

PIPE SYSTEM AT USCG TRACEN PETALUMA

1.0 GENERAL

1.1 BACKGROUND

United States Coast Guard Training Center (TRACEN) Petaluma, located at 599 Tomales Rd., Petaluma, CA 94952, operates multiple propane piping systems that support mission-essential training, housing, and support facilities. Safe operation of this piping is critical to personnel safety, protection of government property, and uninterrupted mission performance.

The Coast Guard is required to maintain propane pipe systems and associated appurtenances in a condition that conforms to applicable codes and standards, including The American Society of Mechanical Engineers (ASME) Boiler and Pressure Vessel Code (BPVC) Section VIII and The National Board of Boiler and Pressure Vessel Inspectors Inspection Code (NBIC), as well as NFPA 58 and 59 (Liquefied Petroleum Gas Code) and other referenced industry standards.

The Coast Guard requires a comprehensive inspection, evaluation, and documentation effort, performed by qualified personnel, to verify the current condition of all pipes, identify deficiencies, evaluate remaining life, and formally document the inspection results in mechanical integrity reports. The work under this Statement of Work (SOW) will provide the technical basis for continued safe operation and for planning future maintenance and inspection intervals.

1.2 SCOPE

This SOW covers the inspection, testing, evaluation, and reporting for the propane pipe systems and associated pressure-retaining components at USCG TRACEN Petaluma. The Contractor must perform:

• Pre-inspection review of existing equipment files and records.

• External visual inspection of tanks and associated piping and appurtenances.

• External non-destructive testing (NDT), including ultrasonic thickness measurements and related activities.

• Rectifier testing to verify cathodic protection performance for pipes equipped with cathodic protection systems.

• Leak testing of fittings, seams, and appurtenances on the pipes.

• Corrosion and coating condition inspections.

• Mechanical integrity evaluations and documentation of conformity with applicable codes and standards.

The scope includes labor, supervision, tools, equipment, materials, instruments, transportation, data reduction, engineering evaluation, and report preparation required to complete the inspections and analyses.

Negative scope: This SOW does not include physical repair, replacement, modification, or alteration of propane piping, rectifiers, or other system components. If the Contractor identifies conditions that require repair or immediate mitigation, the Contractor must document those conditions and provide recommendations; the execution of repair work will be addressed under separate contracting actions.

https://uscg-my.sharepoint-mil.us/personal/daniel_l_standley_uscg_mil/Documents/FE%20COR%20Projects/SCOPE%20PARAGRAPHS.doc

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1.3 OBJECTIVE

The objective of this effort is to obtain a current, code-compliant assessment of the mechanical integrity and fitness-for-service of TRACEN Petaluma’s propane piping systems and associated appurtenances, and to document that assessment in a manner that:

• Confirms whether piping is safe to operate in accordance with ASME BPVC Section VIII and NBIC.

• Verifies that cathodic protection and corrosion control measures for the piping system meet the criteria of NFPA 58/59 and other referenced standards.

• Identifies deficiencies, degradation mechanisms, and required or recommended corrective actions, with associated criticality.

• Establishes recommended future inspection intervals consistent with applicable codes and recognized engineering practice.

1.3.1 Reference Documents

The following documents may be helpful to the Contractor in performing the work described in this SOW. The Contractor is responsible for using the latest applicable editions in effect at the time of contract award, unless otherwise specified.

• National Board Inspection Code (NBIC) – Inspection Code for pressure-retaining items.

• NFPA 58/59, Liquefied Petroleum Gas Code.

• NACE (now AMPP) standards relevant to corrosion control and cathodic protection.

• API 570, Piping Inspection Code.

• SNT-TC-1A, Recommended Practice for Personnel Qualification and Certification in

Nondestructive Testing.

2.0 SPECIFIC REQUIREMENTS / TASKS

The Contractor must perform the tasks described in this section and must provide the deliverables identified in each task.

2.1 TASK ONE. PROJECT MANAGEMENT AND FILE REVIEW

The Contractor must provide overall project management and perform a comprehensive review of existing equipment records for the propane piping system.

