GOADs FAQs

Frequently Asked Questions about GOADS-2017
1. What is the geographic coverage area of the 2017 Gulfwide Outer Continental Shelf
(OCS) Emissions Inventory?
As in previous Gulf of Mexico OCS Emissions Inventory studies, the geographic area
for reporting via the GOADS-2017 software is the Gulf of Mexico Central and
Western Planning Areas, which is the portion of the OCS west of 87° 30' West
longitude.
If you are a lessee/operator in the Alaska OCS Region in the Chukchi, Beaufort, or
the portion of the Hope Basin Planning Areas, which is the North Slope Borough of
the state of Alaska, and plan to conduct oil and gas activities for calendar year 2017,
please contact BOEM at [email protected] to obtain guidance on
submitting activity data under the BOEM NTL No. 2016-N03.
2. How do I access the GOADS-2017 software and User’s Guide?
The GOADS-2017 software and User’s Guide will be available November 1, 2016,
and can be downloaded from: http://www.boem.gov/Gulfwide-Offshore-ActivityData-System-GOADS-2017/
3. How can I find my BOEM Company Number?
You can look up your company number at:
http://www.data.boem.gov/homepg/data_center/index.asp
4. How can I find my Complex and Structure ID numbers assigned by BOEM?
Complex and structure IDs can be obtained from:
http://www.data.boem.gov/homepg/data_center/index.asp
5. Do I have to report ALL of my structures and equipment, or can some be excluded?
All structures and equipment that operated in calendar year 2017 must be reported for
GOADS-2017. This includes minor sources. Temporary equipment and equipment
that operates intermittently must also be included, with the exception of equipment
which is intended for use exclusively in the event of equipment failure or for
emergency response purposes. Activities not associated with oil and gas production
(e.g., painting, sanding, welding) can be excluded.

1

6. What are the differences between GOADS-2014 and GOADS-2017?
The following updates were made to GOADS-2017:
•

•

•

•
•
•
•

•
•

•
•

A new BOEM email address is provided to request static (descriptive) 2014
GOADS data and for GOADS-2017 submittals:
[email protected]
Water depth is requested on the Structure screen (note that this field will be
imported from the GOADS-2014 static files provided by BOEM upon your
request).
A QC check was added to flag platforms with no equipment activity reported, but
platform fuel use, production, or throughput values are populated on the Structure
screen.
The requested Amine Unit unprocessed natural gas concentrations were expanded
to add CO2, N2, and O2.
The Drilling Rig equipment type is now called Drilling Equipment, and the
mobile platform drilling rig name is to be included if known.
For Combustion Flares, you can now indicate if the pilot fuel feed rate is included
in the total volume flared value.
The requested Fugitives data includes noting if an active Leak Detection and
Repair (LDAR) program is in place on the platform, and if the component count
is specific to the platform in question.
The control device options for Natural Gas Engines and Natural Gas, Diesel, and
Dual Fuel Turbines now include selective catalytic reduction (SRC).
Pressure/Level Controllers are now referred to as Pneumatic Controllers, and you
must indicate the type of controller (high bleed, low bleed, intermittent, or zero
bleed).
Fuel gas usage rates for Pneumatic Controllers and Pneumatic Pumps are no
longer optional.
Other revisions focused on programming errors associated with the QC checks
and QA Summary Form checks.

7. What are the similarities between GOADS-2014 and GOADS-2017?
•

BOEM is requesting that you track monthly activities for variables needed to
calculate emissions, and provide the data in one annual submittal.

•

The same emission sources are covered as in GOADS-2014 with essentially the
same monthly activity data are required for the following sources.

•

The program performs the same type of QC checks when the monthly data are
saved.

2

•

The same QA Summary Form is to be submitted to BOEM with the annual
submittal.

•

Like the GOADS-2014 data collection effort, the reported monthly GOADS-2017
volume vented and flared data must be consistent with the information provided
to the Office of Natural Resources Revenue (ONRR) Oil and Gas Operations
Report (OGOR) forms, including data reported based on metered volumes.

