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pdfNOTICE: This report is required by 49 CFR Part 191. Failure to report can result in a civil penalty as provided in 49
USC 60122.
INCIDENT REPORT – GAS DISTRIBUTION
SYSTEM
U.S. Department of Transportation
Pipeline and Hazardous Materials
Safety Administration
OMB NO: 2137-0635
EXPIRATION DATE: 06/30/2026
Report Date
No.
(DOT Use Only)
A federal agency may not conduct or sponsor, and a person is not required to respond to, nor shall a person be subject to a penalty for failure to
comply with a collection of information subject to the requirements of the Paperwork Reduction Act unless that collection of information displays a
current valid OMB Control Number. The OMB Control Number for this information collection is 2137-0635. Public reporting for this collection of
information is estimated to be approximately 12 hours per response, including the time for reviewing instructions, gathering the data needed, and
completing and reviewing the collection of information. All responses to this collection of information are mandatory. Send comments regarding
this burden estimate or any other aspect of this collection of information, including suggestions for reducing this burden to: Information Collection
Clearance Officer, PHMSA, Office of Pipeline Safety (PHP-30) 1200 New Jersey Avenue, SE, Washington, D.C. 20590.
INSTRUCTIONS
Important: Please read the separate instructions for completing this form before you begin. They clarify the information requested and provide specific
examples. If you do not have a copy of the instructions, you can obtain one from the PHMSA Pipeline Safety Community Web Page at
http://www.phmsa.dot.gov/pipeline/library/forms.
PART A – KEY REPORT INFORMATION
Report Type: (select all that apply)
Original
Supplemental
Final
A1. Operator’s OPS-issued Operator Identification Number (OPID):
A2. Name of Operator: auto-populated based on OPID
A3. Address of Operator
A3a. Street Address: auto-populated based on OPID
A3c. State: auto-populated based on OPID
A3b. City: auto-populated based on OPID
A3d. Zip Code: auto-populated based on OPID
A4. Local time (24-hr clock) and date of incident:
Hour
Month
A4a. Time Zone for local time (select only one)
Day
Year
Alaska Eastern Central Hawaii-Aleutian
Mountain Pacific.
A4b. Daylight Saving in effect? Yes No
A5. Location of Incident:
A5a. ___________________________________________________ (Street Address or location description)
A5b. ___________________________________________________ (City)
A5c. ___________________________________________________ (County or Parish)
State:
A5f. Latitude:
A5e. Zip Code:
Longitude: -
A6. Gas released : (select only one, based on predominant volume released)
Natural Gas
Propane Gas
Synthetic Gas
Hydrogen Gas
A7. Estimated volume of gas released unintentionally:
Landfill Gas
Other Gas Name:
thousand standard cubic feet (mcf)
A8. Estimated volume of intentional and controlled release/blowdown:
thousand standard cubic feet (mcf)
A9. Were there fatalities?
Yes No
A10. Were there injuries requiring inpatient hospitalization?
Yes No
If Yes, specify the number in each category:
If Yes, specify the number in each category:
A9a. Operator employees:
A10a. Operator employees:
A9b. Contractor employees working for the Operator:
A10b. Contractor employees working for the Operator:
A9c. Non-Operator emergency responders:
A10c. Non-Operator emergency responders:
A9d. Workers working on the right-of-way, but NOT associated with
this Operator:
A10d. Workers working on the
associated with this Operator:
A9e. General public:
A10e. General public:
A9f. Total fatalities (sum of above): calculated
A10f. Total injuries (sum of above): calculated
Form PHMSA F 7100.1 (rev 6-2023)
Reproduction of this form is permitted
right-of-way, but NOT
Page 1 of 17
A11. What was the Operator’s initial indication of the Failure? (select only one)
SCADA-based information (such as alarm(s), alert(s), event(s), and/or volume or pack calculations)
Static Shut-in Test or Other Pressure or Leak Test
Controller
Local Operating Personnel, including contractors
Air Patrol
Ground Patrol by Operator or its contractor
Notification from Public
Notification from Emergency Responder
Notification from Third Party that caused the Incident
Other:
A11a. If “Controller”, “Local Operating Personnel, including contractors”, “Air Patrol”, or “Ground Patrol by Operator or its contractor” is selected in
Question A11, specify the following: (select only one)
Operator employee
Contractor working for the Operator
A12. Local time operator identified failure
Hour
Month
Day
Year
If A11 = Notification from Emergency Responder, skip questions A13 through A15.
A13. Did the operator communicate with Local, State, or Federal Emergency Responders about the incident?
Yes
No
If No, skip A14 and A15
A14. Which party-initiated communication about the incident? Operator
Local/State/Federal Emergency Responder
A15. Local time of initial Operator and Local/State/Federal Emergency Responder communication
Hour
Month
Day
Year
Day
Year
A16. Local time operator resources arrived on site
Hour
Month
A17. Local time of confirmed discovery
/
/
/ /
Hour
/
/
/ /
Month
/
/ /
Day
/
/ /
Year
A18. Local time (24-hr clock) and date of initial operator report to the National Response Center:
Hour
Month
Day
Year
A19. Initial Operator National Response Center Report Number OR NRC Notification Required But Not Made
A19a. Additional NRC Report numbers submitted by the operator: _____________________
A20. Method of Flow Control (select all that apply)
“Key/Critical” Valve – inspected in accordance with Part 192.747
Service (curb) Valve
Meter/Regulator shut-off Valve
Squeeze-Off
Stopple fitting
A21. Did the gas ignite?
Yes
Main Valve other than “Key/Critical”
Excess flow valve
Other:
No
If A21 = Yes, answer A21a through A21d.
A21a. Local time of ignition
Hour
Month
Day
Year
A21b. How was the fire extinguished?
Operator/Contractor Local/State/Federal Emergency Responder
A21c. Estimated volume of gas consumed by fire (MCF):
A21d. Did the gas explode?
Yes
Allowed to burn out
Other, specify: _________
(must be less than or equal to A7)
No
A22. Number of general public evacuated:
Form PHMSA F 7100.1 (rev 6-2023)
Reproduction of this form is permitted
Page 2 of 17
PART B – ADDITIONAL LOCATION INFORMATION
B1. Was the Incident on Federal land?
Yes
No
B2. Location of Incident: (select only one)
Operator-controlled property
Public property
Private property
Utility Right-of-Way / Easement
B3. Area of Incident: (select only one)
Underground Specify:
Under soil
Under a building
Under pavement
Exposed due to excavation
In underground enclosed space (e.g., vault)
Exposed due to loss cover
Other ____________________________
B3a. Depth-of-Cover (in):
B3b. Were other underground facilities found within 12 inches of the failure location? Yes No
Aboveground Specify:
Typical aboveground facility piping or appurtenance (e.g., valve or regulator station, outdoor meter set)
Overhead crossing
In or spanning an open ditch
Inside a building
In other enclosed space
Other __________________
Transition Area Specify: Soil/air interface
Wall sleeve
Pipe support or other close contact area
Other _______________
B4. Did Incident occur in a crossing? Yes
No
If Yes, specify type below:
Bridge crossing, Specify:
Cased
Uncased
Railroad crossing (Select all that apply)
Cased
Uncased
Bored/drilled
Road crossing (Select all that apply)
Cased
Uncased
Bored/drilled
Water crossing (Select all that apply)
Cased
Uncased
Bored/drilled
Name of body of water (If commonly known): _________________________
Approx. water depth at time and location of Incident (ft):
or Unknown
(select only one of the following)
Shoreline/Bank/Marsh crossing
Below water, pipe in bored/drilled crossing
Below water, pipe buried below bottom (NOT in bored/drilled crossing)
Below water, pipe on or above bottom
PART C – ADDITIONAL FACILITY INFORMATION
C1. Indicate the type of pipeline system:
privately owned
municipally owned
investor owned
C2. Part of system involved in Incident: (select only one)
Main
Main Valve
Service
Service Valve
Inside Meter/Regulator set
Farm Tap Meter/Regulator set
Other mandatory text field ____
_____
C2a. Year item involved in the incident was installed:
cooperative
Other Specify:
Service Riser
Outside Meter/Regulator set
District Regulator/Metering Station
or Unknown
C2b. Year item involved in the incident was manufactured:
or Unknown
When C2.is any value other than “Main”, “Main Valve”, “District Regulator/Metering Station”, or “Other”:
C2c. Indicate the customer type: (select only one)
Single Family Residential
Non-Residential with Meter capacity less than 1,000 scfh
Multi-Family Residential
Non-Residential with Meter Capacity 1,000 scfh of higher
C2d. Was an EFV installed on the service line before the time of the incident? Yes
If C2d = Yes, then C2e. Did the EFV activate?
Yes
No
No
Unable to determine
C2f. Was a curb valve installed on the service line before the time of the incident? Yes
No
C3. When C2. is “Main” or “Service” answer C3a through c and C4:
C3a. Nominal Pipe Size:
/
/
/./
/
/
/
C3b. Pipe specification (e.g., API 5L, ASTM D2513): ___________________
OR Unknown
C3c. Pipe manufacturer: ______________________ or Unknown
C4. Material involved in Incident: Steel
Cast/Wrought Iron
Ductile Iron
Copper
Plastic
Reconditioned Cast Iron
Unknown
Other Specify: _________________________
C4a. If Steel Specify seam type:
Longitudinal ERW - High Frequency Single SAW Flash Welded DSAW Longitudinal ERW - Low Frequency
Continuous Welded
Furnace Butt Welded
Longitudinal ERW – Unknown Frequency
Spiral Welded
Lap Welded
Seamless Other Specify: ________________
C4b. If Steel Specify wall thickness (inches): /
Form PHMSA F 7100.1 (rev 6-2023)
/./
/
/
/
or Unknown
Reproduction of this form is permitted
Page 3 of 17
C4c. If Plastic Specify type: Polyvinyl Chloride (PVC)
Polyethylene (PE)
Cross-linked Polyethylene (PEX)
Polybutylene (PB)
Polypropylene (PP)
Acrylonitrile Butadiene Styrene (ABS)
Polyamide (PA)
Cellulose Acetate Butyrate (CAB)
Other Specify: _______________________________________________
Unknown
C4d. If Plastic Specify Standard Dimension Ratio (SDR): /
/
/
/
/
or wall thickness: /
C4e. If Polyethylene (PE) is selected as the type of plastic in PART C, Question 4.c
Specify PE Pipe Material Designation Code (i.e., 2406, 3408, etc.) PE / / / / /
/./
/
/
/
or Unknown
or Unknown
C5. Type of release involved: (select only one)
Mechanical Puncture Approx. size: /__/__/__/__/./__/in. (axial) by /__/__/__/__/./__/in. (circumferential)
Leak Select Type: Pinhole
Crack
Connection Failure
Seal or Packing
Other
Rupture Select Orientation: Circumferential
Longitudinal
Other ________________________________
Approx. size: /__/__/__/__/./__/ in. (widest opening) by /__/__/__/__/__/./__/in. (length circumferentially or axially)
Other *Describe: ___________________________________________________________________
Form PHMSA F 7100.1 (rev 6-2023)
Reproduction of this form is permitted
Page 4 of 17
PART D – ADDITIONAL CONSEQUENCE INFORMATION
D1. Class Location of Incident: (select only one)
Class 1 Location
Class 2 Location
Class 3 Location
Class 4 Location
D2. Estimated Property Damage :
D2a. Estimated cost of public and non-Operator private property damage
$/
/
/
/,/
/
/
/,/
/
/
/
D2b. Estimated cost of Operator’s property damage & repairs
$/
/
/
/,/
/
/
/,/
/
/
/
/
/,/
/
/
/,/
/
/
/
/,/
/
/,/
/
D2c. Estimated cost of emergency response
$/
D2d. Estimated other costs
/
$/
/
/
/
/
/
Describe: ___________________________________________________
D2e. Total estimated property damage (sum of above)
$ calculated
Cost of Gas Released
Cost of Gas in $ per thousand standard cubic feet (mcf):______________
D2f. Estimated cost of gas released unintentionally
$ calculated
D2g. Estimated cost of gas released intentionally during controlled release/blowdown
$ calculated
D2h. Total estimated cost of gas released (sum of D2f and g)
$ calculated
D2i. Estimated Total Cost (sum of D2e and D2h)
$ calculated
D3. Estimated number of customers out of service:
D3a. Commercial entities /
/,/
/
/
/
D3b. Industrial entities
/
/,/
/
/
/
D3c. Residences
/
/,/
/
/
/
Injured Persons not included in A10 The number of persons injured, admitted to a hospital, and remaining in the hospital for at least one overnight
are reported in A10. If a person is included in A10, do not include them in D4.
