Pipeline_ITM_Study_(8-26-22)_for_SOW.xlsx
XLSX spreadsheet 35 KB Posted
- Attached to
- BLM Pipeline and Wellfield Operations Federal contract opportunity
- Solicitation number
- 140L0623Q0001
About this file
This is a combined synopsis and solicitation from the Bureau of Land Management seeking proposals for pipeline and wellfield operations services. Key requirements include providing personnel to maintain a 425-mile crude helium pipeline and associated wellfield in accordance with the attached statement of work, which outlines inspection, maintenance, and repair duties. Interested parties may attend an optional site visit on November 18th and must submit any questions by November 22nd. Quotes are due by December 9th and pricing must include a firm fixed price for regular duties as well as a time and materials line item for emergency work. The selected contractor will coordinate with two existing BLM contractors at the facility located in Cliffside, Texas.
View the file
Other files for this federal contract opportunity
| File | Type | Posted |
|---|---|---|
| Sol_140L0623Q0001_Amd_0004.pdf | ||
| Pipeline_ITM_Study_For_Contract_(2)_0003.pdf | ||
| Mainline_Valve_SOP_0003.pdf | ||
| BLM_AMFO_Crude_Helium_Pipeline_CP_Inspection_Evaluation_Report_-_20220720_0003.pdf | ||
| B08_-_Evaluation_Critera_(F)_0003.pdf | ||
| Sol_140L0623Q0001_Amd_0003.pdf | ||
| 140L0623Q0001_Q_A_Responses_0003.pdf | ||
| BLM_Pipeline_and_Wellfield_Industry_Day_18_NOV_2022_PPT_0003.pdf | ||
| B08_-_Pipeline_Wellfield_Solicitation_(F)_0003.pdf | ||
| B08_Pipeline_Gasfield_Operations_SOW_(F)_DEC_2022_0003.pdf | ||
| Sol_140L0623Q0001_Amd_0002.pdf | ||
| Wage_Det_2015-5213_Rev_19_0001.pdf | ||
| B08_-_Evaluation_Critera_(F)_0001.pdf | ||
| B08_-_Pipeline_Gasfield_Operations_SOW_(F)_0001.pdf | ||
| B08_-_Pipeline_Wellfield_Solicitation_(F)_0001.pdf | ||
| Sol_140L0623Q0001_Amd_0001.pdf | ||
| Sol_140L0623Q0001.pdf |
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Text version
Inspection-Test-Maintenance
| Area/Equipment Group | Equipment Type | Service/Purpose | Regulatory Agency | RAGAGEP/Best Practice | RAGAGEP Section | Applicable to: Federal Only/Private Only/Both | ITPM (Inspection Testing/Preventative Maintenance) Requirement | ITPM Frequency | Critical Life Safety Equipment? (Y/N/NA) | Comments/Notes | |
| Pipeline | Pipeline-Main/Lateral lines | Helium Transport | PHMSA | 49 CFR Part 192 | Subpart A - 192.5 | TDB | Class location must be determine for each gas transmission pipeline segment. Class 1 (lowest risk), 2, 3, 4 (highest risk) The class location is used to determine risk and affects maintenance activity frequency requirements. | Once and update as required by MOC modifications | N | ||
| Pipeline | Pipeline-Main/Lateral lines | 3rd Party Damage prevention and monitoring | PHMSA | 49 CFR Part 192 | Subpart M - 192.705 | TDB | Patrol right-of-way for indications of leaks, construction activity, and other factors affecting safety and operation | 2x per Calendar Year at Highway and Railroad crossings. 1x per Calendar Year (not to exceed 15 month) at all other locations. | N | ||
| Pipeline | Pipeline-Main/Lateral lines | Leak monitoring | PHMSA | 49 CFR Part 192 | Subpart M - 192.706 | TDB | Leakage surveys of pipeline must be conducted using leak detector equipment. (pipeline without an odor or odorant) | 1x per Calendar Year (not to exceed 15 months) | N | ||
| Pipeline | Pipeline-Main/Lateral lines | 3rd Party Damage Prevention/Identification of pipeline for the public | Best Practice | 49 CFR Part 192 | Subpart M - 192.707 | Both | Line markers are required at all road and railroad crossing and where needed to prevent possible damage. | Once and verified by Patrol survey to ensure the line marker are still in place. | N | ||