8. How do I submit my GOADS-2017 file?
Files must be submitted to BOEM electronically via the following email address:
[email protected]. BOEM should receive all 2017 data files before
April 17, 2018.
When the inventory is completed (12 monthly surveys), it should be exported to your
hard-drive for submittal to BOEM. To export the inventory, use the File|Export
GOADS-2017 Inventory Database option on the main menu.
Submit your completed GOADS.mdb file with the following naming format:
2017_Company Name_GOADS.mdb
In addition, please provide BOEM with the following information electronically
along with your submittal:
1. A PDF of the QA Summary Form.
2. A list of decommissioned structures for BOEM GOADS records (i.e., structures
that were operating in 2014, but not operating in 2017.)
3. Identification of individual wells tied into each platform to aid BOEM in future
GOADS-OGOR reconciliation efforts.
9. Which operating systems will support GOADS-2017?
While individual operating systems may vary, GOADS-2017 has been tested on
Microsoft Windows® XP, Windows® Vista, Windows® 7, 8, and 10 operating
systems.
10. Is there any way to facilitate reporting to the USEPA’s Greenhouse Gas Reporting
Program with GOADS-2017?
For your own records, you may want to note the 2017 annual production
hours/uptime that served as the basis for your GOADS-2017 submittal. Once the
emissions for 2017 are posted at the end of the study, there will be instructions for
extracting emissions data out of the 2017 Gulfwide Emission Inventory database to
aid you in reporting to USEPA under the Greenhouse Gas Reporting Rule.

3

11. Is there any way I can re-use the GOADS-2014 data files for this 2017 inventory
effort?
GOADS-2017 has a file import feature for your 2014 data files. You need to obtain
your 2014 files from BOEM, however, because the GOADS-2017 program structure
is slightly different. Please email [email protected] to obtain your
static data, including your company name, BOEM company number, and a list of all
your complex ID numbers. After importing the data files, you need to create records
for new structures and equipment (including minor sources) that were not in place in
2014. You also need to closely review and edit the imported 2014 data to make sure
they reflect operations for 2017.
12. What should I do if I received the following error message: “3024 Could not find file
“C:\Users\First Initial Last Name\Desktop\GOADS.MDB”?
If this is not the first time you have used GOADS-2017, you have moved or renamed
your database after using the program. Click “OK”. You will receive the 3024 error
window (below). Click “Cancel” to open the program.
“Error # 3024 was generated by DAO.Workspace
Could not find file “C:\Users\First Initial Last Name\Desktop\GOADS.MDB”
Can’t open GOADS database. The database may be in use or may have been moved.
If the database had been in use, please press Retry. If the database had been moved,
please press Cancel.”
Once GOADS opens, you can either:
•
•

Go to File> Open GOADS database, and browse for the last file you were
working on
Go to File> Create New GOADS database to create a new database.

13. When I run the QA Summary Report, I get the following error message: “3265 Item
not found in this collection.”
This error message is shown when not all of the monthly surveys have been added to
the file.
14. What if I can’t create the QA Summary Form?
BOEM attempted to test this feature on numerous operating systems, but it still may
be problematic for some users. If you are unable to generate this form, send an email
to [email protected] for assistance.

4

15. I do not have information to estimate fuel gas consumption for my Pneumatic
Controllers and Pneumatic Pumps.
You can get the information from the manufacturer. You can no longer leave it blank.
16. Does BOEM have any guidance on how to populate the cold vent screen?
To begin with, for equipment that is vented remotely to a cold vent, create the cold
vent record FIRST. If a vent ID is not entered, the program will automatically assume
the equipment is vented locally.
Note that vented emissions are NOT combusted. If emissions are combusted, create a
Combustion Flare record.
It is important to make sure that the monthly volume vented and flared total are
consistent with your monthly OGOR-reported value. BOEM will review both data
submittals for consistency.
17. Does BOEM have any guidance on how to populate the combustion flare screen?
To begin with, for equipment that is flared remotely, create the flare record FIRST. If
a flare ID is not entered, the program will automatically assume the equipment is
flared locally.
Note that flared emissions are combusted. If emissions are not combusted, create a
Cold Vent record.
GOADS-2017 now includes an option for you to indicate if the pilot fuel feed rate is
included in the total volume flared value provided.
It is important to make sure that the monthly volume vented and flared total are
consistent with your monthly OGOR-reported value. BOEM will review both data
submittals for consistency.
18. When do I have to report drilling?
You must report drilling activities for GOADS-2017 for all drilling that directly
occurs on a platform. If a rig is a fixed, permanent structure on a platform, it should it
be accounted for, and the platform drilling rig name is to be included if known.
19. Is the subject drilling that is conducted in an Area/Block with existing subsea
production well exempt? Or any type of drilling in an area/block with existing
subsea production well?
Any mobile source drilling activities that are not directly associated with a platform
(including jack up rigs, semisubmersibles, submersibles, and drill ships) will be
covered in the non-platform inventory, and BOEM will obtain for these sources from