D4. Estimated number of persons with injuries requiring treatment in a medical facility but not requiring overnight in-patient hospitalization:
If a person is included in D4, do not include them in D5.
D5. Estimated number of persons with injuries requiring treatment by EMTs at the site of incident:
Buildings Affected
D6. Number of residential buildings affected (evacuated or required repair or had gas service interrupted):
D7. Number of business buildings affected (evacuated or required repair or had gas service interrupted):
Form PHMSA F 7100.1 (rev 6-2023)
Reproduction of this form is permitted
Page 5 of 17
PART E – ADDITIONAL OPERATING INFORMATION
E1. Estimated pressure at the point and time of the Incident (psig):
/
/
/
/
/
E2. Normal operating pressure at the point and time of the Incident (psig):
/
/
/
/
/
E3. Maximum Allowable Operating Pressure (MAOP) at the point and time of the Incident (psig):
/
/
/
/
/
E3a. MAOP established by 49 CFR section:
� 192.619 (a)(1) � 192. 619 (a)(2) � 192. 619 (a)(3)
� 192.621m
� 192.623
� 192.619 (a)(4)
E3b. Date MAOP established:
/
/
/
/
/ /
Month
/ /
Day
/
� 192. 619 (c)
Year
E4. Describe the pressure on the system relating to the Incident: (select only one)
Pressure did not exceed MAOP
Pressure exceeded MAOP, but did not exceed the applicable allowance in §192.201
Pressure exceeded the applicable allowance in §192.201
E5. Type of odorization system for gas at the point of failure:
� none � d r i p � i n j e c t i o n p u m p � b y - p a s s � wick
� combination of odorization types � o d o r i z e d b y o t h e r s
� Other, specify:
E6. Odorant level near the point of failure measured after the failure:
%LEL OR
Not Measured
E7. Was a Supervisory Control and Data Acquisition (SCADA)-based system in place on the pipeline or facility involved in the Incident?
No
Yes E7a. Was it operating at the time of the Incident?
Yes
No
E7b. Was it fully functional at the time of the Incident?
Yes
No
E7c. Did SCADA-based information (such as alarm(s), alert(s), event(s), and/or volume or pack calculations) assist with the initial indication of the
Incident?
Yes
No
E7d. Did SCADA-based information (such as alarm(s), alert(s), event(s), and/or volume calculations) assist with the
discovery of the Incident?
Yes
No
confirmed
E8. Was an investigation initiated into whether or not the controller(s) or control room issues were the cause of or a contributing factor to the Incident?
(select only one)
Yes, but the investigation of the control room and/or controller actions has not yet been completed by the operator (Supplemental Report required)
No, the facility was not monitored by a controller(s) at the time of the Incident
No, the operator did not find that an investigation of the controller(s) actions or control room issues was necessary due to:
(provide an explanation for why the operator did not investigate)
_________________________________________________________________________________________________________________________
_________________________________________________________________________________________________________________________
____________________________________________________________________________
Yes, Specify investigation result(s): (select all that apply)
Investigation reviewed work schedule rotations, continuous hours of service (while working for the Operator) and other factors associated
with fatigue
Investigation did NOT review work schedule rotations, continuous hours of service (while working for the Operator) and other factors
associated with fatigue (provide an explanation for why not)
_________________________________________________________________________________________________________________________
_________________________________________________________________________________________________________________________
_____________________________________________________________
Investigation identified no control room issues
Investigation identified no controller issues
Investigation identified incorrect controller action or controller error
Investigation identified that fatigue may have affected the controller(s) involved or impacted the involved controller(s) response
Investigation identified incorrect procedures
Investigation identified incorrect control room equipment operation
Investigation identified maintenance activities that affected control room operations, procedures, and/or controller response
Investigation identified areas other than those above Describe: ___________________________________________
Form PHMSA F 7100.1 (rev 6-2023)
Reproduction of this form is permitted
Page 6 of 17
PART F – DRUG & ALCOHOL TESTING INFORMATION
F1. As a result of this Incident, were any Operator employees tested under the post-accident drug and alcohol testing requirements of DOT’s Drug &
Alcohol Testing regulations?
No
Yes F1a. Specify how many were tested:
F1b. Specify how many failed:
/
/
/
/
/
/
F2. As a result of this Incident, were any Operator contractor employees tested under the post-accident drug and alcohol testing requirements of DOT’s
Drug & Alcohol Testing regulations?
No
Yes F2a. Specify how many were tested:
/
/
F2b. Specify how many failed:
Form PHMSA F 7100.1 (rev 6-2023)
/
/
/
/
Reproduction of this form is permitted
Page 7 of 17
PART G – APPARENT CAUSE Select only one box from PART G in the shaded column on the left representing the APPARENT Cause of the
Incident, and answer the questions on the right. Enter secondary, contributing, or root causes of the Incident in Part J – Contributing Factors
G1 – Corrosion Failure – only one sub-cause can be picked from shaded left-hand column
External
Corrosion
1. Results of visual examination:
Localized Pitting
General Corrosion
Other _____________________
2. Type of corrosion: (select all that apply):
Galvanic
Atmospheric
Stray Current
Other _____________________
2a. If 2. is Stray Current, specify:
Microbiological
Alternating Current
Selective Seam
Direct Current
AND
2b. Describe the stray current source: _______________________
3. The type(s) of corrosion selected in Question 2 is based on the following: (select all that apply)
Field examination
Determined by metallurgical analysis
Other _______________________
4. Was the failed item buried or submerged?
Yes
4a. Was failed item considered to be under cathodic protection at the time of the incident?
Yes
No
Year protection started:
/
/
/
/
/
4b. Was shielding, tenting, or disbonding of coating evident at the point of the incident?
Yes
No
4c. Has one or more Cathodic Protection Survey been conducted at the point of the incident?
(select all that apply)
Yes, CP Annual Survey Most recent year conducted:
/ / / / /
Yes, Close Interval Survey Most recent year conducted:
Yes, Other CP Survey Most recent year conducted:
No
No
/
/
/
/
/
/
/
/
/
/
Describe Other CP Survey:
4d. Was the failed item externally coated or painted?
Yes
No
5. Was there observable damage to the coating or paint in the vicinity of the corrosion?
Yes No N/A Bare/Ineffectively Coated Pipe
6. Pipeline coating type, if steel pipe is involved: (select only one)
Epoxy
Coal Tar
Asphalt
Cold Applied Tape
Paint
Composite
Unknown
6a. Field Applied?
Form PHMSA F 7100.1 (rev 6-2023)
Polyolefin
None
Extruded Polyethylene
Other ________________
Y, N, or Unknown
Reproduction of this form is permitted
Page 8 of 17
Internal
Corrosion
7. Results of visual examination:
Localized Pitting
General Corrosion
Not cut open
8. Cause of corrosion: (select all that apply)
Corrosive Commodity
Water drop-out/Acid
Other ___________
Other ________________
Microbiological Erosion
9. The cause(s) of corrosion selected in Question 8 is based on the following; (select all that apply)
Field examination
Determined by metallurgical analysis
Other ________________
10. Location of corrosion: (select all that apply)
Low point in pipe
Elbow
Drop-out
11. Was the gas/fluid treated with corrosion inhibitors or biocides?
Other ________________________
Yes
No
12. Were any liquids found in the distribution system where the Incident occurred?
Yes
No
Complete the following if any Corrosion Failure sub-cause is selected AND the “Part of system involved in Incident” (from PART C, Question 2)
is Main, Service, or Service Riser.
13. Date of the most recent Leak Survey conducted:
/
/
Month
/
/
/
Day
/
/
/
Year
/
14. Has one or more pressure test been conducted since original construction at the point of the Incident?
Yes Most recent year tested: / / / / /
Test pressure (psig): /
/
/
/
/
/
No
G2 – Natural Force Damage – only one sub-cause can be picked from shaded left-handed column
Earth Movement, NOT due to
Heavy Rains/Floods
1. Specify:
Earthquake
Other ___________________
Heavy Rains/Floods
2. Specify:
Washouts/Scouring
Other ________________
Lightning
3. Specify:
Temperature
Thermal Stress
4. Specify:
Other ________________________________
High Winds
Tree/Vegetation Roots
Damage from Snow/Ice Impact or Accumulation
Other Natural Force Damage
Direct hit
Subsidence
Landslide
Flotation
Mudslide
Secondary impact such as resulting nearby fires
Frost Heave
Frozen Components
5. Describe: _________________________________________________
Complete the following if any Natural Force Damage sub-cause is selected.
6. Were the natural forces causing the Incident generated in conjunction with an extreme weather event?
6.a. If Yes, specify: (select all that apply)
Form PHMSA F 7100.1 (rev 6-2023)
Yes
No
Hurricane
Tropical Storm
Tornado
Other ______________________________
Reproduction of this form is permitted
Page 9 of 17
G3 – Excavation Damage – only one sub-cause can be picked from shaded left-hand column
Excavation Damage by Operator (First Party)
Excavation Damage by Operator’s Contractor (Second Party)
Excavation Damage by Third Party
Previous Damage due to Excavation Activity
Complete the following ONLY IF the “Part of system involved in Incident” (from PART C, Question 2) is Main, Service, or Service Riser.
1. Date of the most recent Leak Survey conducted:
/
/
/
/ /
Month
/
/ /
Day
/
Year
2. Has one or more pressure test been conducted since original construction at the point of the Incident?
Yes Most recent year tested: / / / / /
Test pressure (psig):
/
/
/
/
/
/
No
Complete the following if any Excavation Damage sub-cause is selected.
3. Did the operator get prior notification of the excavation activity?
Yes No
3a. If Yes, Notification received from: (select all that apply) One-Call System Excavator Contractor Landowner
3b. Per the primary Incident Investigator report, did State law exempt the excavator from notifying the one-call center? Yes No Unknown
If yes, answer 3c through 3e.
Excavator is exempt
3c. (select only one)
Activity is exempt and did not exceed the limits of the exemption
Activity is exempt and exceeded the limits of the exemption
Other mandatory text field:
3d. Exempting Authority: ________________
3e. Exempting Criteria: _______________________
4. Do you want PHMSA to upload the following information to CGA-DIRT (www.cga-dirt.com)?
Yes
No
5. Right-of-Way where event occurred: (select all that apply)
Public Specify: City Street State Highway County Road Interstate Highway
Private Specify: Private Landowner Private Business Private Easement
Pipeline Property/Easement
Power/Transmission Line
Railroad
Dedicated Public Utility Easement
Federal Land
Unknown/Other
6 Was the facility part of a Joint Trench? Yes
7. Did this event involve a Cross Bore? Yes
Other
No
No
8. Measured Depth from Grade: (select only one)
Embedded in Concrete/Asphalt Pavement <18”
18” – 36”
>36”
Measured depth From Grade in inches:__________
9. Type of excavator: (select only one)
Contractor
Railroad
County
State
Developer
Utility
Farmer
Municipality
Unknown/Other
Occupant
10. Type of excavation equipment: (select only one)
Auger
Explosives
Probing Device
Backhoe/Trackhoe
Farm Equipment
Trencher
Boring
Grader/Scraper
Vacuum Equipment
Drilling
Hand Tools
Unknown/Other
Directional Drilling
Milling Equipment
11. Type of work performed: (select only one)
Agriculture
Drainage
Grading
Cable TV
Driveway
Irrigation
Curb/Sidewalk
Electric
Landscaping
Building Construction
Engineering/Surveying
Liquid Pipeline
Natural Gas
Pole
Public Transit Authority
Railroad Maintenance
Sewer (Sanitary/Storm) Site Development
Steam
Storm Drain/Culvert
Telecommunications
Traffic Signal
Traffic Sign
Water
Unknown/Other
12. Was the One-Call Center notified?
Yes
No If No, skip to question 11
Form PHMSA F 7100.1 (rev 6-2023)
Reproduction of this form is permitted
Building Demolition
Fencing
Milling
Road Work
Street Light
Waterway Improvement
Page 10 of 17
12a. If Yes, specify ticket number: /
/
/
/
/
/
/
/
/
/
/
/
/
/
/
/
/
/
/
12b. If this is a State where more than a single One-Call Center exists, list the name of the One-Call Center notified:
_____________________________________________________________
12c. Was work area white lined?