| Pipeline | Pipeline-Main/Lateral lines | Corrosion Monitoring | PHMSA | 49 CFR Part 192 | Subpart M - 192.710 | TDB | Pipeline Assessment: An operator must perform initial assessments (In-line-inspection (ILI), Hydrotest, Guide Wave ultra sonic (GWUT), or Direct Assessment) for all applicable pipeline segments no later than July 3, 2034. | 10 years (not to exceed 126 months) | N | ||
| Pipeline | Relief Device | Pressure Protection | Best Practice | 49 CFR Part 192 | Subpart M - 192.739 | Both | Relief Device: Inspect and test for mechanical condition, set pressure, capacity, reliability, installation, etc. | 1x per Calendar Year (not to exceed 15 months) | N | ||
| Pipeline | Shutdown Valve | Leak volume reduction | Best Practice | 49 CFR Part 192 | Subpart M - 192.745 | Both | Pipeline valves inspection is required for all valves that might be required during any emergency. | 1x per Calendar Year (not to exceed 15 months) | N | ||
| Pipeline | Cathodic Protection | Corrosion Prevention | Best Practice | 49 CFR Part 192 | Subpart I - 192.465 a) | Both | Cathodic Protection (CP) Annual Survey to determine whether the cathodic protection meets the requirements for the pipeline. | 1x per Calendar Year (not to exceed 15 months) | N | ||
| Pipeline | Cathodic Protection | Corrosion Prevention | Best Practice | 49 CFR Part 192 | Subpart I - 192.465 b) | Both | Cathodic Protection (CP) Rectifier Survey - CP rectifier or impressed current power source must be inspected. | 6x per Calendar Year (not to exceed 2.5 months) | N | ||
| Pipeline | Cathodic Protection | Corrosion Prevention | Best Practice | 49 CFR Part 192 | Subpart I - 192.465 c) | Both | Cathodic Protection: Each reverse current switch, each diode, and each interference bond whose failure would jeopardize structure protection must be electrically checked for proper performance. | 6x per Calendar Year (not to exceed 2.5 months) | N | ||
| Pipeline | Cathodic Protection | Corrosion Prevention | Best Practice | 49 CFR Part 192 | Subpart I - 192.481 | Both | Atmospheric Corrosion Monitoring: Inspect and evaluate each pipeline or portion of the pipeline that is exposed to the atmosphere for evidence of atmospheric corrosion. | Every 3 years (not to exceed 39 months) | N | ||
| Pipeline | Procedures | Identify Maintenance and Operations Requirements & Information | PHMSA | 49 CFR Part 192 | Subpart L - 192.605 | Both | Operations and Maintenance (O&M) Plan: A manual of written procedures for conducting operations and maintenance activities, abnormal operations and for emergency response. Appropriate parts of the manual must be kept at locations where operations and maintenance activities are conducted | Reviewed and updated 1x per Calendar Year (not to exceed 15 months) | N | ||
| Pipeline | Procedures | 3rd Party Damage Prevention/Identification of pipeline for the public | Best Practice | 49 CFR Part 192 | Subpart L - 192.614 | Both | Damage Prevention Program: each operator of a buried pipeline must carry out a written program to prevent damage to that pipeline from excavation activities and 3rd party damage. | Ongoing with 811 Call before you Dig program | N | ||
| Pipeline | Procedures | Procedure | PHMSA | 49 CFR Part 192 | Subpart L - 192.615 | TBD | Emergency Plans: Each operator shall establish written procedures to minimize the hazard resulting from a gas pipeline emergency. (Identification of emergency, notifications, emergency shutdown, availability of equipment, tools, material and personnel to respond to the emergency, training, etc. | Review annually during O&M Plan. | N | ||
| Pipeline | Procedures | Procedure | PHMSA | 49 CFR Part 192 | Subpart L - 192.616 & API-RP-1162 | TBD | Public Awareness: Each pipeline operator must develop and implement a written continuing public education program that follows the guidance provided in the API-RP-1162. The operator's program must specifically include provisions to educate the public, appropriate government organizations, and persons engaged in excavation related activities. | Public awareness messages twice annually. | N | ||