5

the Bureau of Safety and Environmental Enforcement (BSEE) Field Operations
Division. They should not, therefore, be included in the GOADS-2017 submittal.
20. Does BOEM have any guidance on how to populate the losses from the flashing
screen?
The preferred data for this screen are to supply data for "SCF of flash per bbl of oil"
along with the “Type of vessel,” “API gravity of stored oil” and the “Oil/Condensate
throughput.” No data are needed for the operating pressures and temperatures of the
vessels if these data are supplied in GOADS.
An operator can obtain these data using the following methods:
•
•
•
•
•

Direct measurement
Vasquez-Beggs Correlation Equations (SPE Paper 6719)
www.nmenv.state.nm.us/aqb/Vasquez-Beggs-Flashing-Calculations.xls.
Pressurized oil sample and measurement of gas-to-oil ratio (GOR) in lab
American Petroleum Institute's (API) E&P TANK Version 2 software
Process simulators such as HYSYS or PROSIM

Flash gas is natural gas liberated when crude oil and condensate undergo a pressure
drop. There are many areas in the production, gas processing and transmission
processes where flash gas is generated and vented to the atmosphere, including:
•

•

Intermediate Flash: high/intermediate-pressure separators that send crude oil and
condensate to a low-pressure separator. This low-pressure separator operates at a
pressure greater than atmospheric pressure and may vent directly to the
atmosphere. A heater treater may also be utilized in an intermediate flash
situation. (See diagram below.)
Fixed Roof Storage Tanks: high/low-pressure crude oil and condensate are
flashed into tanks operating at atmospheric pressure. (See diagram below.)

Note that for storage tanks, emissions from flashing are in addition to working and
breathing emissions.
Below is a diagram of possible flash losses and routes for the flash gas.

6

For each stage of flash (e.g., low-pressure separator oil to heater treater) that is vented
to the atmosphere (locally or to remote vent) or flared (locally or to remote flare), the
operator should give the following data:
•
•
•
•
•
•
•
•

Type of vessel (high-pressure separator, low-pressure separator, heater treater,
surge tank, storage tank)
API gravity of stored oil
Operating pressure of vessel that has flash gas that is vented or flared
Operating temperature of vessel that has flash gas that is vented or flared
Oil/Condensate throughput
Operating pressure of vessel upstream of vessel with flash gas that is vented or
flared
Operating temperature of vessel upstream of vessel with flash gas that is vented or
flared
If available, the “SCF of flash per bbl of oil” can be entered along with the “Type
of vessel,” “API gravity of the stored oil" and "Oil/Condensate Throughput.” If
the “SCF of flash per bbl of oil” is entered, then the company does not have to
enter the operating pressures and temperatures of the vessels.

For example, an operator has a low-pressure separator (LP) that sends its oil to a
heater treater (HT), which dumps its oil to an atmospheric storage tank (T-1) that
vents its flash gas to the atmosphere locally. The low-pressure separator sends its
flash gas to the suction of the onsite compressor (i.e., the system). The heater treater