No
Yes
Unknown
13. Type of Locator:
Facility Owner
Contractor Locator
Unknown/Other
14. Were facility locate marks visible in the area of excavation?
No
Yes
Unknown/Other
15. Did the damage cause an interruption in service?
No
Yes
Unknown/Other
15a. If Yes, specify duration of the interruption:
/___/___/___/___/ hours
16. Description of the CGA-DIRT Root Cause (select the predominant CGA-DIRT Root Cause from the list below):
Notification Issue
No notification made to the One-Call Center/811
☐ Excavator dug outside area described on ticket
☐ Excavator dug prior to valid start date/time
☐ Excavator dug after valid ticket expired
☐ Excavator provided incorrect notification information
Excavation Issue
☐ Excavator dug prior to verifying marks by test-hole (pothole)
☐ Excavator failed to maintain clearance after verifying marks
☐ Excavator failed to protect/shore/support facilities
☐ Improper backfilling practices
☐ Marks faded or not maintained
☐ Improper excavation practice not listed above
Locating Issue
☐ Facility not marked due to Abandoned facility
☐ Facility not marked due to Incorrect facility records/maps
☐ Facility not marked due to Locator error
☐ Facility not marked due to No response from operator/contract locator
☐ Facility not marked due to Incomplete marks at damage location
☐ Facility not marked due to Tracer wire issue
☐ Facility not marked due to Unlocatable Facility
☐ Facility marked inaccurately due to Abandoned facility
☐ Facility marked inaccurately due to Incorrect facility records/maps
☐ Facility marked inaccurately due to Locator error
☐ Facility marked inaccurately due to Tracer wire issue
Miscellaneous Root Causes
☐ Deteriorated facility
☐ One Call Center Error
☐ Previous damage
☐ Root Cause not listed (comment required):
Form PHMSA F 7100.1 (rev 6-2023)
Reproduction of this form is permitted
Page 11 of 17
G4 – Other Outside Force Damage – only one sub-cause can be selected from the shaded left-hand column
Nearby Industrial, Man-made, or Other Fire/Explosion as
Primary Cause of Incident
Damage by Car, Truck, or Other Motorized Vehicle/Equipment
NOT Engaged in Excavation
Damage by Boats, Barges, Drilling Rigs, or Other Maritime
Equipment or Vessels Set Adrift or Which Have Otherwise Lost
Their Mooring
1. Vehicle/Equipment operated by: (select only one)
Operator
Operator’s Contractor
Third Party
If this sub-cause is picked, complete questions 7-13 below.
2. Select one or more of the following IF an extreme weather event
was a factor:
Hurricane
Tropical Storm
Tornado
Heavy Rains/Flood
Other
______________________________
Routine or Normal Fishing or Other Maritime Activity NOT
Engaged in Excavation
Electrical Arcing from Other Equipment or Facility
Previous Mechanical Damage NOT Related to Excavation
Complete the following ONLY IF the “Part of system involved in
Incident” (from PART C, Question 2) is Main, Service, or Service
Riser.
3. Date of the most recent Leak Survey conducted:
/
/ / /
Month
Day
/
/
/
/
Year
4. Has one or more pressure test been conducted since original
construction at the point of the Incident?
Yes Most recent year tested:
/
/
/
/
/
Test pressure (psig):
/
/
/
/
/
/
No
Intentional Damage
5. Specify:
Vandalism
Terrorism
Theft of transported commodity Theft of equipment
Other ________________________________________
Erosion of Support Due to Other Utilities
6. Describe: ________________
Other Outside Force Damage
Complete the following if Damage by Car, Truck, or Other Motorized Vehicle/Equipment NOT Engaged in Excavation sub-cause is selected.
7. Was the driver of the vehicle or equipment issued one or more citations related to the incident?
Yes
No Unknown
If 7. is Yes, what was the nature of the citations (select all that apply)
7a. Excessive Speed
7b. Reckless Driving
7c. Driving Under the Influence
7d. Other, describe: _______________________
8. Was the driver under control of the vehicle at the time of the collision? Yes
No Unknown
9. Estimated speed of the vehicle at the time of impact (miles per hour)?_______________or Unknown
10. Type of vehicle? (select only one)
Motorcycle/ATV
Passenger Car Small Truck
11. Where did the vehicle travel from to hit the pipeline facility? (select only one)
Roadway
Driveway
Parking Lot
Loading Dock
Bus Large Truck
Off-Road
12. Shortest distance from answer in 11. to the damaged pipeline facility (in feet): .________________________
13. At the time of the incident, were protections installed to protect the damaged pipeline facility from vehicular damage?
Yes
No
If 13. is Yes, specify type of protection (select all that apply):
13a. Bollards/Guard Posts
13b. Barricades, including “jersey” barriers and fences
13c. Guard Rails
13d. Meter Box
13e. Ingress or Regress at a Residence
13f. Other, describe: _________________________________
Form PHMSA F 7100.1 (rev 6-2023)
Reproduction of this form is permitted
Page 12 of 17
/
G5 – Pipe, Weld, or Joint Failure – only one sub-cause can be selected from the shaded left-hand column
Body of Pipe
1. Specify:
Butt Weld
Fillet Weld
Dent Gouge Bend Arc Burn Crack
Other ___________________________
2. Specify: Pipe Fabrication Other
________________________________
Branch Hot Tap Fitting Repair Sleeve
Other _______________________________
4. Specify: LF ERW HF ERW Flash Weld DSAW
SAW Spiral
Other 3. Specify:
Pipe Seam
Threaded Metallic Pipe
Mechanical Joint Failure
________________________
5a. Specify the Mechanical Fitting Involved (select only one)
Stab
Nut Follower
Bolted
Other Compression Type Fitting (specify): ______________
5b. Specify the Type of Mechanical Fitting (select only one)
Service or Main Tee
Tapping Tee Transition Fitting
Riser Adapter
Valve
Sleeve
Coupling
End Cap
Other (specify): _____________________
5c. Fitting Manufacturer: ___________________ or Unknown
5d. Part or Model Number:__________________ or Unknown
5e. Fitting Material (select only one)
Steel Plastic Brass Combination Plastic and Steel
Unknown
Other (specify): ______________
5f. How did the joint failure occur? (select only one)
Leaked Through Seal Leaked Through Body
Pulled Out Other (specify): ________________
Fusion Joint
6. Specify: Butt, Heat Fusion Butt, Electrofusion Saddle,
Heat Fusion
Saddle, Electrofusion Socket, Heat Fusion
Socket, Electrofusion
Other _______________________________
7. Year installed:
/
/
/
/
/
8. Other
attributes:________________________________________________
_________
9. Specify the two materials being joined:
9a. First material being joined:
Polyvinyl Chloride (PVC)
Polyethylene (PE)
Cross-linked Polyethylene (PEX)
Polybutylene
(PB)
Polypropylene (PP)
Acrylonitrile Butadiene
Styrene (ABS)
Cellulose Acetate Butyrate (CAB)
Polyamide (PA)
Other Specify:
__________________________________
Other Pipe, Weld, or Joint Failure
Form PHMSA F 7100.1 (rev 6-2023)
9b. Second material being joined:
Polyvinyl Chloride (PVC)
Polyethylene (PE)
Cross-linked Polyethylene (PEX)
Polybutylene
(PB)
Polypropylene (PP)
Acrylonitrile Butadiene
Styrene (ABS)
Cellulose Acetate Butyrate (CAB)
Polyamide (PA)
Other Specify:
__________________________________
10.
Describe:_________________________________________________
_____________
Reproduction of this form is permitted
Page 13 of 17
Complete the following if any Pipe, Weld, or Joint Failure sub-cause is selected.
11. Additional Factors: (select all that apply) Dent Gouge Pipe Bend
Lamination
Buckle
Wrinkle
Misalignment
Other __________________________________
12. Was the Incident a result of:
Construction defect, specify:
Material defect, specify:
Arc Burn Crack
Burnt Steel
Lack of Fusion
Poor workmanship Procedure not followed Poor construction/installation procedures
Long seam Other ___________________________________________________
Design defect
Previous damage
13. Has one or more pressure test been conducted since original construction at the point of the Incident?
Yes
No
Most recent year tested: /
/
/
/
/
Test pressure (psig): /
/
/
/
/
/
G6 – Equipment Failure– only one sub-cause can be selected from the shaded left-hand column
Malfunction of Control/Relief Equipment
1. Specify: (select all that apply)
Control Valve
Instrumentation
SCADA
Communications
Block Valve
Check Valve
Relief Valve
Power Failure
Pressure Regulator
Stopple/Control Fitting
Threaded Connection Failure
Other____________________________________________
2. Specify:
Pipe Collar
Pipe Nipple
3. Specify:
O-Ring
Valve Threads
Threaded
Threaded Fitting Other
___________________________________
Non-threaded Connection Failure
Gasket
Other Seal or Packing
Other_____________________________________________
Valve
4. Specify: Manufacturing defect Other
________________________________
4a. Valve type:
____________________________________
4b. Manufactured by:
________________________________
4c. Year manufactured: /
4d. Valve Material:
Ductile Iron
/
/
/
/ or Unknown
Steel Plastic Cast/Wrought Iron
Other, specify: mandatory text
field______________________
Other Equipment Failure
Form PHMSA F 7100.1 (rev 6-2023)
5. Describe:
________________________________________________________
__________
________________________________________________________
______________________
Reproduction of this form is permitted
Page 14 of 17
G7 – Incorrect Operation – *only one sub-cause can be selected from the shaded left-hand
Damage by Operator or Operator’s Contractor NOT Related
to Excavation and NOT due to Motorized Vehicle/Equipment
Damage
Valve Left or Placed in Wrong Position, but NOT Resulting
in an Overpressure
Pipeline or Equipment Overpressured
Equipment Not Installed Properly
Wrong Equipment Specified or Installed
Other Incorrect Operation
1. Describe: _____________________
Complete the following if any Incorrect Operation sub-cause is selected.
2. Was this Incident related to: (select all that apply)
Inadequate procedure
No procedure established
Failure to follow procedure
Other:* ________________________________________________________
3. What category type was the activity that caused the Incident:
Construction
Commissioning
Decommissioning
Right-of-Way activities
Routine maintenance
Other maintenance
Normal operating conditions
Non-routine operating conditions (abnormal operations or emergencies)
4. Was the task(s) that led to the Incident identified as a covered task in your Operator Qualification Program? Yes
No
4a. If Yes, were the individuals performing the task(s) qualified for the task(s)?