| Pipeline | Procedures | Management of Change | Best Practice | ASME 31.8S | 31.8S.11 | Both | Formal management of change procedures shall be developed in order to identify and consider the impact of changes to pipeline systems and their integrity. | As required when changes are made to the facility | N | ||
| Pipeline | Reports | Incident Reporting | PHMSA | 49 CFR Part 191 | 191.15 | TBD | Incident Reports: Each operator must submit DOT Form PHMSA F 7100.2 as soon as practicable but not more than 30 days after detection of an incident. | After incident - 30 day max to submit Form F 71000.2 | N | ||
| Pipeline | Reports | Annual Report | PHMSA | 49 CFR Part 191 | 191.15 | TBD | Annual Report: Each operator must submit an annual report for that system on DOT Form PHMSA F 7100.2-1. | Annually- no later than March 15, for the preceding calendar year | N | ||
| Pipeline | Qualifications & Training | Qualifications & Training | PHMSA | 49 CFR 192 | Subpart N | TBD | Operator Qualification (OQ) Program: Minimum requirements for qualification of individuals performing covered operations/maintenance tasks on a pipeline facility. | Ongoing- Current qualification shall be maintained while the individual is performing the covered task. | N | ||
| Metering Building | Gas Analyzers | Process Gas Composition to Cliffside Plant | Best Practice | OEM Recommendation | OEM Recommendation | Both | Calibration and filter change of GC analyzer per manufacture recommendations | Calibration- Monthly / Filter Changes- Annually | N | ||
| Metering Building | Gas Analyzers | Process Gas Composition to Cliffside Plant | Best Practice | OEM Recommendation | OEM Recommendation | Both | Calibration of O2 and LEL Detectors in GC buildings | Annual | Y | ||
| Pipeline | GC Analyzers | Gas Composition in Pipeline | Best Practice | OEM Recommendation | OEM Recommendation | Both | Calibration and filter change of GC analyzer per manufacture recommendations | Calibration- Monthly / Filter Changes- Annually | N | ||
| Pipeline | GC Analyzers | Gas Composition in Pipeline | Best Practice | OEM Recommendation | OEM Recommendation | Both | Calibration of O2 and LEL Detectors in GC buildings | Annual | Y | ||
| Wellhead / Gathering | Underground Gas Storage | Permit | TX RRC | 16 TAC 3 | Statewide Rule 97.b | ||||||
| Private Only | No person may operate an underground gas storage facility without obtaining a permit from the TRRC | one time event | N | ||||||||
| Wellhead / Gathering | Underground Gas Storage | Ownership Transfer FORM P-4 | TX RRC | 16 TAC 3 | Statewide Rule 97.g | ||||||
| Private Only | A storage facility permit may not be transferred without TRRC approval. | one time event | N | ||||||||
| Wellhead / Gathering | Injection/Withdrawal Wells | ||||||||||
| Monitoring | TX RRC | Monitoring | |||||||||
| 16 TAC 3 | Statewide Rule 97.h.1 | ||||||||||
| Private Only | All gas injection and withdrawal activities shall be monitored by an experienced and trained individual. Any facility that is unattended during injection and withdrawal activities shall have company personnel on call at all times. On-call personnel must be able to reach the facility within 30 minutes from the time a potential problem is noted. | Continuously monitored | N | ||||||||
| Wellhead / Gathering | Injection/Withdrawal Wells | ||||||||||
| Emergency Shutdown Valve | TX RRC | 16 TAC 3 | Statewide Rule 97.h2.B.iii. | ||||||||
| Private Only | Each emergency shutdown valve shall be closed /opened at least monthly. | Monthly | N | ||||||||
| Wellhead / Gathering | Injection/Withdrawal Wells | ||||||||||
| Emergency Shutdown Valve | TX RRC | 16 TAC 3 | Statewide Rule 3.97h.2.B.iv | ||||||||