7

vents its flash gas remotely to the low-pressure vent system. The operator would
create two flash records, say FLASH-1 and FLASH-2. On FLASH-1, enter data for
the flash between the LP to HT flash, and on FLASH-2, enter data for the flash
between the HT and T-1 flash. Since the LP separator sends its gas to the onsite
compressor, this flash is not vented to the atmosphere (or flared) and would not be
reported.
21. Does BOEM have any guidance on how to populate the fuel combustion screens?
Diesel average heating value: average = 19,300 Btu/lb
Natural gas average heating value = 1,050 Btu/scf
Gasoline average heating value = 20,300 Btu/lb
To calculate total fuel used, see equations in the User’s Guide (and help screens) for
diesel and gasoline engines, boilers/heaters/burners, natural gas engines, and natural
gas turbines.
22. Sometimes the requested data are grayed out and I cannot edit them. Why is this?
GOADS-2017 will not let you see data that you have entered that are in conflict with
other data and selections you have made. For example, if you indicate that a piece of
equipment is vented locally and enter details on the local vent, the program will save
the information. If you then change the equipment to be vented remotely (where
details on the remote vent are recorded on the cold vent screen instead), the local vent
data will be “grayed out” so you know that BOEM will ignore the local vent data and
use the remote vent information instead of the local vent information.
23. Does BOEM have any guidance on how to populate the fugitives screen?
GOADS-2017 now includes noting if you have an active Leak Detection and Repair
(LDAR) program in place on the platform, how often inspections occur, and the
inspection method.
To estimate the average VOC weight percent of fugitives, the following information
is from the User’s Guide and help screen: The average VOC content of fugitive
emissions for the inventoried components and the selected stream type. You may find
it beneficial to use the following information as a starting point (Table 2).
Table 2. Speciation Fractions for Total Hydrocarbon (THC) Emissions by Stream Type
THC Fraction
Methane
Volatile Organic
Compounds (VOC)

0.945

Light Oil
(≥ 20 API Gravity)
0.612

Heavy Oil
(<20 API Gravity)
0.942

0.0137

0.296

0.030

Gas

Water/Oil*
0.612
0.296

Source: API, 1996. Calculation Workbook for Oil and Gas Production Equipment Fugitive Emissions.

8

GOADS-2017 now also asks you to indicate whether the component count provided
is specific to the platform (i.e., is an actual count provided rather than a surrogate). If
an actual count cannot be provided, the information provided by the Offshore
Operators Committee may be helpful as a starting point in compiling a component
count (Table 3).

15
25
9
34
70
9
69
9
12
45
21
32
8
9
121
10
43
11
0

1 1
0 3
0 0
4 6
0 3
0 1
0 9
0 1
0 1
1 7
2 0
1 4
0 2
0 1
2 12
0 0
0 0
0 0
0 0

0
0
0
0
0
0
4
0
0
6
0
0
0
0
0
0
7
0
0

Other Relief Valves

Polished Rods

0 0
0 0
0 0
0 0
0 0
0 0
0 0
0 0
0 0
0 0
0 0
0 0
0 15
0 0
0 0
0 0
0 0
0 0
0 0

Pressure Relief Valves

2
3
1
1
2
0
1
1
1
4
1
1
1
1
5
1
1
0
0

Meters

0
0
0
0
0
0
0
0
0
0
0
0
1
0
1
0
0
0
0

Instruments

0
0
0
0
0
0
4
0
0
0
0
0
0
0
0
0
0
0
0

Hatches

0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0

Dump Arms

Drains

73
114
47
69
78
16
138
37
40
194
26
85
70
18
391
18
148
19
9

Diaphragms

Flanges

Threaded
Connections
13
70
6
75
12
14
113
25
14
110
11
47
34
13
166
46
31
6
0

Compressor Seals*

0
0
3
1
3
0
0
0
0
0
0
0
1
0
8
0
0
0
0

Open Ended Lines

34
98
21
62
39
13
119
30
23
134
10
62
41
13
226
30
108
15
3

Pump Seals

Skid Type
Separator Skid
Heater Treater Skid
LACT Charge Pump Skid
LACT Skid
Pipeline Pumps Skid
Pig Launcher/Receiver Skid
Compressor Skid
Filter/Separator Skid
Gas Dehydration Skid
Glycol Regeneration Skid
Gas Meter
Fuel Gas Skid
Flotation Cell Skid
Scrubber
Amine Unit
Line Heater
Production Manifold
Wellhead
Import or Export Pipeline

Valves

Table 3. Summary of Equipment Inventory Data (Number of Components) by Skid Type

0
0
0
0
0
0
0
0
0
1
0
0
2
0
1
1
0
0
0

24. Where can I get information on reducing venting and flaring emissions?
The Natural Gas STAR Program is a flexible, voluntary partnership between the
USEPA and the oil and natural gas industry. Through the Program, the USEPA works
with companies that produce, process, and transmit and distribute natural gas to
identify and promote the implementation of cost-effective technologies and practices
to reduce emissions of methane, a potent greenhouse gas. For more information, see
https://www.epa.gov/natural-gas-star-program.