2.1.1 Project Management and Coordination

a. The Contractor must designate a single point of contact for the Government for all technical and contractual matters related to this SOW.

b. The Contractor must develop and maintain a project schedule that identifies key milestones, site access dates, inspection activities, and deliverable due dates.

c. The Contractor must coordinate with the Government Technical Representative (GTR) to:

• Schedule site visits, inspections, and testing within the established Period of Performance and normal hours of operation, unless otherwise authorized.

• Identify required facility support, including access, escort requirements, and lockout/tagout or system isolation requirements.

d. The Contractor must provide status updates to the GTR at intervals agreed upon at project kickoff, to include schedule progress, site findings of immediate concern, and anticipated changes to planned activities.

2.1.2 Equipment File Review

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a. The Contractor must perform a detailed review of available equipment documentation for the piping and associated pressure-retaining item, including, where available:

• Original design documents and specifications.

• Original Equipment Manufacturer (OEM) construction drawings and data reports.

• Nameplate data and historical design information (design pressure, design temperature, corrosion allowance, materials of construction).

• Repair and alteration documentation.

• Previous inspection reports, NDT results, and thickness measurement data.

• Cathodic protection system design and previous rectifier testing records.

b. The Contractor must use the file review to:

• Establish baseline design and service conditions for the piping.

• Identify known degradation mechanisms and previous areas of concern.

• Develop preliminary inspection plans, including proposed NDT techniques, thickness measurement locations (TMLs), and areas requiring focused attention.

c. The Contractor must document significant gaps in available documentation and must identify any missing, incomplete, or inconsistent information that may affect the assessment of mechanical integrity. This documentation must be incorporated into the final report.

2.2 TASK TWO. FIELD INSPECTIONS AND TESTING

The Contractor must perform field inspections and testing of the propane piping system and associated pressure-retaining components identified in Exhibit 1, consistent with ASME BPVC Section VIII, NBIC, NFPA 58, NFPA 25, NFPA 59 as applicable, 6 NYCRR, NACE standards, STI SP001, API 570, and recognized and generally accepted good engineering practice.

2.2.1 External Visual Inspection

a. The Contractor must perform a systematic external visual inspection aboveground piping, appurtenances, supports, and visible portions of cathodic protection equipment.

b. Visual inspections must be conducted by personnel competent in tank, piping, and pressure vessel design and damage mechanisms, and familiar with API 570, STI SP001, and NBIC inspection practices.

c. At a minimum, the Contractor must visually examine and document:

• Exterior of piping for evidence of distortion, deformation, bulging, dents, or misalignment.

• Fittings, fitting attachments, and structural support for cracking, corrosion, or other distress.

• External surfaces for general corrosion, pitting, coating breakdown, undercutting, or damage.

• Accessories and appurtenances such as valves, gauges, relief devices, level indicators, and associated hardware for obvious damage, leakage, or improper configuration.

• Cycle all valves in the system and ensure proper operation.

d. The Contractor must record observed conditions with written descriptions and photographs sufficient to support subsequent engineering evaluation and repair recommendations.

e. If the Contractor identifies deficiencies during visual inspection that present an immediate or urgent safety concern, the Contractor must inform the GTR in writing as soon as practicable, describing the condition, the basis for concern, and recommended immediate actions (for example, removal from service, temporary mitigation, or closer monitoring).

2.2.2 External Nondestructive Testing (NDT)

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a. The Contractor must perform external NDT on the piping and associated components, using techniques appropriate for the materials, geometry, and anticipated damage mechanisms.

Techniques may include, but are not limited to, ultrasonic thickness testing (UT), magnetic particle testing (MT), dye penetrant testing (PT), and other applicable methods.

b. Personnel performing NDT must meet the qualification and certification requirements of SNT-TC-1A for the methods used.

c. For ultrasonic thickness measurements, the Contractor must:

• Establish and document Thickness Measurement Locations (TMLs) on all aboveground piping and other areas susceptible to corrosion or thinning.

• Record thickness readings at each TML and document the exact location (for example, by dimensioned sketches, grid systems, or other mapping techniques).

• Provide a TML map in the final report that allows future inspectors to repeat measurements at the same locations.

d. The Contractor must evaluate the NDT results for evidence of wall loss, pitting, laminations, cracking, or other relevant discontinuities and must integrate these findings into the mechanical integrity assessment.