Yes, they were qualified for the task(s)
No, but they were performing the task(s) under the direction and observation of a qualified individual
No, they were not qualified for the task(s) nor were they performing the task(s) under the direction and observation of a qualified
individual
G8 – Other Incident Cause – *only one sub-cause can be selected from the shaded left-hand column
Miscellaneous
Unknown
Form PHMSA F 7100.1 (rev 6-2023)
1. Describe: ___ ________________________________________
2. Specify:
unknown
Investigation complete, cause of Incident
Mandatory comment field:
______________________________
Still under investigation, cause of Incident to be determined*
(*Supplemental Report required)
Reproduction of this form is permitted
Page 15 of 17
PART J – CONTRIBUTING FACTORS
The Apparent Cause of the accident is contained in Part G. Do not report the Apparent Cause again in this Part J. If Contributing Factors were
identified, select all that apply below and explain each in the Narrative:
Pipe/Weld Failure
External Corrosion
Design-related
External Corrosion, Galvanic
Construction-related
External Corrosion, Atmospheric
Installation-related
External Corrosion, Stray Current Induced
Fabrication-related
External Corrosion, Microbiologically Induced
Original Manufacturing-related
External Corrosion, Selective Seam
Equipment Failure
Internal Corrosion
Internal Corrosion, Corrosive Commodity
Malfunction of Control/Relief Equipment
Internal Corrosion, Water drop-out/Acid
Threaded Connection/Coupling Failure
Internal Corrosion, Microbiological
Non-threaded Connection Failure
Internal Corrosion, Erosion
Valve Failure
Natural Forces
Earth Movement, NOT due to Heavy Rains/Floods
Incorrect Operation
Damage by Operator or Operator’s Contractor NOT Excavation
and NOT Vehicle/Equipment Damage
Heavy Rains/Floods
Lightning
Valve Left or Placed in Wrong Position, but NOT Resulting in
Overpressure
Temperature
Pipeline or Equipment Overpressured
High Winds
Equipment Not Installed Properly
Snow/Ice
Wrong Equipment Specified or Installed
Tree/Vegetation Root
Inadequate Procedure
Excavation Damage
Excavation Damage by Operator (First Party)
Excavation Damage by Operator’s Contractor (Second Party)
Excavation Damage by Third Party
No procedure established
Failure to follow procedures
Previous Damage due to Excavation Activity
Other Outside Force
Nearby Industrial, Man-made, or Other Fire/Explosion
Damage by Car, Truck, or Other Motorized Vehicle/Equipment
NOT Engaged in Excavation
Damage by Boats, Barges, Drilling Rigs, or Other Adrift
Maritime Equipment
Routine or Normal Fishing or Other Maritime Activity NOT
Engaged in Excavation
Electrical Arcing from Other Equipment or Facility
Previous Mechanical Damage NOT Related to Excavation
Intentional Damage
Other underground facilities buried within 12 inches of the
failure location
Form PHMSA F 7100.1 (rev 6-2023)
Reproduction of this form is permitted
Page 16 of 17
PART H – NARRATIVE DESCRIPTION OF THE INCIDENT (Attach additional sheets as necessary)
__________________________________________________________________________________________________________________
__________________________________________________________________________________________________________________
__________________________________________________________________________________________________________________
__________________________________________________________________________________________________________________
__________________________________________________________________________________________________________________
__________________________________________________________________________________________________________________
__________________________________________________________________________________________________________________
__________________________________________________________________________________________________________________
__________________________________________________________________________________________________________________
__________________________________________________________________________________________________________________
__________________________________________________________________________________________________________________
__________________________________________________________________________________________________________________
__________________________________________________________________________________________________________________
__________________________________________________________________________________________________________________
PART I – PREPARER AND AUTHORIZED PERSON
Preparer's Name (type or print)
Preparer's Title (type or print)
Preparer’s Telephone Number
Preparer's E-mail Address
Local Contact Name: optional
Local Contact Email: optional
Preparer’s Facsimile Number
Local Contact Phone: optional
Authorized Signer Telephone Number
Authorized Signer
Authorized Signer’s Title
Form PHMSA F 7100.1 (rev 6-2023)
Authorized Signer’s E-mail Address
Reproduction of this form is permitted
Page 17 of 17
Instructions (rev 6-2023) for Form PHMSA F 7100.1 (rev 6-2023)
INCIDENT REPORT – GAS DISTRIBUTION SYSTEMS
GENERAL INSTRUCTIONS
Each operator of a gas distribution system shall file Form PHMSA F 7100.1 for an Incident that
meets the criteria in 49 CFR §191.3 as soon as practicable but not more than 30 days after
detection of the incident. Requirements for submitting reports are in §191.7 and §191.9.
Master meter operators are exempt from filing incident reports per §191.9(c).
The intentional and controlled release of gas for the purpose of maintenance or other routine
operating activities need not be reported if the only reportable criterion is unintentional loss of
gas of 3 million cubic feet or more as described in §191.3 under “Incident” (1)(iii).
Special considerations apply when a gas distribution system failure or release occurs that involves
secondary ignition of the gas system. Secondary ignition is a fire where the origin of the fire is
unrelated to the gas systems subject to Parts 191 or 192, such as electrical fires, arson, etc., and
includes events where fire or explosion not originating from a gas distribution system failure or
release was the primary cause of the gas distribution system failure or release, such as a house fire
that subsequently resulted in – but was not caused by – a gas distribution system failure or release.
An event caused by secondary ignition is not to be reported unless a release of gas escaping
from facilities subject to regulation under Parts 191 or 192 results in one or more of the
consequences as described in §191.3 under "Incident" (1). The determination of consequences
from a gas distribution system Incident caused by secondary ignition, though, is an area of possible
confusion when reporting Incidents. PHMSA is providing the following guidance for operators to
use when secondary ignition is involved (sometimes referred to as “Fire First” incidents):
• A gas distribution system Incident attributed to secondary ignition is to be
reported to PHMSA if any fatalities or injuries are involved unless it can be
established with reasonable certainty that all of the casualties either preceded the
gas distribution system failure or release or would have occurred whether or not
the gas distribution system failure or release occurred.
• A gas distribution system Incident attributed to secondary ignition is NOT to be
reported to PHMSA if the only reportable criterion is unintentional loss of gas
of 3 million cubic feet or more as described in §191.3 under "Incident" (1)(iii).
• A gas distribution system Incident attributed to secondary ignition is NOT to be
reported to PHMSA unless the damage to facilities subject to Parts 191 or 192
equals or exceeds the property damage reporting threshold in effect on the date
of the incident.
These considerations apply to several gas distribution system Incident cause categories as
indicated in pertinent sections of these instructions.
Form PHMSA F 7100.1 and these instructions can be found on
http://phmsa.dot.gov/pipeline/library/forms. The applicable documents are listed in the section titled
Accident/Incident/Annual Reporting Forms.
ONLINE REPORTING REQUIREMENTS
Page 1 of 28
Instructions (rev 6-2023) for Form PHMSA F 7100.1 (rev 6-2023)
INCIDENT REPORT – GAS DISTRIBUTION SYSTEMS
Incident Reports must be submitted online through the PHMSA Portal at
https://portal.phmsa.dot.gov/portal, unless an alternate method is approved (see Alternate
Reporting Methods below). You will not be able to submit reports until you have met all of the
Portal registration requirements – see
https://portal.phmsa.dot.gov/PHMSAPortal2/staticContentRedesign/howto/PortalAccountCrea
tion.pdf
Completing these registration requirements could take several weeks. Plan ahead and
register well in advance of the report due date.
Use the following procedure for online reporting:
1. Go to the PHMSA Portal at https://portal.phmsa.dot.gov/portal
2. Enter PHMSA Portal Username and Password; press enter
3. Select OPID; press “continue” button.
4. On the left side menu under “Incident/Accident (2010 to present)” select “ODES 2.0”
5. Under “Create Reports” on the left side of the screen, select “Gas Distribution” and
proceed with entering your data.
6. Click “Submit” when finished with your data entry to have your report uploaded to
PHMSA’s database as an official submission of an Incident Report; or click “Save” which
doesn’t submit the report to PHMSA but stores it in a draft status to allow you to come back
to complete your data entry and report submission at a later time. Note: The “Save” feature
will allow you to start a report and save a draft of it which you can print out and/or save as a
PDF to email to colleagues in order to gather additional information and then come back to
accurately complete your data entry before submitting it to PHMSA.
7. Once you click “Submit”, the system will check if all applicable portions of the report
have been completed. If portions are incomplete, a listing of these portions will appear above
the row of Parts. If all applicable portions have been completed, the system will show your
Saved Incident/Accident Reports in the top portion of the screen and your Submitted
Incident/Accident Reports in the bottom portion of the screen. Note: To confirm that your
report was successfully submitted to PHMSA, look for it in the bottom portion of the screen
where you can also view a PDF of what you submitted.
Supplemental Report Filing – Follow Steps 1 through 4 above and double-click a submitted
report from the Submitted Incident/Accident Reports list. The report will default to a “Read Only”
mode that is pre-populated with the data you submitted previously. To create a supplemental
report, click on “Create Supplemental” found in the upper right corner of the screen. At this point,
you can amend your data and make an official submission of the report to PHMSA as either a
Supplemental Report or as a Supplemental Report plus Final Report (see “Specific Instructions, PART
Page 2 of 28
Instructions (rev 6-2023) for Form PHMSA F 7100.1 (rev 6-2023)
INCIDENT REPORT – GAS DISTRIBUTION SYSTEMS
A, Report Type”), or you can use the “Save” feature to create a draft of your Supplemental Report to
be submitted at some future date.
Alternate Reporting Methods
Operators for whom electronic reporting imposes an undue burden and hardship may submit a
written request for an alternate reporting method. Operators must follow the requirements in
§191.7(d) to request an alternate reporting method and must comply with any conditions imposed
as part of PHMSA’s approval of an alternate reporting method.
RETRACTING A 30-DAY WRITTEN REPORT
An operator who reports an incident in accordance with §191.9 (oftentimes referred to as a 30-day
written report) and upon subsequent investigation determines that the event did not meet the
criteria in §191.3 may request that their report be retracted. Requests to retract a 30-day written
report are to be emailed to InformationResourcesManager@dot.gov. Requests are to include the
following information:
a. The Report ID (the unique 8-digit identifier assigned by PHMSA)
b. Operator name
c. PHMSA-issued OPID number
d. The number assigned by the National Response Center (NRC) when an immediate
notice was made in accordance with §191.5. If Supplemental Reports were made to the
NRC for the event, list all NRC report numbers associated with the event.
e. Date of the event
f. Location of the event
g. A brief statement as to why the report should be retracted.
Note: PHMSA no longer requests that operators rescind erroneously reported “Immediate
Notices” filed with the NRC in accordance with §191.5 (oftentimes referred to as “Telephonic
Reports”).
SPECIAL INSTRUCTIONS
All applicable data fields must be completed before an Original Report will be accepted. Your
Original Report cannot be submitted online until the required information has been provided,
although your partially completed report can be saved online so that you can return at a later time
to provide the missing information.
1. An entry should be made in each applicable space or check box, unless otherwise directed by
the section instructions.
2. If the data is unavailable, enter “Unknown” for text fields and leave numeric fields and fields
using check boxes or “radio” buttons blank.
Page 3 of 28
Instructions (rev 6-2023) for Form PHMSA F 7100.1 (rev 6-2023)
INCIDENT REPORT – GAS DISTRIBUTION SYSTEMS
3. Estimate data only if necessary. Provide an estimate in lieu of answering a question with
“Unknown” or leaving the field blank.
Estimates should be based on best-available
information and reasonable effort.
4. For unknown or estimated data entries, the operator should file a Supplemental Report when
additional or more accurate information becomes available.
5. If the question is not applicable, enter “N/A” for text fields and leave numeric fields and fields
using check boxes or “radio” buttons blank. Do not enter zero unless this is the actual value
being submitted for the data in question.
6. If OTHER is checked for any answer to a question, include an explanation or description in
the text field provided, making it clear why “Other” was the necessary selection.
7. Pay close attention to each question for the phrase:
a. (select all that apply)
b. (select only one)
If the phrase is not provided for a given question, then “select only one” applies. “Select only
one” means that you should select the single, primary, or most applicable answer. DO NOT
SELECT MORE ANSWERS THAN REQUESTED. “Select all that apply” requires that all
applicable answers (one or more than one) be selected.
8. Date format = mm/dd/yyyy
9. Time format: All times are reported as a 24-hour clock:
Time format Examples:
a. (0000) = midnight =
b. (0800) = 8:00 a.m. =
c. (1200) = Noon
=
d. (1715) = 5:15 p.m. =
e. (2200) = 10:00 p.m. =
/0/0/0/0/
/0/8/0/0/
/1/2/0/0/
/1/7/1/5/
/2/2/0/0/
Local time always refers to time at the site of the incident. Note that time zones at the incident
site may be different than the time zone for the person discovering or reporting the event. For
example, if a release occurs at an gas distribution system facility in Denver, Colorado at 2:00 pm
MST, but a supervisor located in Houston is filing the report after having been notified at 3:00
pm CST, the time of the incident should be reported as 1400 hours based on the time in Denver,
which is the physical site of the incident.
Page 4 of 28
Instructions (rev 6-2023) for Form PHMSA F 7100.1 (rev 6-2023)
INCIDENT REPORT – GAS DISTRIBUTION SYSTEMS
SPECIFIC INSTRUCTIONS
PART A – KEY REPORT INFORMATION
Report Type: (select all that apply)
Check the appropriate report box or boxes to indicate the type of report being filed. Depending on
the descriptions below, the following combinations of boxes – and only one of these combinations
- may be selected:
•
•
•
•
Original Report only
Original Report plus Final Report
Supplemental Report only
Supplemental Report plus Final Report
Original Report
Select if this is the FIRST report filed for this Incident and you expect that additional or
updated information will be provided later.