9

25. What is the average H2S content of pipeline quality gas?
For sweet pipeline quality gas, use 4 ppm H2S. Pipeline quality specifications are
usually 0.25 grains H2S per 100 SCF. One grain of H2S per 100 SCF is equal to
16 ppm.
26. What are standard conditions?
Standard pressure of 14.7 psia and standard temperature of 60°F.
27. How do I allocate fuel to different equipment?
Most platforms meter only total fuel (Natural Gas or Diesel) used. To allocate fuel to
each piece of fuel burning equipment do the following:
1. Calculate the theoretical fuel used for each piece of equipment based on the fuel
efficiency and hours operated for the month, e.g. Btu/hp-hr for engines or
MMBtu/hr for heater treaters.
2. To Calculate Theoretical Fuel Use for Natural Gas Engine, use the following
formula:
scf/Month = (Hrs/Month) (hp) (Btu/hp-hr) (scf/1050 Btu)
3. To Calculate Theoretical Fuel use for Heater/Treater or Burner, use the following
formula:
scf/Month = (Hrs/Month) (MMBtu/hr) (scf/1050 Btu) (1,000,000 Btu/MMBtu)
4. To Calculate Theoretical Fuel Use for Diesel Engine, use the following formula.
Gals/Month = (Hrs/Month) (hp) (Btu/hp-hr) (1lb/19,300 Btu) (1 gal/7.2558 lb)
28. What happens if I leave some months/equipment data fields blank?
If you do not select No Emission to Report, BOEM will assume that the platform or
equipment is operating that month, and surrogate data will be used to develop
emission estimates if necessary. BOEM will also assume that activity values that are
left blank (null) should be populated with surrogate data.
29. What are some of the surrogate data?
The surrogate data are for use as default data. If you do not have and cannot get
information about a piece of equipment or scientific data, use the surrogate data.
BOEM has approved these data for your use (See Table 4).
Table 4. Surrogate Stack Parameters Used to Supplement GOADS Data
Unit
Amine Unit– ventilation system for acid
gas from reboiler
Amine Unit– ventilation system for acid
gas from reboiler
Amine Unit–ventilation system for acid
gas from reboiler
Boiler/heater/burner – exhaust

Exit velocity

Field

Default Value
Calculated with AMINECalca

Exit temperature

110 oF

Combustion temperature

1832 oF

Exit temperature

400 oF

10

Unit
System
Boiler/heater/burner – exhaust system
Boiler/heater/burner – exhaust system
Boiler/heater/burner – exhaust system
Diesel Engine
Diesel Engine
Diesel Engine– exhaust system
Diesel Engine– exhaust system
Diesel Engine– exhaust system
Diesel Engine– exhaust system
Combustion Flare

Field

Default Value

Combustion Flare
Combustion Flare
Glycol Dehydrator– flash tank
Glycol Dehydrator– flash tank
Glycol Dehydrator– ventilation system

Outlet orientation
Outlet inner diameter
Exit velocity
Max rated fuel use
Average fuel use
Exit velocity
Exit temperature
Outlet orientation
Outlet inner diameter
Average combustion
temperature (excluding upsets)
Stack orientation
Stack inner diameter
Flash tank temperature
Flash tank pressure
Exit temperature

Glycol Dehydrator– ventilation system
Glycol Dehydrator– ventilation system
Glycol Dehydrator– ventilation system
Glycol Dehydrator– ventilation system

Outlet orientation
Flare feed rate (scf/hr)
Combustion temperature
Condenser temperature

Glycol Dehydrator– ventilation system
Losses from Flashing– ventilation system
Losses from Flashing– ventilation system
Natural Gas Engine
Natural Gas Engine
Natural Gas Engine– exhaust system
Natural Gas Engine– exhaust system
Natural Gas Engine– exhaust system
Natural Gas Engine– exhaust system
Natural Gas, Diesel, or Dual Fuel Turbine
Natural Gas, Diesel, or Dual Fuel Turbine
Natural Gas, Diesel, or Dual Fuel
Turbine– exhaust system
Natural Gas, Diesel, or Dual Fuel
Turbine– exhaust system
Pneumatic Pumps– ventilation system
Pneumatic Controllers