| Private Only | Each emergency shutdown valve system shall be tested. The test shall consist of activating the actuation devices, checking the warning system, and observing the valve closure. | twice each calendar year at intervals not to exceed 7 1/2 months, while in active service | N | ||||||||
| Wellhead / Gathering | Injection/Withdrawal Wells | ||||||||||
| Leak or fire detectors | TX RRC | 16 TAC 3 | Statewide Rule 3.97.h.5.B | ||||||||
| Private Only | Leak or fire detectors installed at each storage well and structurally closed compressor site shall be tested and when defective, repaired or replaced within 10 days. | tested twice each calendar year at intervals not to exceed 7 1/2 months | Y | ||||||||
| Wellhead / Gathering | Injection/Withdrawal Wells | ||||||||||
| Warning Systems & Alarms | TX RRC | 16 TAC 3 | Statewide Rule 3.97.h.6 | ||||||||
| Private Only | Alarm system for shutdown valve and leak/fire detectors | twice each calendar year at intervals not to exceed 7 1/2 months | Y | ||||||||
| Wellhead / Gathering | Injection/Withdrawal Wells | ||||||||||
| Facility Emergency Response Plan | TX RRC | 16 TAC 3 | Statewide Rule 3.97.h.7 | ||||||||
| Private Only | Emergency Response Plan shall be submitted to TRRC and LEPC (Local Emergency Planning Committee) and updated. | Updated as changes in safety features at the facility occur, or as the Commission or its designee requires. | N | ||||||||
| Wellhead / Gathering | Injection/Withdrawal Wells | ||||||||||
| Uncontrolled Release Notification | TX RRC | 16 TAC 3 | Statewide Rule 3.97.h.8 | ||||||||
| Private Only | Notification of uncontrolled release to TRRC and local authorities ASAP and submit report to TRRC | Notification - as soon as practicable. | |||||||||
| Report - within 30 days | N | ||||||||||
| Wellhead / Gathering | Injection/Withdrawal Wells | ||||||||||
| Emergency Drills | TX RRC | 16 TAC 3 | Statewide Rule 3.97.h.9 | ||||||||
| Private Only | Operator shall conduct a drill that tests response to a simulated emergency and file a written evaluation of the drill and plans for improvements | Drill - annually, and submit written evaluation within 30 days | N | ||||||||
| Wellhead / Gathering | Injection/Withdrawal Wells | ||||||||||
| Employee and Contractor Safety Training | TX RRC | 16 TAC 3 | Statewide Rule 3.97.h.10 | ||||||||
| Private Only | Prepare and implement operational safety training for each employee at facility and each contractor | Contractor - prior to commencement of new contract work at facility | N | ||||||||
| Wellhead / Gathering | Injection/withdrawal well | Operating Pressure | TX RRC | 16 TAC 3 | Statewide Rule 3.97.k.1,2,&l.3 | ||||||
| Private Only | The operating pressure of each gas storage well shall not exceed the permitted maximum allowable operating pressure for that well. The maximum operating pressure at the casing seat shall not exceed 0.85 pounds per square inch per foot of depth. The permitted maximum allowable operating pressure is that pressure specified in the Commission permit or order, or that pressure stated in the application or the application for amendment to a permit or order. | Continuously monitored - electronically record all liquid and gas pressures and injection volumes and rates at a frequency of at least once per minute, and all actuations of the emergency shutdown valve. | N | ||||||||
| Wellhead / Gathering | Injection/withdrawal well | Monitoring Requirements | TX RRC | 16 TAC 3 | Statewide Rule 3.97.l.1 &3 | ||||||
| Private Only | Gas pressure on the injection/withdrawal casing or tubing or piping connected thereto shall be equipped with a pressure sensor to monitor the wellhead pressure. Pressure sensors shall be integrated electronically with the warning systems, alarms, and emergency shutdown valve actuation system | Continuously monitored - electronically record all liquid and gas pressures and injection volumes and rates at a frequency of at least once per minute, and all actuations of the emergency shutdown valve. | N | ||||||||