Original Report
plus
Final Report
Select both Original Report and Final Report if ALL of the information requested is known and
can be provided at the time the initial report is filed, including final property damage costs and
apparent failure cause information. If new, updated, and/or corrected information becomes
available, you are still able to file a Supplemental Report.
Supplemental Report
Select only if you have already filed an Original Report AND you are now providing new, updated,
and/or corrected information. Multiple Supplemental Reports are to be submitted, as necessary,
in order to provide new, updated, and/or corrected information when it becomes available and, per
§191.9(b), each Supplemental Report containing new, updated, and/or corrected information is to
be filed as soon as practicable. Submission of new, updated, and/or corrected information is NOT
to be delayed in order to accumulate “enough” to “warrant” a Supplemental Report, or to complete
a Final Report. Supplemental Reports must be filed as soon as practicable following the
Operator’s awareness of new, updated, and/or corrected information. Failure to comply with
these requirements can result in enforcement actions, including the assessment of civil penalties
as provided in 49 USC 60122.
For Supplemental Reports filed online, all data previously submitted will automatically populate
in the form. Page through the form to make edits and additions where needed.
Page 5 of 28
Instructions (rev 6-2023) for Form PHMSA F 7100.1 (rev 6-2023)
INCIDENT REPORT – GAS DISTRIBUTION SYSTEMS
Supplemental Report
plus
Final Report
If an Original Report has already been filed AND new, updated, and/or corrected information is
now being submitted via a Supplemental Report, AND the operator is reasonably certain that no
further information will be forthcoming, then Final Report is to also be selected along with
Supplemental Report. (See also the requirements stated above under “Supplemental Report”.)
A1. Operator’s OPS -Issued Operator Identification Number (OPID)
For online entries, the OPID will automatically populate based on the selection you made when
entering the Portal. If you have log-in credentials for multiple OPID, be sure the report is being created
for the appropriate OPID. Contact PHMSA’s Information Resources Manager at 202-366-8075 if you
need assistance with an OPID. Business hours are 8:30 AM to 5:00 PM Eastern Time.
A2. Name of Operator
This is the company name associated with the OPID. For online entries, the name will automatically
populate based on the OPID entered in A1. If the name that appears is not correct, you need to submit
an Operator Name Change (Type A) Notification.
A3. Address of Operator
For online entries, the headquarters address will automatically populate based on the OPID entered in
A1. If the address that appears is not correct, you need to change it in the online Contacts module.
A4. Local time (24-hour clock) and date of incident
Enter the earliest of the following:
estimate of the time/date when the release of commodity began; or
time/date that personal injury or damage to property first occurred rather than the
time/date the consequences are quantified.
In most cases, this time/date will be nearly the same as when the operator identified the failure,
which is reported in A13. In some cases, this date/time will be prior to the operator’s identification
of the failure and must be estimated based on information gathered during the investigation. For
example, the operator will need to estimate the time/date that the release began for large leaks that
are not detected remotely and do not impact people or property.
See “Special Instructions”, numbers 8 and 9 for examples of Date format and Time format
expressed as a 24-hour clock.
A4a. Select the local time zone where the Incident occurred (select only one).
A4b. Select “Yes” if Daylight Saving was in effect at the time of the Incident, or “No” if
it was not.
Page 6 of 28
Instructions (rev 6-2023) for Form PHMSA F 7100.1 (rev 6-2023)
INCIDENT REPORT – GAS DISTRIBUTION SYSTEMS
A5. Location of Incident
a. Provide the street address of the incident (enter “unknown” if no street address)
b. Provide the name of the city where the incident occurred. If the incident did not occur within
a municipality, select Not Within Municipality in the City field.
c. Provide the name of the county or parish where the incident occurred.
d. Enter the 2-digit state abbreviation where the incident occurred.
e. Enter the zip code where the incident occurred.
f. The latitude and longitude of the incident are to be reported as Decimal Degrees with a
minimum of 5 decimal places (e.g. Lat: 38.89664; Long: -77.04327), using the NAD83 or
WGS84 datums.
If you have coordinates in degrees/minutes or degrees/minutes/seconds use the formula
below to convert to decimal degrees:
degrees + (minutes/60) + (seconds/3600) = decimal degrees
e.g. 38° 53' 47.904" = 38 + (53/60) + (47.904/3600) = 38.89664°
All locations in the United States will have a negative longitude coordinate, which has
already been included on the data entry form so that operators do not have to enter
the negative sign.
If you cannot locate the incident with a GPS or some other means, there are online tools that
may assist you at http://viewer.nationalmap.gov/viewer/. Any questions regarding the
required format, conversion, or how to use the tools noted above can be directed to Amy
Nelson (202-493-0591 or amy.nelson@dot.gov).
A6. Gas released:
Select the type of gas released. An example of Synthetic Gas is manufactured gas based on naphtha.
Landfill Gas includes biogas.
A7. Estimated volume of gas released unintentionally
Estimate the amount of gas that was released (in thousands of standard cubic feet, mcf) from the
beginning of the incident until such time as gas is no longer being released from the gas distribution
system or until intentional and controlled blowdown has commenced. Estimates are to be based
on best-available information. Important Note: Volumes consumed by fire and/or explosion are
to be included in the estimated volume reported.
A8. Estimated volume of intentional and controlled release/blowdown
Estimate the amount of gas that was released (in thousands of standard cubic feet, mcf) during any
intentional release or controlled blowdown conducted as part of responding to or recovering from
the Incident. Intentional and controlled blowdown implies a level of control of the site and
situation by the operator such that the area and the public are protected during the controlled
release. Important Note: Volumes consumed by fire and/or explosion are to be included in the
estimated volume reported.
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A9. Were there fatalities?
Select “Yes” or “No” and if “Yes” is selected, enter the number of fatalities resulting from the
Incident for A9a through e as applicable.
If a person dies at the time of the incident or within 30 days of the initial incident date due to
injuries sustained as a result of the incident, report as a fatality. If a person dies subsequent to an
injury more than 30 days past the incident date, report as an injury. (Note: This aligns with the
Department of Transportation's general guidelines for all jurisdictional modes for reporting deaths
and injuries.)
Contractor employees working for the operator are individuals hired to work for or on behalf
of the operator of the gas distribution system. These individuals are not to be reported as “Operator
employees”.
Non-Operator emergency responders are individuals responding to render professional aid at
the incident scene including on-duty and volunteer fire fighters, rescue workers, EMTs, police
officers, etc. “Good Samaritans” that stop to assist are to be reported as “General public.”
Workers Working on the Right of Way, but NOT Associated with this Operator means people
authorized to work in or near the right-of-way, but not hired by or working on behalf of the
operator of the gas distribution system. This includes all work conducted within the rightof-way including work associated with other underground facilities sharing the right-of-way,
building/road construction in or across the right-of-way, or farming. This category most
often includes employees of other underground facilities operators, or their contractors,
working in or near a shared right-of-way. For distribution pipelines not located in a defined
right-of-way, this category should be left blank. Workers performing work near, but not on,
the right-of-way and who are affected are to be reported as “General public”.
A10. Were there injuries requiring inpatient hospitalization?
Select “Yes” or “No” and if “Yes” is selected, enter the number of injured persons resulting from
the Incident for A10a through e as applicable.
Injuries requiring inpatient hospitalization are injuries sustained as a result of the incident and
requiring hospital admission and at least one overnight stay.
See Question A9 for additional definitions that apply.
A11. What was the Operator’s initial indication of the Failure? (select only one)
Select the best option to describe the manner in which the operator first became aware of a failure
resulting in this reported Incident.
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Controller means a qualified individual whose function within a shift is to remotely monitor
and/or control the operations of entire or multiple sections of distribution pipelines or systems via
a SCADA system from a control room, and who has operational authority and accountability for
the daily remote operational functions of gas distribution systems.
Local Operating Personnel including contractors means employees or contractors working on
behalf of the operator outside the control room.
A11a. If the Incident was identified by Operator’s personnel or a contractor working for the
Operator (including controller, air and ground patrols) in A11, identify if it was by an Operator
employee, or a contractor working for the Operator.
A12. When did the operator identify the failure?
Enter the date/time the operator’s initial indication of the failure reported in A11.
A13 -15 Operator Communication with Local, State, or Federal Emergency Responders
In an Advisory Bulletin dated October 11, 2012, PHMSA reminded Operators of the need to
communicate with Emergency Responders in the early stages of a potential Incident. This is
typically accomplished by contacting Public Safety Access Points (PSAPs) along the pipeline
route. The purpose of the communication is to assist in the identification, location, and planning
for response to pipeline Incidents through coordination and information sharing.
Indicate in 13 if the Operator communicated with Local, State, or Federal Emergency Responders
about the Incident, identify who initiated the communication about the Incident in 14, and enter
the Local date and time of the initial communication in 15.
A16. What time did Operator resources arrive on site?
Enter the date/time operator responders, company or contract, arrived on site. This time is to be
shown by 24-hour clock notation and reported in the time in the time zone where the incident
occurred. (See “Special Instructions”, numbers 8 and 9 and 10.) PHMSA will use this data to
calculate incident response times.
A17. Enter local time and date of Confirmed Discovery as defined in 49 CFR §191.3.
A18. Local time (24-hr clock) and date of initial operator report to the National Response
Center
Enter the time and date of the initial Immediate Notice of incident to the NRC submitted by the
operator. The time is to be shown by 24-hour clock notation and is to reflect the time in the time
zone where the incident was physically located. (See “Special Instructions”, numbers 8 and 9.)
A19. National Response Center (NRC) Report Number
§191.5 requires that incidents meeting the criteria outlined in §191.3 be reported directly to the
24-hour National Response Center (NRC) at 1-800-424-8802 at the earliest practicable moment.
The NRC assigns numbers to each call. The number assigned to Initial Immediate Notice
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(sometimes referred to as the “Telephonic Report”) is to be entered in Question 19. When there
is more than one NRC report for the incident, enter the Initial report in this field and remaining
NRC report numbers in A19a. If a NRC report was not made, select NRC Notification Required
But Not Made.
A19a. Additional NRC Report Numbers
If the operator made more than one call to the NRC, enter each additional NRC report number.
A20. Method of Flow Control (select all that apply)
The response to gas distribution pipeline emergencies may involve several methods of controlling
flow to the failure location. Select all methods of flow control used during response to the incident.
A21. Did the Gas Ignite?
Ignite means the released gas caught fire or a conflagration, detonation or explosion occurred,
even if there was no residual fire after the initial ignition event.
If the answer is “Yes,” complete questions A21a through d.
A21a. Enter the time and date of the ignition. The time is to be shown by 24-hour clock notation
in the time zone where the Incident occurred.
A21b. Indicate how the fire was extinguished.
A21c. Estimate volume of gas consumed by fire in thousands of standard cubic feet, MCF
A21d. Did the Gas Explode?
Explode means the ignition of the released gas occurred with a sudden and violent release of
energy.
A22. Number of general public evacuated
The number of people evacuated is to be estimated based on operator knowledge, or police, fire
department, or other emergency responder reports. If there was no evacuation involving the
general public, report zero (0). If an estimate is not possible for some reason, leave the field blank
but include an explanation of why it was not possible to provide a number in PART H – Narrative
Description of the Incident.
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PART B – ADDITIONAL LOCATION INFORMATION
1. Was the incident on Federal Land?
Federal Lands means all lands the United States owns, including military reservations, except lands
in National Parks and lands held in trust for Native Americans. Incidents at Federal buildings, such
as Federal Court Houses, Custom Houses, and other Federal office buildings and warehouses, are
NOT to be reported as being on Federal Lands.
2. Location of incident
Operator-controlled property would normally apply to an operator’s facility, which may or may
not have controlled access, but which is oftentimes fenced or otherwise marked with discernible
boundaries. This “operator-controlled property” does not refer to the pipeline right-ofway/easement, which is a separate choice for this question.
3. Area of incident
This refers to the location on the gas distribution system at which gas was released, resulting in
the incident. It does not refer to adjacent locations in which released gas may have accumulated
or ignited.
Underground means pipe, components, or other facilities installed below the natural ground level,
road bed, or below the underwater natural bottom.
Under pavement includes under streets, sidewalks, paved roads, driveways, and parking lots.