Condenser pressure
Exit velocity
Outlet inner diameter
Max rated fuel usage
Average fuel usage
Exit velocity
Exit temperature
Exit temperature
Outlet inner diameter
Max rated fuel use
Average fuel use
Exit velocity

0 degrees
12 inches
120 oF
60 psig
GLYCalc default (usually
212 oF)b
0 degrees
Calculated with GLYCalcb
1832 oF
110 oF (or calculated with
GLYCalc)b
14.8 psia
Calculated
Use Tank Vent Outlet Diameter
7500 Btu/hp-hr
7500 Btu/hp-hr
Calculated
4-cycle rich burn: 1100 oF
2-cycle lean burn: 700 oF
12 inches
10,000 Btu/hp-hr
10,000 Btu/hp-hr
Calculated

Outlet inner diameter

12 inches

Exit velocity
Equipment elevation (above sea
level)
Roof height above shell (ft)
Exit velocity
Exit temperature
Stack orientation
Flare feed rate

Calculated
50 ft

Storage Tank – General Information
Storage Tank– ventilation system
Storage Tank– ventilation system
Storage Tank– ventilation system
Storage Tank– ventilation system

Cold Vent
Vent

Stack outlet elevation (above
sea level)
Stack inner diameter

Vent

Exit temperature

11

0 degrees
12 inches
Calculated
7000 Btu/hp-hr
7000 Btu/hp-hr
Calculated
900 oF
0 degrees
12 inches
1832 oF

0.0625*(Tank Diameter, ft / 2)
Calculated
70 oF
0 degrees
Calculated (or use the calculated
storage tank exhaust vol. flow
rate)
50 ft
Calculated (average of submitted
data)
70 oF

Unit
Field
Default Value
Vent
Outlet orientation
0 degrees
Vent– upsets
Exit temperature
70 oF
a
AMINECalc is released by the Gas Technology Institute as part of the AIRCalc Air Emissions Inventory Report
Management Software Program (GTI 2001)
b
GLYCalc is released by the Gas Technology Institute, formerly the Gas Research Institute (GRI) (GTI 2000)

30. How do I convert API Gravity to Specific Gravity?
Specific gravity of oil = 141.5/(API gravity + 131.5)
31. What are the Ideal Gas Law Relationships?
Standard Conditions are 14.7 psia and 60 o F or 520 o R. Note: o R= degrees Rankine =
(o F + 460)
1 lb-mole of gas occupies approximately 379 standard cubic feet.
32. How do I calculate the weight in lbs of a gas that has a molecular weight of 18 lbs/lbmole?
Lbs of gas = (scf)(1 lb-mole/379 scf)(18 lbs gas/lb-mole)
33. How do I calculate horsepower of a compressor?
Horsepower of Compressor from Discharge, Suction Pressure and Compressed Gas
Volume
Hp = [50.5 * (1.255 / (1.255 - 1)) * (((Discharge Pressure + 14.7) / (Suction Pressure
+ 14.7)) ^ 0.203) – 1) * MMscfd] + 5% total hp for externally driven equipment
34. How do I calculate Exit Velocity for Boiler/heater/burner, ft/sec?

[(Average Fuel Usage, SCF/hr ) * (36.79 SCF Exhaust Gas/SCF Fuel) * (1 hr/3600 sec ) * ((460 + Exit Temperature, deg F) / 520)]
2
3.1416 * [((Stack Diameter, in.)/12 ) * 0.5]
35. How do I calculate Exit Velocity for Diesel Fired Engine, ft/sec?

[(Average Fuel Rate, gal/hr ) * (2713.3 SCF Exhaust Gas/gal Fuel) * (1 hr/3600 sec ) * ((460 + Exit Temperature, deg F) / 520)]
2
3.1416 * [((Stack Diameter, in.)/12 ) * 0.5]
36. How do I calculate Exit Velocity for Flare, ft/sec?

(Volumetric Fuel Rate, SCF/hr ) * [(10.52 SCF Exhaust Gas/SCF Fuel) * (1 hr/3600 sec) * ((460 + Exit Temperature, deg F) / 520)]
2
3.1416 * [((Stack Diameter, in.)/12) * 0.5]
37. How do I calculate Flashing Exhaust Vol. Flow Rate, scf/hr?