2.2.3 Rectifier Testing and Cathodic Protection Evaluation

a. For the pipes equipped with cathodic protection systems, the Contractor must test rectifiers and associated components to evaluate operational status and protection levels.

b. The Contractor must measure structure-to-electrolyte potentials and other parameters required to determine whether protection criteria are met. For buried or electrically isolated components governed by NFPA 58/59, the Contractor must verify that protection levels achieve a minimum of -0.85 volts (DC), measured with appropriate reference electrodes and instruments, consistent with NFPA 58/59 requirements and applicable NACE standards.

c. The Contractor must document:

• Rectifier operating voltages and currents.

• Measured potential and test locations.

• Observed deficiencies in rectifier operation, wiring, test stations, or anode systems.

d. If cathodic protection is not effective or is not operating as intended, the Contractor must identify the condition, discuss its impact on corrosion risk, and provide recommendations for corrective action.

2.2.4 Odorometer / Leak Testing

a. The Contractor must conduct leak testing on fittings, seams, and other accessible joints on the pipes and associated appurtenances to identify gas leaks.

b. Leak testing must be conducted using appropriate detection methods and equipment suitable for liquefied petroleum gas (LPG) service, consistent with NFPA 58/59 and relevant industry practice.

c. The Contractor must document test methods, locations tested, and results, including a description and location of any detected leaks.

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d. If the Contractor detects a leak that presents a safety concern, the Contractor must immediately notify the GTR verbally and follow with written notification describing the location, magnitude (as reasonably assessed), and recommend immediate actions.

2.2.5 Corrosion Inspection and Coating Condition Assessment

a. The Contractor must evaluate the structural and corrosion condition of the piping, including external surfaces, visible internal areas (if any are accessible during the performance period), and associated supports and appurtenances.

b. At a minimum, the Contractor must:

• Identify areas of general corrosion, pitting, localized attack, or coating breakdown.

• Comment on paint and coating conditions, including blistering, flaking, rust-through, or impact damage.

• Evaluate whether observed conditions are consistent with expected service environments and with findings from previous inspections (if available).

c. The Contractor must assess whether the observed corrosion or coating condition affects structural integrity, code compliance, or expected remaining service life and must reflect these assessments in the final mechanical integrity reports.

d. For any corrosion-related condition that the Contractor considers to be urgent or requiring prompt repair, the Contractor must inform the GTR in writing and describe the basis for that assessment and recommended actions.

2.3 TASK THREE. ANALYSIS, REPORTING, AND DOCUMENTATION

The Contractor must perform engineering evaluations of the inspection and testing data and must generate mechanical integrity reports for all applicable piping.

2.3.1 Engineering Evaluation and Mechanical Integrity Assessment

a. The Contractor must evaluate inspection and NDT results in accordance with ASME BPVC Section VIII, NBIC, API 570, STI SP001, NFPA 58/59, NACE guidance, and applicable Coast Guard requirements.

b. For all piping, the Contractor must:

• Determine or confirm calculation bases, including design conditions, materials, corrosion allowance, and joint efficiencies, as information is available.

• Calculating minimum required thickness for pressure-retaining components, using appropriate code formulas and design assumptions consistent with ASME BPVC Section VIII and related standards.

• Compare measured thickness values to calculated minimum thickness and identify any locations where measured thickness is at or below minimum required values.

• Assess remaining life based on measured corrosion rates and remaining thickness, using accepted methods from API 570, and related standards.

• Evaluate the overall fitness-for-service of each piping system, indicating whether the piping is acceptable for continued operation, acceptable with conditions, or not acceptable without repair or mitigation.

c. The Contractor must consider the effects of detected leaks, corrosion, structural damage, rectifier performance, and other deficiencies when determining overall mechanical integrity and must provide clear justification for conclusions reached.

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2.3.2 Reports and Deliverables

a. The Contractor must prepare a mechanical integrity report for all piping at a minimum, include:

1. Identification Information o Equipment identification number, service, location, and capacity.

o Manufacturer, year of construction (if known), design pressure, design temperature, and materials of construction (if known).

2. Summary of Applicable Codes and Evaluation Basis o Codes and standards applied (for example, ASME BPVC Section VIII, NBIC, API

570, NFPA 58/59, NACE, STI SP001).

o Assumptions made due to missing or incomplete data.