| Wellhead / Gathering | Injection/withdrawal well | Monitoring Requirements | TX RRC | 16 TAC 3 | Statewide Rule 3.97.l.2&3 | ||||||
| Private Only | Pressure observation valves. The injection/withdrawal casing or tubing shall be equipped with a pressure observation valve and gauge. The wellhead shall be equipped with a pressure observation valve on each casing annulus so that a gauge may be installed for pressure monitoring. | As required to monitor annulus pressure. | N | ||||||||
| Metering Building | Metering | Monitoring Requirements | TX RRC | 16 TAC 3 | Statewide Rule 3.97.l.3 | ||||||
| Private Only | The volume of gas injected into and withdrawn from each storage well shall be measured by: (A) flow meter for each well; or | ||||||||||
| (B) an alternate method approved by the Commission. | Continuously monitored - electronically record all liquid and gas pressures and injection volumes and rates at a frequency of at least once per minute, and all actuations of the emergency shutdown valve. | N | |||||||||
| Metering Building | Metering | Monitoring Requirements | TX RRC | 16 TAC 3 | Statewide Rule 3.97.l.4 | ||||||
| Private Only | Meters that measure the volume of gas into storage and out of storage shall be recalibrated | at least once per year | N | ||||||||
| Wellhead / Gathering | Injection/withdrawal well | Reporting Requirements | TX RRC | 16 TAC 3 | Statewide Rule 3.97.m.2 | ||||||
| Private Only | The operator shall file a status report for each storage well in accordance with the instructions on the form prescribed by the Commission. | Annually | N | ||||||||
| Wellhead / Gathering | Injection/withdrawal well | Record Retention | TX RRC | 16 TAC 3 | Statewide Rule 3.97.n.1.A. | ||||||
| Private Only | Operations electronic records of storage well pressures, volumes of gases injected and withdrawn, and the inventory of gas in storage. | retain for at least 3 months, recorded at a frequency of at least once per minute. | N | ||||||||
| Wellhead / Gathering | Injection/withdrawal well | ||||||||||
| Reporting Requirements | TX RRC | 16 TAC 3 | Statewide Rule 3.97n.1.B.2 | ||||||||
| Private Only | Operations records reported to the Commission under subsection (m) | retain for at least 5 years, recorded at a frequency of at least once per day. | N | ||||||||
| Wellhead / Gathering | Injection/withdrawal well | ||||||||||
| Record Retention | TX RRC | 16 TAC 3 | Statewide Rule 3.97n.1.B.3 | ||||||||
| Both | Construction and maintenance data. The operator shall retain for the life of the facility documents and records pertaining to the drilling, mining, completion, repair and workover of storage wells and the testing of storage well integrity, and shall transfer all such documents and records to any new owner and/or new operator of the facility. | one time event | N | ||||||||
| Wellhead / Gathering | Injection/withdrawal well | Testing & Maintenance | TX RRC | 16 TAC 3 | Statewide Rule 3.97.o.1 | ||||||
| Private Only | Each gas storage well shall be tested for integrity as described in 397.o.1.A-C. | Prior to being placed into service, at least once every five years, and after each workover that involves physical changes to any cemented casing string. | N | ||||||||
| Wellhead / Gathering | Injection/withdrawal well | Testing & Maintenance | TX RRC | 16 TAC 3 | Statewide Rule 3.97.o.1.D | ||||||
| Private Only | The operator shall notify the district office prior to conducting any integrity test. | at least 5 days prior | N | ||||||||
| Wellhead / Gathering | Injection/withdrawal well | Testing & Maintenance | TX RRC | 16 TAC 3 | Statewide Rule 3.97.o.1.E | ||||||
| Private Only | A complete record of each integrity test shall be filed in duplicate with the district office . | Within 30 days after testing is completed | N | ||||||||