(Oil/Condensate Throughput, bbl/yr) * (Standard cubic feet of flash per barrel of oil, SCF/bbl)
Hours Operated, hr/yr

12

38. How do I calculate Vent Exhaust Vol. Flow Rate, scf/hr?

(Volume Vented, excluding upsets, Mscf/month )* (1000)
Hours Operated, excluding upsets, hr/month

39. How do I calculate Exit Velocity (applicable for Flashing Losses, Glycol
Dehydrators, Pneumatic Pumps, Storage Tanks, and Vents), ft/sec?

(Exhaust Vol. Flow Rate, SCF/hr ) * ((460 + Exit Temperature, deg F)deg R / 520 deg R )
(3600 sec/hr ) * [3.1416 * [((Stack Diameter, in.)/12) * 0.5] 2 ]
40. How do I calculate Exit Velocity for Rich-burn, Natural Gas Fired Engine, ft/sec?

[(Average Fuel Rate, SCF/hr ) * (10.52 SCF Exhaust Gas/SCF Fuel) * (1 hr/3600 sec) * ((460 + Exit Temperature, deg F) / 520)]
2
3.1416 * [((Stack Diameter, in.)/12) * 0.5]
41. How do I calculate Exit Velocity for Lean-burn, Natural Gas Fired Engine, ft/sec?

[(Average Fuel Rate, SCF/hr ) * (20.08 SCF Exhaust Gas/SCF Fuel) * (1 hr/3600 sec) * ((460 + Exit Temperature, deg F) / 520)]
2
3.1416 * [((Stack Diameter, in.)/12) * 0.5]
42. How do I calculate turbine exit velocity?

[(Average Fuel Rate, SCF/hr ) * (36.79 SCF Exhaust Gas/SCF Fuel) * (1 hr/3600 sec) * ((460 + Exit Temperature, deg F) / 520)]
2
3.1416 * [((Stack Diameter, in.)/12) * 0.5]
43a. Do we need to report the diesel and jet fuel horizontal/cylindrical) tanks that
supply fuels for generators and helicopter?
No, they are not crude or condensate.
43b. Are there any tanks exempt from reporting due to size, capacity, material, or
throughput? E.g. are corrosion inhibitor tanks exempt? Are methanol tanks less
than 1000 gallons exempt?
Only storage tanks for crude oil and condensate are required to report under GOADS2017. There is no exemption from reporting based on size, capacity, or throughput.
44a. Can floatation cell emissions be categorized as "LP Cold Vent" emissions?
There’s a constant gas supply to this floatation cell to separate oil and water and
vapors are vented locally.
44b. Will the BOEM require the reporting of flash emissions from skim tanks?
Produced water from 3-phase separators, chemelectric treaters and sumps are routed
to skim tanks where the oil entrapped in the water is allowed to separate and is

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skimmed off. The amount of oil is at most a few barrels per day so the flash losses
would be negligible.
44c. How to estimate the losses from flashing for the O/W skimmer? Typically, the
water drawoff from the HP Separator goes to the O/W skimmer and mostly water.
I know the oil/condensate API coming out of O/W skimmer and its operating
pressure, but its oil/condensate flow is typically NOT measured and very small?
How can I estimate the losses from flashing of the O/W skimmer? Is there a
typical volume % (that should be very small) of the oil/condensate from the O/W
skimmer versus the total condensate to sales which is metered?
For GOADS-2017, BOEM is not requiring data for produced water separation
equipment (e.g., flotation cells).
45. Do I need to count the vents and valves on storage tanks in the fugitive component
count?
No, when you create a storage tank equipment record, the tank emissions will be
accounted for.
46. I have found that several emission sources have dual exhaust stacks. The diameters
of the stacks are the same but the heights and orientations are different. When
reporting the source exhaust information in GOADS how do we handle dual
exhaust stacks?
Report each exhaust stack separately as an emission source. For example, if you have
a line heater with 2 exhaust stacks, you can code them as Heater 1 Exhaust 1 and
Heater 1 Exhaust 2.
47. Does the level low or high shutdown (LSL or LSH) count as one level control
instrument? For example, an O/W separator normally has three LSL/LSH and two
level controllers for oil and water. Do I count it as 5 or 2 level controllers?
Count them as 5.
48. How does BOEM intend to use exit velocity? It seems exit velocity is a function of
production, therefore will be valid when operators begin submitting production
volumes. Given other data such as size of exhaust pipe, flow rate, temperature,
pressure and hours vented, exit velocity seems redundant.
Exit velocity is needed in air quality modeling, and is used by BOEM as a QA/QC
tool for the other reported variables.