3. Visual and NDT Inspection Results o Narrative summary of visual inspection findings.

o Summary of NDT methods used, including technique, extent, and limitations.

o Detailed tabulation of UT thickness readings and other NDT results.

4. Ultrasonic Testing Data and TML Map o Tabulated UT readings with associated TML identifiers.

o A TML map (sketches, grid layouts, or diagrams) showing the locations of all

TMLs used for evaluation.

5. Graphical Representation of Pipe Thickness Data o Plots or graphical representations of shell thicknesses by elevation, circumferential location, or other meaningful arrangement to illustrate corrosion patterns and minimum thickness locations.

6. Calculated Minimum Thickness o Calculated minimum required thickness for relevant components, including shell, heads, and other critical sections, with supporting equations and input values.

7. Remaining Life Expectancies o Calculated remaining life for each pipe based on measured thicknesses, corrosion rates (derived from current and previous data where available), and minimum thickness criteria.

8. Repair and Mitigation Recommendations with Criticality Ranking o Specifically recommended repairs, modifications, monitoring actions, and/or operational limitations.

o A criticality ranking or prioritization scheme that categorizes recommendations by urgency (for example, immediate, short-term, or long-term) and potential impact on safety and reliability.

9. Inspection Photographs o Representative photographs documenting the overall condition of each pipe and illustrating key findings, including corrosion, coating condition, structural issues, or observed leaks.

10. Future Inspection Intervals o Recommended future internal and external inspection intervals and NDT re-examination frequencies consistent with NBIC, API 570, STI SP001, NFPA 58/59, and recognized engineering practice.

11. Rectifier and Cathodic Protection Results o Rectifier test data, structure-to-electrolyte potentials, and assessment of cathodic protection effectiveness.

o Recommended actions where protection criteria are not met.

12. Leak Test and Corrosion Condition Summary o Summary of leak test methods, locations tested, and results.

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o Summary of corrosion and coating conditions and their impact on integrity.

b. All final mechanical integrity reports forms must be reviewed and approved by:

• A licensed professional engineer (PE) experienced in pressure vessel inspection and evaluation, and

• An inspector holding appropriate certifications that include, at a minimum, API-570 (Piping), NACE Level II (corrosion), and STI certification for aboveground piping inspection, or equivalent certifications accepted by the Government.

c. The Contractor must consolidate individual pipe reports into a summary report that:

• Provides a high-level overview of the condition of the propane piping population at

TRACEN Petaluma.

• Summarizes key risks and system-level issues (for example, systematic cathodic protection problems, recurring coating failures, or design-related vulnerabilities).

• Consolidates recommended actions and inspection intervals into a prioritization list for planning and budgeting.

d. The Contractor must deliver all reports in electronic format, compatible with DHS workstations (for example, Microsoft Word for narrative reports and Microsoft Excel for tables and data, as applicable), in accordance with SOW 4.5.

e. All deficiencies identified during the analysis phase must be clearly communicated in the written reports described in this section.

3.0 CONTRACTOR PERSONNEL

It is the responsibility of the contractor to propose qualified contractor personnel to perform all requirements specified in the SOW. As a general rule, the government should not specify education, experience or other qualifications for contractor personnel. In some instances, however, it may be necessary for the government to specify contractor qualifications, certifications, and/or education. For example, there may be a need for a Certified Public Accountant (CPA) for a requirement for financial support services. Similarly, you may deem it necessary to specify qualifications, certifications, and/or education for contractor Subject Matter Experts. And it is recommended that you specify minimum qualifications, certifications, and/or education for contractor Key personnel and obtain resumes for those positions. Before including education, experience or other qualifications for contractor personnel in the SOW, discuss the matter with your Contracting Officer.

3.1 QUALIFIED PERSONNEL

The Contractor must provide qualified personnel to perform all requirements specified in this

SOW.

3.2 KEY PERSONNEL

Before replacing any individual designated as Key by the Government, the Contractor must notify the Contracting Officer no less than 15 business days in advance, submit written justification for replacement, and provide the name and qualifications of any proposed substitute(s). All proposed substitutes must possess qualifications equal to or superior to those of the Key person being replaced, unless otherwise approved by the Contracting Officer. The Contractor must not replace Key Contractor personnel without approval from the Contracting Officer. The following Contractor personnel are designated as Key for this requirement. Note:

The Government may designate additional Contractor personnel as Key at the time of award.