| Wellhead / Gathering | Injection/withdrawal well | Testing & Maintenance | TX RRC | 16 TAC 3 | Statewide Rule 3.97.o.2 | ||||||
| Private Only | Storage wellhead components and casing shall be inspected for corrosion, cracks, deformations, or other conditions that may compromise integrity and that may not be detected by the five-year integrity test. The operator may request an extension of up to five years from the Commission for good cause. | at least once every 15 years. | N | ||||||||
| Wellhead / Gathering | Gas Surface Piping, including Drip Station piping | Testing & Maintenance | TX RRC | 16 TAC 3 | Statewide Rule 3.97.o.4 | ||||||
| Private Only | In conjunction with the storage well integrity testing, all gas surface piping shall be maintained in conjunction with the storage well integrity testing and according to piping integrity management plan. | every 5 years. | N | ||||||||
| Wellhead / Gathering | Injection/withdrawal well | Plugging | TX RRC | 16 TAC 3 | Statewide Rule 3.97.p.1&2 | Private Only | A gas storage well shall be plugged upon permanent abandonment or with TRRC approval it can be converted to a monitoring well. | Upon permanent abandonment | N | ||
| Wellhead / Gathering | Injection/withdrawal well | Well Cellar | TX RRC | n/a | n/a | n/a | Not regulated | n/a | n/a | ||
| Wellhead / Gathering | Drip Station Aboveground Storage Tank | Oily water from drip stations. | TX RRC | 16 TAC 3 | Statewide Rule 8. 3.8.f & 3.8.g | Private Only | Oil and gas waste transporter must have TRRC O&G waste hauler permit. | ||||
| Recordkeeping - keep the following information for 3 years: BLM storage location, disposal facility, hauler name & permit No., type & volume of waste; may be in the form of run ticket, invoice, or other. | tbd | ||||||||||
| Pipeline (main) | Asbestos-wrapped Pipeline | Asbestos Containing Material Disposal | TCEQ | 30 TAC 330 | 171.c.3&4 | Both | Management and disposal options for special waste: | ||||
| 1. | Asbestos: There are two types of asbestos waste—regulated |
(friable) and non-regulated (not friable) asbestos-containing material (RACM and non-RACM) as defined in 40 CFR Part 61 Section 141. Also, the amount of asbestos in the material contributes to the type of asbestos waste. Non-RACM may become RACM if subject to sanding, grinding, cutting, or abrading, or it has a high probability of being reduced to powder during demolition or renovation.
a. RACM is friable asbestos-containing material that contains greater than 1 percent asbestos. Friable is defined as asbestos containing material that, when dry, can be crushed to a powder by hand pressure. RACM may be disposed of at a Type I or Type I arid exempt (AE) MSW landfill in accordance with 30 TAC 330.171(c)(3).
| b. Non-RACM is material containing less than one percent asbestos or non-friable asbestos-containing material not identified as regulated. Non-RACM may be disposed of at any MSW landfill provided the facility is authorized to accept the waste in accordance with 30 TAC 330.171(c)(4). | as needed | n/a | ||||||||
| Pipeline (main) | Asbestos-wrapped Pipeline | Asbestos Abatement | USEPA | |||||||
| NESHAP | Subpart M | Both | If exposing 260 linear feet of pipe to atmosphere for maintenance activities, ensure operations follow the NESHAP Subpart M requirements of emissions abatement (wetting pipeline, sealing exposed pipeline in leak-proof material, proper disposal) | As event occurs | N | |||||
| Wellhead / Gathering | Piping | Maintenance / Startup / Shutdown | TCEQ | 30 Part 1 Ch. 106 Subchapter O | RULE §106.355/106.359 | Both | Maintain records of any Maintenance/Startup/Shutdown (MSS) venting and obtain permit prior to venting if uncontrolled emissions would exceed 1 tons per year (TPY) VOC or NOx | As event occurs | N |
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