Exposed due to Excavation means that a normally buried facility had been exposed by any party
(operator, operator’s contractor, or third party) preparatory to or as a result of excavation. The
cause of the release, however, may or may not necessarily be related to excavation damage. This
category could include a corrosion leak not previously evidenced by stained vegetation, but found
during excavation, or a release caused by a non-excavation vehicle where contact happened to
occur while the facility was exposed for excavation repair or examination. Natural forces might
also damage a facility that happened to be temporarily exposed. In each case, the cause is to be
appropriately reported in PART G of this form.
Exposed due to Loss of Cover means that a normally buried facility had been exposed due to a
cause other excavation activities. For example, natural forces might cause a facility that had been
installed underground to become exposed.
Aboveground means pipe, components, or other facilities that are above the natural grade.
Typical aboveground facility piping includes any pipe or components installed aboveground
such as those at regulating stations or valve sites.
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Transition area means the junction of differing material or media between pipes, components, or
facilities such as those installed at a belowground-aboveground junction (soil/air interface),
another environmental interface, or in close contact to supporting elements such as those at water
crossings and meter stations.
If B3. is Underground, enter the depth of cover as found in B3a. and indicate whether other
underground facilities were found within 12 inches of the failure location in B3b.
4. Did Incident occur in a crossing?
Use Bridge Crossing if the pipeline is suspended above a body of water or roadways, railroad
right-of-way, etc. either on a separately designed pipeline bridge or as a part of or connected to a
road, railroad, or passenger bridge.
Use Railroad Crossing or Road Crossing, as appropriate, if the pipeline is buried beneath rail
bed or roadbed.
Use Water Crossing if the pipeline is in the water, beneath the water, in contact with the natural
ground of the lake bed, etc., or buried beneath the bed of a lake, reservoir, stream, or creek, whether
the crossing happens to be flowing water at the time of the incident or not. The name of the body
of water is to be provided if it is commonly known and understood among the local population.
(The purpose of this information is to allow persons familiar with the area in which the incident
occurred to identify the location and understand it in its local context. Research to identify names
that are not commonly used is not necessary since such names would not fulfill the intended
purpose. If a body of water does not have a name that is commonly used and understood in the
local area, this field may be left blank). For Approximate Water Depth (ft) of the lake, reservoir,
etc., estimate the typical water depth at the location and time of the incident, ignoring seasonal,
weather-related, and other factors which may affect the water depth from time to time. Finally,
specify the part of the water crossing where the failure occurred.
PART C – ADDITIONAL FACILITY INFORMATION
C1. Indicate the type of pipeline system:
Designate the type of gas distribution system on which the incident occurred.
C2. Part of system involved in Incident
This should be the part of the system principally involved in the incident, from which gas was
released resulting in reportable consequences. If the failure occurred on an item not provided in
this section, select “Other” and specify in the space provided the item involved in the incident.
C2a. Year Installed Enter the year the item involved in the incident was installed.
C2b. Year Manufactured Enter the year the item involved in the incident was manufactured.
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When C2. is any value other than “Main”, “Main Valve”, “District Regulator/Metering
Station”, or “Other”, answer 2c through 2f.
C2c. Customer Type Select only one. Customer Types are:
Single Family - residential building designed for a single family
Multi-Family - residential dwellings such as apartments, town homes, and duplexes
Industrial – customers manufacturing products
Commercial – retail and wholesale sales customers, including hospitals, schools, and other
government affiliated customers
C2d. EFV Installed Had an Excess Flow Valve (EFV) been installed on the service line before
the time of the failure? If Yes:
C2e. EFV Activation Did the EFV activate in response to the failure? If you are unable
to determine if the EFV activated, select “unable to determine.”
C2f. Curb Valve Installed Had a curb valve been installed on the service line before the time
of the failure? Curb valves are manually operated valves located near the main.
C3. When “Main” or “Service” is selected in C2., answer C3a. through c:
C3a. Nominal Pipe Size (NPS) For pipe greater than 5 inches in diameter, enter only the
integer portion of the diameter value; for example, 8-5/8 pipe has a nominal pipe size of 8. For
pipe less than 5 inches in diameter, the NPS may include decimals to three places. For more
details, see http://en.wikipedia.org/wiki/Nominal_Pipe_Size
C3b. Pipe Specification is the specification to which the pipe or component was manufactured,
such as API 5L or ASTM A106.
C3c. Pipe Manufacturer
Enter the name of the company that manufactured the pipe.
C4. Material involved in incident:
Identify the type of material involved and provide additional information as indicated.
C5. Type of release involved:
Mechanical puncture means a puncture of the facility, typically by a piece of equipment such as
would occur if the facility were pierced by directional drilling or a backhoe bucket tooth. Not all
excavation-related damage will be a “mechanical puncture.” (Precise measurement of size – e.g.,
micrometer – is not needed. Approximate measurements can be provided in inches and one
decimal.)
Leak means a failure resulting in an unintentional release of gas that is often small in size, usually
resulting a low flow release of low volume, although large volume leaks can and do occur on
occasion.
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Rupture means a loss of containment that immediately impairs the operation of the gas
distribution system or facility. Facility ruptures often result in a higher flow release of larger
volume. The terms “circumferential” and “longitudinal” refer to the general direction or
orientation of the rupture relative the pipe’s axis. They do not exclusively refer to a failure
involving a circumferential weld such as a girth weld, or to a failure involving a longitudinal weld
such as a pipe seam. (Precise measurement of size – e.g., micrometer – is not needed.
Approximate measurements can be provided in inches and one decimal.)
PART D – ADDITIONAL CONSEQUENCE INFORMATION
D2. Estimated Property Damage
All relevant costs available at the time of submission must be included in the initial written Incident
Report as well as being updated as needed on Supplemental Reports. This includes (but is not
limited to) costs due to property damage to the operator’s facilities and to the property of others,
facility repair and replacement, gas distribution service restoration and relighting, leak locating,
and environmental cleanup and damage. Do NOT include cost of gas lost. Additionally, do NOT
include costs incurred for facility repair, replacement, or changes that are NOT related to the
incident and which are typically done solely for convenience. An example of doing work solely
for convenience is working on non-leaking facilities unearthed because of the incident. Litigation
and other legal expenses related to the incident are not reportable.
Operators are to report costs based on the best estimate available at the time a report is submitted.
It is likely that an estimate of final repair costs may not be available when the initial report must
be submitted (30 days, per §191.9). The best available estimate of these costs is to be included in
the initial report. For convenience, this estimate can be revised, if needed, when Supplemental
Reports are filed for other reasons, however, when no other changes are forthcoming,
Supplemental Reports are to be filed as new cost information becomes available. If Supplemental
Reports are not submitted for other reasons, a Supplemental Report is to be filed for the purpose
of updating or correcting the estimated cost if these costs differ from those already reported by 20
percent or $20,000, whichever is greater.
D2a. Public and non-operator private property damage estimates generally include physical
damage to the property of others, the cost of investigation and remediation of a site not owned or
operated by the Company, laboratory costs, third party expenses such as engineers or scientists,
and other reasonable costs, excluding litigation and other legal expenses related to the incident.
D2b. Operator’s property damage & repairs estimates generally include physical damage to
the property of Operator or Owner Company such as the estimated installed value of the damaged
pipe, coating, component, materials, or equipment due to the incident, excluding the cost of any
gas lost. Also to be excluded are litigation and other legal expenses related to the incident.
When estimating the Cost of repairs to company facilities, the standard shall be the cost necessary
to safely restore property to its predefined level of service. Property damage estimates include the
cost to access, secure, excavate, and repair the facility using methods, materials, and labor
necessary to re-establish operations at a predetermined level. These costs may include the cost of
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repair sleeves or clamps, re-routing of piping, or the removal from service of an appurtenance or
facility component. When more comprehensive repairs or improvements are justified but not
required for continued operation, the cost of such repairs or replacement is not attributable to the
incident. Costs associated with improvements to the gas distribution system to mitigate the risk
of future failures are not included.
D2c. Emergency response includes emergency response operations necessary to return the
incident site to a safe state, actions to minimize the volume of gas released, conduct
reconnaissance, and to identify the extent of incident impacts. They include materials, supplies,
labor, and benefits. If you reimbursed local, state, or federal emergency responders, include these
amounts. Costs related to stakeholder outreach, media response, etc. are not to be included.
D2d. Other costs are to include any and all costs which are not included above. Cost of any gas
lost is NOT to be reported here, but is to be reported under Cost of Gas Released. Operators are
to NOT use this category to report any costs which belong in cost categories separately listed
above.
Costs are to be reported in only one category and are not to be double counted. Costs can be split
between two or more categories when they overlap more than one reporting category.
Cost of Gas Released – enter your gas cost, excluding taxes, in dollars per thousand standard
cubic feet (mcf). The cost of gas released will be calculated based on the volumes reported in A7
and A8.
D3. Estimated number of customers out of service:
Count number of individual services in each category that were affected, not number of persons
served.
Injured persons not included in A10. The number of persons injured, admitted to a hospital,
and remaining in the hospital for at least one overnight are reported in A10. If a person is
included in A10, do not include them in D4.
D4. Estimated number of persons with injuries requiring treatment in a medical facility but not
requiring overnight in-patient hospitalization.
If a person is included in D4, do not include them in D5.
D5. Estimated number of persons with injuries requiring treatment by EMTs at the site of
incident.
Buildings Affected The term ‘affected’ means the building was either damaged and required
repair, or evacuated, or had gas service interrupted.
D6. Enter the number of residential buildings affected.
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D7. Enter the number of commercial and industrial buildings affected.
PART E – ADDITIONAL OPERATING INFORMATION
E2. Normal operating pressure at point and time of the incident (psig)
If the normal operating pressure of a distribution system varies throughout the year (e.g.,
seasonally), report the normal operating pressure at the time the incident occurred.
E3a. MAOP Established By Select the response serving as the limiting factor for establishing
MAOP at the incident site. A short explanation of each option is:
§ 192.619
(paragraph)
(a)
(a)(1)
(a)(2)
(a)(3)
(a)(4)
(c)
§192.621
§192.623
Methodology Description
Introduction: Except as specified in (c), use the lowest MAOP determined by
(a)(1), (a)(2), (a)(3), (a)(4).
Design Pressure
Post-Construction Pressure Test
High Actual Operation Pressure during 5 years preceding July 1, 1970 – this
is NOT the Grandfather Clause
History of Pipe (primarily corrosion and actual operating pressure)
Grandfather Clause – Highest Actual Operating Pressure during five years
preceding 1970, even if this MAOP is higher than MAOPs determined by
other (a) methods
Maximum allowable operating pressure: High-pressure distribution systems
Maximum and minimum allowable operating pressure; Low-pressure
distribution systems
E3b. MAOP Date
Enter the date the MAOP in E3a. was established.
E4. Operating Pressure and MAOP Select the option that describes the relationship among
the operating pressure at the point and time of the incident, the MAOP, and the allowances in
§192.201.
E5. Odorization Type
Select the one option that best describes the odorization system(s)
affecting gas at the point of failure.
E6. Odorant Level Enter the odorant level in, % LEL, as measured near the failure site or
indicate that no measurement was done.
E7. Was a Supervisory Control and Data Acquisition (SCADA)-based system in place on
the pipeline or facility involved in the incident?
This does not mean a system designed or used exclusively for leak detection.
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E7a. Was it operating at the time of the Incident?
Was the SCADA system in operation at the time of the incident?
E7b. Was it fully functional at the time of the Incident?
Was the SCADA system capable of performing all of its functions, whether or not it
was actually in operation at the time of the incident? If no, describe functions that
were not operational in PART H – Narrative Description of the Incident.
E7c and d. Did SCADA-based information (such as alarm(s), alert(s), event(s),
and/or volume or pack calculations) assist with the detection or confirmation of
the Incident?
Select Yes if SCADA-based information was used to confirm the incident even if the
initial report or identification may have come from other sources. Use of SCADA data
for subsequent estimation of amount of gas lost, etc. is not considered use to confirm
the incident.
Select No if SCADA-based information was not used to assist with identification of
the incident.
E8. Was an investigation initiated into whether or not the controller(s) or control room
issues were the cause of or a contributing factor to the Incident?
Select only one of the choices to indicate whether an investigation was/is being conducted (Yes)
or was not conducted (No). If an investigation has been completed, select all the factors that apply
in describing the results of the investigation.