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49. Does BOEM have certain guidelines to determine if oil is crude or condensate?
Condensate is a liquid hydrocarbon that lies in a range between oil and gas and is
almost always produced along with gas in the Gulf of Mexico. API gravity values for
condensate are generally within the range of 50 to 120 (Handbook of Oil Industry
Terms and Phrases, R.D. Langenkamp, 1988). A review of liquid commingling
systems in the Gulf of Mexico for the year 1995 indicated 37 major pipeline systems
carrying condensate liquids. API gravity data for these pipeline systems in the Gulf of
Mexico ranged from 42 to 68. Thus, API gravity values overlap for light crudes and
heavy condensates.
50. If a structure with separators, tanks, compressors, etc. is going to be out of service
throughout 2017 does a report have to be submitted?
To assist in BOEM’s completeness checks, a GOADS submittal is required if the
structure is out of service the entire year (select No Emission to Report at the
Structure level).
51. Is the subject sales gas data available for each platform in BOEM, if yes where is it?
Can I use the data that were imported from 2014?
Most companies will have a recent sales gas analysis for each facility and/or field that
can be used. These data are typically available from the production and accounting
departments. You should not use the data from 2014. You should use a current sales
gas analysis.
52. Do we need to count the new platforms that startup during the reporting year (e.g. if
they start up in March, September, or December)?
Yes, you need to report any platforms that operate any time during calendar year
2017.
53. A facility has a vent header and vent boom and also has pressured vessels that vent
locally. How do we report in GOADS? VEN-01 would be the existing Flare Boom.
Would we then continue with VEN-02 for say HP Separator #2, VEN-03 for LP
Separator, etc.? The only time these vessels would vent would be for emergency
relief, but they would not vent to the existing header.
That type of ID convention will work fine in GOADS, but remember you don’t create
a Vent ID for sources that vent locally. It is most important to make sure you track all
local vents, and don't double report what is vented to the existing header.

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54. Is the exhaust for the small pneumatic injection pumps listed as a vent location if the
exhaust is not piped to a remote location? Also is this referred to as a cold vent?
All pneumatic pumps should be entered as “Pneumatic Pumps.” They would not be
considered cold vents, but could be routed to a cold vent.
The “Ventilation System” tab is where the user should list where the gas is vented to vented locally, flare locally, vented remotely, flare remotely or routed to system.
55. I have a separator that routes to a condensate storage tank at atmospheric pressure
which, in turn, vents to the atmosphere. If I report flashing losses from the
separator to this tank and also report a storage tank, then does that cause double
counting of the emissions?
No. You would indicate on the ventilation tabs of both the flashing losses screen and
the storage tank screen that the emissions are vented locally. The calculations for the
storage tank do not include flashing emissions, only working and breathing
emissions.
56. Some of my engines have much larger fuel usages than your recommended Max
Rated Fuel Use for the diesel, natural gas engines (7,000 Btu/hp-hr) and turbines
(10,000 Btu/hp-hr). What values should I use? If I use my actual values, I think the
software will give an error?
Please enter the actual values for your equipment. If you trigger a QC error message,
you can use the comment field to indicate the value is valid for the equipment.
57. How do I specify on the glycol dehydrator ventilation system tab that the still
column vent is processed by a VRU and not a vent or flare?
On the glycol dehydrator General Information tab, you are asked for the Destination
of the Flash gas. Enter routed back into the system.
58. What is the expected MW of VOCs in a gas stream containing 95% methane and
2% ethane with the other 3% VOCs. These % are in mole or volume %. The mole
wt. of the gas is between 16 - 17.
A good average would be about 44.
59. I don't see a need to report a storage tank that its vent goes to a vapor recovery unit
which is running by electricity? Is this correct?
You need to report this tank, and select “Vapor Recovery and/or Condenser” as the
Installed Control Equipment on the Ventilation System tab. When we calculate
emissions, our program will make adjustments for the VR/C.

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