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3.3 EMPLOYEE IDENTIFICATION

3.3.1 Contractor employees visiting Government facilities must wear an identification badge that, at a minimum, displays the Contractor name, the employee’s photo, name, clearance-level and badge expiration date. Visiting Contractor employees must comply with all Government escort rules and requirements. All Contractor employees must identify themselves as Contractors when their status is not readily apparent and display all identification and visitor badges in plain view above the waist at all times.

3.4.2 Contractor employees working on-site at Government facilities must wear a Government issued identification badge. All Contractor employees must identify themselves as Contractors when their status is not readily apparent (in meetings, when answering Government telephones, in e-mail messages, etc.) and display the Government issued badge in plain view above the waist at all times.

3.5 EMPLOYEE CONDUCT

Contractor’s employees must comply with all applicable Government regulations, policies and procedures (e.g., fire, safety, sanitation, environmental protection, security, “off limits” areas, wearing of parts of DHS uniforms, and possession of weapons) when visiting or working at Government facilities. The Contractor must ensure Contractor employees present a professional appearance at all times and that their conduct must not reflect discredit on the United States or the Department of Homeland Security. The Project Manager must ensure Contractor employees understand and abide by Department of Homeland Security established rules, regulations and policies concerning safety and security.

3.6 REMOVING EMPLOYEES FOR MISCONDUCT OR SECURITY REASONS

The Government may, at its sole discretion (via the Contracting Officer*), direct the Contractor to remove any Contractor employee from DHS facilities for misconduct or security reasons.

Removal does not relieve the Contractor of the responsibility to continue providing the services required under the contract. The Contracting Officer will provide the Contractor with a written explanation to support any request to remove an employee.

4.0 OTHER APPLICABLE CONDITIONS

4.1 SECURITY

Contractor access to classified information is not currently required under this SOW.

4.2 PERIOD OF PERFORMANCE

The period of performance for this contract must not exceed 60 calendar days from the date of award.

4.3 PLACE OF PERFORMANCE

The primary place of performance will be United States Coast Guard at USCG TRACEN Petaluma located at 599 Tomales Rd. Petaluma, CA 94952

4.4 HOURS OF OPERATION

Contractor employees must generally perform all work between the hours of 0730 and 1530 PST/PDT, Monday through Friday (except Federal holidays). However, there may be occasions when Contractor employees must be required to work other than normal business hours, including weekends and holidays, to fulfill requirements under this SOW.

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4.5 GENERAL REPORT REQUIREMENTS

The Contractor must provide all written reports in electronic format with read/write capability using applications that are compatible with DHS workstations (Microsoft Office Applications).

5.0 GOVERNMENT FURNISHED RESOURCES

The Government will provide all necessary information, data and documents to the Contractor for work required under this contract.

6.0 CONTRACTOR FURNISHED PROPERTY

The Contractor must furnish all facilities, materials, equipment and services necessary to fulfill the requirements of this contract, except for the Government Furnished Resources specified in SOW 2.0 and SOW 5.0.

7.0 GOVERNMENT ACCEPTANCE PERIOD

The Government Technical Representative will review deliverables prior to acceptance and provide the contractor with an e-mail that provides documented reasons for non-acceptance. If the deliverable is acceptable, the Government Technical Representative will send an e-mail to the Contractor notifying it that the deliverable has been accepted.

7.1 The Government Technical Representative will have the right to reject or require correction of any deficiencies found in the deliverables that are contrary to the information contained in the Contractor’s accepted proposal. In the event of a rejected deliverable, the Contractor will be notified in writing by the Government Technical Representative of the specific reasons for rejection. The Contractor may have an opportunity to correct the rejected deliverable and return it per delivery instructions.

7.2 The Government Technical Representative will have 10 business days to review deliverables and make comments. The Contractor must have 10 business days to make corrections and redeliver.

7.3 All other review times and schedules for deliverables must be agreed upon by the parties based on the final approved Project Plan. The Contractor must be responsible for timely delivery to Government personnel in the agreed upon review chain, at each stage of the review.

The Contractor must work with personnel reviewing the deliverables to assure that the established schedule is maintained.