Cause means an action or lack of action that directly resulted in the gas distribution system
incident.
Contributing factor means an action or lack of action that when added to the existing
circumstances heightened the likelihood of the release or added to the impact of the release.
Controller Error means that the controller failed to identify a circumstance indicative of a release
event, such as an abnormal operating condition, alarm, pressure drop, change in flow rate, or other
similar event.
Incorrect Controller action means that the controller errantly operated the means for controlling
an event. Examples include opening or closing the wrong valve or hitting the wrong switch or
button.
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PART F – DRUG & ALCOHOL TESTING INFORMATION
Requirements for post-accident drug and alcohol tests are in 49 CFR §199.105 and §199.225
respectively. If the incident circumstances were such that tests were not required by these sections,
and if no tests were conducted, select No. If tests were administered, select Yes and report
separately the number of operator employees and contractors working for the operator who were
tested and the number of each that failed such tests.
PART G – APPARENT CAUSE
PART G – Apparent Cause
Select the one, single sub-cause listed under sections G1 thru G8 that best describes the
apparent cause of the Incident. These sub-causes are contained in the shaded column on the
left under each main cause category. Answer the corresponding questions that accompany
your selected sub-cause, and enter secondary, contributing, or root causes of the Incident in
PART J – Contributing Factors.
G1 – Corrosion Failure
Corrosion includes a release or failure caused by galvanic, atmospheric, stray current,
microbiological, or other corrosive action. A corrosion release or failure is not limited to a hole in
the pipe or other piece of equipment. If the bonnet or packing gland on a valve or flange on piping
deteriorates or becomes loose and leaks due to corrosion and failure of bolts, it is classified as
Corrosion. (Note: If the bonnet, packing, or other gasket has deteriorated to failure, whether
before or after the end of its expected life, but not due to corrosive action, report it under a different
cause category, such as G7 Incorrect Operation for improper installation or G6 - Equipment Failure
if the gasket failed.)
External Corrosion
4a. Under cathodic protection means cathodic protection in accordance with §192.455,
§192.457, and §192.463. Recognizing that older facilities may have had cathodic protection added
over a number of years, provide an estimate if exact year cathodic protection started is unknown.
Internal Corrosion
10. Location of corrosion
A low point in pipe includes portions of the pipe contour in which water might settle out. This
includes, but is not limited to, the low point of vertical bends at a crossing of a foreign line or
road/railroad, etc., an elbow, a drop out or low point drain.
11. Was the gas/fluid treated with corrosion inhibitors or biocides?
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Select Yes if corrosion inhibitors or biocides were included in the gas/fluid transported.
Either External or Internal Corrosion
14. Has one or more hydrotest or other pressure test been conducted since original
construction at the point of the Incident?
Information from the initial post-construction hydrostatic test is not to be reported.
G2 – Natural Force Damage
Natural Force Damage includes a release or failure resulting from earth movement, earthquakes,
landslides, subsidence, lightning, heavy rains/floods, washouts, flotation, mudslide, scouring,
temperature, frost heave, frozen components, high winds, or similar natural causes.
Earth Movement NOT due to Heavy Rains/Floods refers to incidents caused by land shifts such
as earthquakes, landslides, or subsidence, but not mudslides which are presumed to be initiated by
heavy rains or floods.
Heavy Rains/Floods refer to all water-related natural force causes. While mudslides involve earth
movement, report them here since typically they are an effect of heavy rains or floods.
Lightning includes both damage and/or fire caused by a direct lighting strike and damage and/or
fire as a secondary effect from a lightning strike in the area. An example of such a secondary
effect would be a forest fire started by lightning that results in damage to a gas distribution system
asset which results in an incident. (See also the discussion of “secondary ignition” under the
General Instructions.)
Temperature includes weather-related temperature and thermal stress effects, either heat or cold,
where temperature was the initiating cause.
Thermal stress refers to mechanical stress induced in a pipe or component when
some or all of its parts are not free to expand or contract in response to changes
in temperature.
Frozen components would include incidents where components are inoperable
because of freezing and those due to cracking of a piece of equipment due to
expansion of water during a freeze cycle.
High Winds includes damage caused by wind induced forces. Select this category if the damage
is due to the force of the wind itself. Damage caused by impact from objects blown by wind are
to be reported under section G4 - Other Outside Force Damage.
Tree/Vegetation Root includes damages when tree and vegetation roots caused damage to the gas
distribution system asset which results in an incident.
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Snow/Ice Impact or Accumulation includes damages when snow or ice accumulation or impact
caused damage to the gas distribution system asset which results in an incident.
Other Natural Force Damage. Select this sub-cause for types of Natural Force Damage not
included otherwise and describe in the space provided. If necessary, provide additional
explanation in PART H – Narrative Description of the Incident.
Answer 6a if the incident occurred in conjunction with an extreme weather event. If the extreme
weather was something other than those listed, indicate Other and describe the event in the space
provided.
G3 – Excavation Damage
Excavation Damage includes a release or failure resulting directly from excavation damage by
operator's personnel (oftentimes referred to as “first party” excavation damage) or by the operator’s
contractor (oftentimes referred to as “second party” excavation damage) or by people or
contractors not associated with the operator (oftentimes referred to as “third party” excavation
damage). Also, this section includes a release or failure determined to have resulted from previous
damage due to excavation activity. For damage from outside forces OTHER than excavation
which results in a release, use G2 - Natural Force Damage or G4 - Other Outside Force, as
appropriate. Also, for a strike, physical contact, or other damage to a gas distribution system or
facility that apparently was NOT related to excavation and that results in a delayed or eventual
release, report the incident under G4 as “Previous Mechanical Damage NOT related to
Excavation.”
Excavation Damage by Operator (First Party) refers to incidents caused as a result of
excavation by a direct employee of the operator.
Excavation Damage by Operator’s Contractor (Second Party) refers to incidents caused as a
result of excavation by the operator’s contractor or agent or other party working for the operator.
Excavation Damage by Third Party refers to incidents caused by excavation damage resulting
from actions by personnel or other third parties not working for or acting on behalf of the operator
or its agent.
Previous Damage due to Excavation Activity refers to incidents that were apparently caused by
prior excavation activity and that then resulted in a delayed or eventual release. Indications of
prior excavation activity might come from the condition of the pipe when it is examined, or from
records of excavation at the site, or through metallurgical analysis or other inspection and/or testing
methods. Dents and gouges in the 10:00-to-2:00 o’clock positions on the pipe, for instance, may
indicate an earlier strike, as might marks from the bucket or tracks of an earth moving machine or
similar pieces of equipment.
2. Has one or more pressure test been conducted since original construction at the point of
the incident?
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Instructions (rev 6-2023) for Form PHMSA F 7100.1 (rev 6-2023)
INCIDENT REPORT – GAS DISTRIBUTION SYSTEMS
Information from the initial post-construction hydrostatic test is not to be reported.
If any Excavation Damage sub-cause is selected, answer questions 3 through 16.
3. and 3a. Prior Notification Indicate whether you received prior notification of the excavation
activity. If yes, indicate all of the notification sources.
3b. through 3e. One-Call State Law Exemptions Per the primary Incident Investigator results,
indicate whether State law exempted the excavator from notifying a one-call center. If yes, select
the type of exemption from the list. If “Other” is selected, enter text describing the exemption.
Describe the exempting authority and exempting criteria.
5. – 16. Instructions for answering these questions can be found at
https://www.phmsa.dot.gov/operator-resources/damage-information-reporting-tool-dirt-usersguide
NOTE: If you have or will be reporting the information in questions 5 thru 16 to CGADIRT, select “No” in question 4 to avoid duplication of data submitted to CGA.
G4 – Other Outside Force Damage
Other Outside Force Damage includes, but are not limited to, a release or failure resulting from
non-excavation-related outside forces, such as nearby industrial, man-made, or other fire or
explosion; damage by vehicles or other equipment; failures due to mechanical damage; and
intentional damage including vandalism and terrorism.
Nearby Industrial, Man-made or Other Fire/Explosion as Primary Cause of Incident applies
to situations where the fire occurred before - and caused - the release. (See also the discussion of
“secondary ignition” under the General Instructions.) Examples of such an incident would be an
explosion or fire that originated at a house or neighboring installation (chemical plant, tank farm,
or other industrial facility) or structure, debris, or brush/trees that results in a release at the
operator’s gas distribution system or facility. This includes forest, brush, or ground fires that are
caused by human activity. If the fire, however, is known to have been started as a result of a
lightning strike, the incident’s cause is to be classified under G2 - Natural Force Damage. Arson
events directed at harming the gas distribution system or the operator are to be reported as G4 Intentional Damage (see below).
Damage by Car, Truck, or Other Motorized Vehicle/Equipment NOT Engaged in
Excavation. An example of this sub-cause would be damage to a meter set caused by vehicle
impact. Other motorized vehicles or equipment include tractors, backhoes, bulldozers and other
tracked vehicles, and heavy equipment that can move. Include under this sub-cause incidents
caused by vehicles operated by the gas distribution system operator, the gas distribution system’s
contractor, or a third party and specify the vehicle/equipment operator’s affiliation from one of
these three groups. Gas distribution system incidents resulting from vehicular traffic loading or
other contact are to also be reported in this category. If the activity that caused the incident
involved digging, drilling, boring, grading, cultivation, or similar excavation activities, report
under G3 - Excavation Damage.
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Instructions (rev 6-2023) for Form PHMSA F 7100.1 (rev 6-2023)
INCIDENT REPORT – GAS DISTRIBUTION SYSTEMS
Damage by Boats, Barges, Drilling Rigs, or Other Maritime Equipment or Vessels Set Adrift
or Which Have Otherwise Lost Their Mooring. This sub-cause includes impacts by maritime
equipment or vessels (including their anchors or anchor chains or other attached equipment) that
have lost their moorings and are carried into the gas distribution system or facility by the current.
This sub-cause also includes maritime equipment or vessels set adrift as a result of severe weather
events and carried into the gas distribution system or facility by waves, currents, or high winds.
In such cases, also indicate the type of severe weather event. Do NOT report in this sub-cause
incidents which are caused by impact of maritime equipment or vessels while they are engaged in
their normal or routine activities; such incidents are to be reported as “Routine or Normal Fishing
or Other Maritime Activity NOT Engaged in Excavation” under this section G4 (see below) so
long as those activities are not excavation activities. If those activities are excavation activities
such as dredging or bank stabilization or renewal, the incident is to be reported under G3 Excavation Damage.
Routine or Normal Fishing or Other Maritime Activity NOT Engaged in Excavation. This
sub-cause includes incidents due to shrimping, purseining, oil drilling, or oilfield workover rigs,
including anchor strikes, and other routine or normal maritime-related activities UNLESS the
movement of the maritime asset was inadvertent and due to a severe weather event (this type of
incident is to be reported under “Damage by Boats, Barges, Drilling Rigs, or Other Maritime
Equipment or Vessels Set Adrift or Which Have Otherwise Lost Their Mooring” in this section
G4); or, the incident was caused by excavation activity such as dredging of waterways or bodies
of water (this type of incident is to be reported under G3 - Excavation Damage”).
Electrical Arcing from Other Equipment or Facility such as a pole transformer or adjacent
facility’s electrical equipment.
Previous Mechanical Damage NOT Related to Excavation. This sub-cause covers incidents
where damage occurred at some time prior to the release that was apparently NOT related to
excavation activities and would include prior outside force damage of an unknown nature, prior
natural force damage, prior damage from other outside forces, and any other previous mechanical
damage other than that which was apparently related to prior excavation. Incidents resulting from
previous damage sustained during construction, installation, or fabrication of the pipe, weld, or
joint from which the release eventually occurred are to be reported under G5 – Pipe, Weld, or Joint
Failure. (See this sub-cause for typical indications of previous construction, installation, or
fabrication damage.) Incidents resulting from previous damage sustained as a result of excavation
activities should be reported under G3 – Previous Damage due to Excavation Activity. (See this
sub-cause for typical indications of prior excavation activity.)
Intentional Damage
Vandalism means willful or malicious destruction of the operator’s gas distribution
system or facility or equipment. This category would include arson, pranks,
systematic damage inflicted to harass the operator, motor vehicle damage that was
inflicted intentionally, and a variety of other intentional acts. (See also the discussion
of “secondary ignition” under the General Instructions.)
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INCIDENT REPORT – GAS DISTRIBUTION SYSTEMS
Terrorism, per 28 CFR §0.85 General Functions, includes the unlawful use of force
and violence against persons or property to intimidate or coerce a government, the
civilian population, or any segment thereof, in furtherance of political or social
objectives. Operators selecting this item are encouraged to also notify the FBI.
Theft of commodity or Theft of equipment means damage by any individual or
entity, by any mechanism, specifically to steal, or attempt to steal, the transported gas
or gas distribution system equipment.
Other Describe in the space provided and, if necessary, provide additional explanation
in PART H – Narrative Description of the Incident.
Damage from Snow/Ice Impact or Accumulation includes damage caused by snow and/or ice.
Select this category if the damage is due to Snow/Ice, including encased regulator sets.
Erosion of Support Due to the Other Utilities Select this sub-cause when utilities near the gas
distribution system caused the removal of support from under the gas system. Do NOT report this
type of event as G5 – Pipe, Weld, or Joint Failure.
Other Outside Force Damage. Select this sub-cause for types of Other Outside Force Damage
not included otherwise, and describe in the space provided. If necessary, provide additional
explanation in PART H – Narrative Description of the Incident.
7 - 13 Additional Data for Damage by Car, Truck, or Other Motorized Vehicle/Equipment
NOT Engaged in Excavation
When answering the questions, include information that can be substantiated from police reports
or other investigative reports.
The following definitions apply for reporting the type of motorized vehicle in Question 10:
Motorcycle/All-Terrain Vehicle (ATV) - All two or three-wheeled motorized vehicles, and some
four-wheeled vehicles are to be reported in this category. Typical vehicles in this category have
saddle type seats and are steered by handlebars rather than steering wheels. This category
includes motorcycles, motor scooters, mopeds, motor-powered bicycles, and three-wheel
motorcycles. Additionally, four-wheeled off-road and all-terrain vehicles (sometimes referred to
as “four-wheelers”) are to be reported under this category.
Passenger Car -- All sedans, coupes, and station wagons manufactured primarily for the purpose
of carrying passengers and including those passenger cars pulling recreational or other light
trailers.
Small Truck - All two-axle, four-tire, vehicles, other than passenger cars. Included in this
classification are pickups, panels, vans, and other vehicles such as campers, motor homes,
ambulances, hearses, carryalls, and minibuses.
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Instructions (rev 6-2023) for Form PHMSA F 7100.1 (rev 6-2023)
INCIDENT REPORT – GAS DISTRIBUTION SYSTEMS
Bus - All vehicles manufactured as traditional passenger-carrying buses with two axles and six
tires or three or more axles. This category includes only traditional buses (including school
buses) functioning as passenger-carrying vehicles. Modified buses should be considered to be a
truck and should be appropriately classified.
Large Truck - All vehicles on a single frame including trucks, camping and recreational
vehicles, motor homes, etc., with two or more axles and at least two rear wheels on each side
When specifying the type of protection in Question 13; select the category “Barricades” for Jersey
barriers, fencing, and other structures that are other than Guard Rails or Bollards/Guard Posts. If
“Other” is selected, enter text describing the protection.
G5 – Pipe, Weld, or Joint Failure
Use this section to report failures only for main or service pipe, or welds, joints, or connections
joining main pipe or service pipe.
This section includes releases in or failures of main or service pipe, or welds, joints, or connections
joining main pipe or service pipe due to material defect, design defect, or in-service stresses such
as vibration, fatigue, and environmental cracking.
Mechanical Joint Failure
“Mechanical fitting” means a mechanical device used to connect sections of pipe. The term
“Mechanical fitting” applies only to:
a. Stab Type fittings;
b. Nut Follower Type fittings;
c. Bolted Type fittings; or
d. Other Compression Type fittings.
5a. Specify the Mechanical Fitting
Stab - Internally there are specially designed components including an elastomer seal, such as an
“O” ring, and a gripping device to affect pressure sealing and pull-out resistance capabilities.
Self-contained stiffeners are included in this type of fitting. With this style fitting the operator
would have to prepare the pipe ends, mark the stab depth on the pipe, and “stab” the pipe in to
the depth prescribed for the fitting being used.
Nut Follower – The components are generally a body; a threaded compression nut or a follower;
an elastomer seal ring; a stiffener or an integrated stiffener for plastic pipe; and, with some, a
gripping ring. Normally the design concept of this type of fitting typically includes an elastomer
seal in the assembly. The seal, when compressed by tightening of a threaded compression nut
grips the outside of the pipe, affecting a pressure-tight seal and, in some designs, providing pullout resistance. For plastic pipe, the inside of the pipe wall should be supported by the stiffener
under the seal ring and under the gripping ring (if incorporated in the design), to prevent collapse
of the pipe. A lack of this support could result in a loss of the seal affected by the seal ring or the
gripping of the pipe for pull-out resistance. This fitting style is normally used in pipelines 2Page 24 of 28
Instructions (rev 6-2023) for Form PHMSA F 7100.1 (rev 6-2023)
INCIDENT REPORT – GAS DISTRIBUTION SYSTEMS
inches in diameter and smaller. There are two categories of this type of joining device
manufactured. One type provides a seal only, and the other provides a seal plus pipe restraint
against pull-out.
Bolted – The bolt type mechanical fitting has similar components as the nut follower except
instead of a threaded compression nut or follower, there is a bolt arrangement. This fitting style
is most often used in pipelines 2-inches in diameter and larger.
Other Compression Type Fitting – Use “Other” only if the fitting does not fit one of the above
categories and is a compression type fitting. Describe the other fitting in the text field.
5b. Type of Mechanical Fitting Select the type of fitting which failed. Service or Main Tee
should be selected when the fitting provides for the diversion of the gas stream into a branch
pipeline without the use of further “tapping” either through a built-in mechanism or external
equipment. Tapping Tee should be selected when the fitting is externally attached to the pipeline
and a cutter or tapping machine is used. Select “Other” if the fitting type is not listed and provide
a description.
5c. Fitting Manufacturer
This is the name of the company that produced the fitting. The manufacturer name would
typically be on a sticker attached to a fitting or product or it may be stamped into the fitting.
Operators should take care in identifying the manufacturer. Some types of fittings are commonly
referred to as “Dresser fittings” (for example) even though the particular fitting may have been
manufactured by a different company. Operators should report here the company that actually
manufactured the involved fitting when known. To improve data quality, we have created a
drop-down list with the most common manufacturers that were reported in 2011. This is not an
exhaustive list. If you do not see the name of the manufacturer in the drop down, please select
“Other”, and enter the name of the manufacturer in the text box that is provided. If you do not
know the manufacturer, please select “unknown”.
5d. Part or Model Number
Enter the part/model number used by the manufacturer to designate the failed fitting. If the Part
or Model, Number is not known, then enter “unknown”.
5e. Fitting Material
Select the material that forms the body of the fitting. Select “Other” if the material is not listed
and provide a description.
5f. How did the joint failure occur?
Enter whether the gas was escaping between the fitting and the pipe (Leaked Through Seal), from
the body of the fitting (Leaked Through Body), or if the pipe pulled out of the fitting (Pulled Out).
Select “Other” if how the joint failed is not listed and provide a description.
13. Has one or more pressure test been conducted since original construction at the point of
the Incident?
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Instructions (rev 6-2023) for Form PHMSA F 7100.1 (rev 6-2023)
INCIDENT REPORT – GAS DISTRIBUTION SYSTEMS
Information from the initial post-construction pressure test is not to be reported. Records of test
pressure from past pressure tests may not be available. In such cases, the operator is to estimate
the test pressure using best available information.
G6 – Equipment Failure
This section applies to failures of items other than main or service pipe, or welds, joints, or
connections joining main pipe or service pipe.
Equipment Failure includes a release or failure resulting from: malfunction of control/relief
equipment including valves, regulators, or other instrumentation; failures of compressors, or
compressor-related equipment; failures of various types of connectors, connections, and
appurtenances; failures of the body of equipment, vessel plate, or other material (including those
caused by construction, material, or design defects or anomalies); and all other equipment-related
failures.
Malfunction of Control/Relief Equipment. Examples of this type of incident cause include:
overpressurization resulting from malfunction of control or alarm device; malfunction of relief
valve; valves failing to open or close on command; or valves which opened or closed when not
commanded to do so. If overpressurization or some other aspect of this incident was caused by
incorrect operation, the incident is to be reported under G7 - Incorrect Operation.
ESD System Failure means failure of an emergency shutdown system.
Other Equipment Failure. Select this sub-cause for types of Equipment Failure not included
otherwise, and describe in the space provided. If necessary, provide additional explanation in
PART H – Narrative Description of the Incident.
G7 – Incorrect Operation
Incorrect Operation includes a release or failure resulting from operating, maintenance, repair,
or other errors by facility personnel, including, but not limited to, improper valve selection or
operation, inadvertent overpressurization, improper selection of procedures, incorrect installation
of equipment, and failure to follow manufacturer instructions.
Other Incorrect Operation. Select this sub-cause for types of Incorrect Operation not included
otherwise and describe in the space provided. If necessary, provide additional explanation in
PART H – Narrative Description of the Incident.
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INCIDENT REPORT – GAS DISTRIBUTION SYSTEMS
G8 – Other Incident Cause
This section is provided for incidents whose cause is currently unknown, or where investigation
into the cause has been exhausted and the final judgment as to the cause remains unknown, or
where a cause has been determined which does not fit into any of the main cause categories listed
in sections G1 thru G7.
If the incident cause is known but doesn’t fit in any category in sections G1 through G7, select
Miscellaneous and enter a description of the incident cause, continuing with a more thorough
explanation in PART H - Narrative Description of the Incident.
If the incident cause is unknown at time of filing this report, select Unknown in this section and
select one reason from the accompanying two choices. Once the operator’s investigation into the
incident cause is completed, the operator is to file a Supplemental Report as soon as practicable
either reporting the apparent cause or stating definitively that the cause remains Unknown, along
with any other new, updated, and/or corrected information pertaining to the incident. This
Supplemental Report is to include all new, updated, and/or corrected information pertaining to all
portions of the report form known at this time, and not only that information related to the apparent
cause.
Important Note: Whether the investigation is completed or not, or if the cause continues to be
unknown, Supplemental Reports are to be filed reflecting new, updated, and/or corrected
information as and when this information becomes available. In those cases, in which
investigations are ongoing for an extended period of time, operators are to file a Supplemental
Report within one year of their last report for the incident even in those instances where no new,
updated, and/or corrected information has been obtained, with an explanation that the cause
remains under investigation in PART H – Narrative Description of the Incident. Additionally,
final determination of the apparent cause and/or closure of the investigation does NOT preclude
the need for the operator’s filing of additional Supplemental Reports as and when new, updated,
and/or corrected information becomes available.
PART J – CONTRIBUTING FACTORS
Contributing factor means an action or lack of action that when added to the existing
circumstances heightened the likelihood of the release or added to the impact of the release. The
Apparent Cause of the accident is contained in Part G. Do not select the Apparent Cause again
in Part J. If Contributing Factors were identified, select all that apply and explain each in the
Narrative.
PART H – NARRATIVE DESCRIPTION OF THE INCIDENT
Concisely describe the incident, including the facts, circumstances, and conditions that may have
contributed directly or indirectly to causing the incident. Include secondary, contributing, or root
causes when possible, or any other factors associated with the cause that are deemed pertinent.
Use this section to clarify or explain unusual conditions and to explain any estimated data.
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INCIDENT REPORT – GAS DISTRIBUTION SYSTEMS
If you selected Miscellaneous in section G8, the narrative is to describe the incident in detail,
including all known or suspected causes and possible contributing factors.
PART I – PREPARER AND AUTHORIZED PERSON
The Preparer is the person who compiled the data and prepared the responses to the report and who
is to be contacted for more information (preferably the person most knowledgeable about the
information in the report or who knows how to contact the person or persons most knowledgeable).
Enter the Preparer’s e-mail address if the Preparer has one, and the phone and fax numbers used
by the Preparer.
The Authorized Person is responsible for assuring the accuracy and completeness of the reported
data. In addition to their title, a phone number and email address are to be provided for the
Authorized Person.
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| File Type | application/pdf |
| Author | PHMSA |
| File Modified | 2023-08-03 |
| File Created | 2023-08-03 |