Burden/Cost Calculation Tables

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Overview

respondent_costs
Agency_cost
Ex 6.1
Ex 6.2
Ex 6.3
Ex 6.4

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Sheet 1: respondent_costs

				Year 1-3	(A) Hours per Occurrence	(B) Occurrences/ Respondent/Year	(C) Hours/ Respondent/ Year (A x B)	(D) Respondents/ Year	Engineer Hours/Year (C x D)	Technician Hours/Year	Middle Manager Hours/Year	Senior Manager Hours/Year	Lawyer Hours/Year	Costs ($)
1. APPLICATIONS (Not Applicable)
2. SURVEY AND STUDIES (Not Applicable)
3. ACQUISITION, INSTALLATION, AND UTILIZATION OF TECHNOLOGY AND SYSTEMS
4. REPORT REQUIREMENTS
	A1. Read Rule, Instructions, Guidance Documents for Subpart W
		Incremental costs accounted for at the end of this section
	A2. Read Rule, Instructions, Guidance Documents for Subpart A								-	-	-	-	-	$0
		Incremental costs accounted for at the end of this section
	B. Required Activities													$0
		Acid Gas Removal Units 1												$0
			Gather CEMS data for e-GGRT reporting (M1)											$0
8				LNG Storage reporters 4,5,6,7	1.00	2.0	2.00	1	2.0		0.2	0.1		$258
4				LNG Import and Export Equipment reporters 4,5,6,7,8	1.00	2.0	2.00	1	2.0		0.2	0.1		$258
			Conduct quarterly gas sampling (M2)											$0
8				LNG Storage reporters 5,6,7,9	0.67	2.2	1.47	1	1.5		0.1	0.1		$189
4				LNG Import and Export Equipment reporters 5,6,7,8,9	0.67	2.2	1.47	1	1.5		0.1	0.1		$189
			Perform engineering calculation (M3)											$0
8				LNG Storage reporters 5,7,10,11	0.17	3.0	0.50	2	1.0		0.1	0.1		$129
4				LNG Import and Export Equipment reporters 5,7,8,12	0.17	3.0	0.50	3	1.5		0.2	0.1		$194
			Perform simulation run using AspenTech HYSYS®, or API 4679 AMINECalc (M4)											$0
8				LNG Storage reporters 6,7,13	0.42	2.1	0.88	1	0.9		0.1	0.0		$113
4				LNG Import and Export Equipment reporters 6,7,8,13	0.42	2.1	0.88	1	0.9		0.1	0.0		$113
		Nitrogen Removal Units 1												$0
			Gather CEMS data for e-GGRT reporting (M1)											$0
1				Onshore Natural Gas Processing reporters 4,7,14,15	1.00	2.0	2.00	1	2.0		0.2	0.1		$258
5				Onshore Petroleum and Natural Gas Production reporters 4,7,14,15	1.00	0.0	0.00	0	-		-	-		$0
9				Onshore Petroleum and Natural Gas Gathering and Boosting reporters 4,7,14,15	1.00	1.0	1.00	1	1.0		0.1	0.1		$129
8				LNG Storage reporters 4,7,14,15	1.00	2.0	2.00	1	2.0		0.2	0.1		$258
4				LNG Import and Export Equipment reporters 4,7,14,15	1.00	2.0	2.00	1	2.0		0.2	0.1		$258
			Conduct quarterly gas sampling (M2)											$0
1				Onshore Natural Gas Processing reporters 7,9,13,15	0.67	1.3	0.87	56	48.5		4.9	2.4		$6,264
5				Onshore Petroleum and Natural Gas Production reporters 7,9,13,15	0.67	1.0	0.67	1	0.7		0.1	0.0		$86
9				Onshore Petroleum and Natural Gas Gathering and Boosting reporters 7,9,13,15	0.67	2.2	1.47	10	14.7		1.5	0.7		$1,893
8				LNG Storage reporters 7,9,13,15	0.67	2.2	1.47	1	1.5		0.1	0.1		$189
4				LNG Import and Export Equipment reporters 7,9,13,15	0.67	2.2	1.47	1	1.5		0.1	0.1		$189
			Perform engineering calculation (M3)											$0
1				Onshore Natural Gas Processing reporters 7,10,14,15	0.17	1.5	0.25	125	31.3		3.1	1.6		$4,033
5				Onshore Petroleum and Natural Gas Production reporters 7,10,14,15	0.17	1.8	0.30	6	1.8		0.2	0.1		$232
9				Onshore Petroleum and Natural Gas Gathering and Boosting reporters 7,10,14,15	0.17	3.0	0.50	27	13.5		1.4	0.7		$1,742
8				LNG Storage reporters 7,10,14,15	0.17	3.0	0.50	2	1.0		0.1	0.1		$129
4				LNG Import and Export Equipment reporters 7,10,14,15	0.17	3.0	0.50	3	1.5		0.2	0.1		$194
			Perform simulation run using AspenTech HYSYS®, or API 4679 AMINECalc (M4)											$0
1				Onshore Natural Gas Processing reporters 7,13,14,15	0.42	1.6	0.67	76	50.7		5.1	2.5		$6,539
5				Onshore Petroleum and Natural Gas Production reporters 7,13,14,15	0.42	2.0	0.83	5	4.2		0.4	0.2		$538
9				Onshore Petroleum and Natural Gas Gathering and Boosting reporters 7,13,14,15	0.42	2.1	0.88	24	21.0		2.1	1.1		$2,710
8				LNG Storage reporters 7,13,14,15	0.42	2.1	0.88	1	0.9		0.1	0.0		$113
4				LNG Import and Export Equipment reporters 7,13,14,15	0.42	2.1	0.88	1	0.9		0.1	0.0		$113
		Equipment Leaks 1												$0
			Conduct Leak Detection Surveys and Perform Emission Calculations
10				Natural Gas Transmission Pipeline reporters 7,16,25	4.00	3.0	12.00	22	258.0		25.8	12.9		$33,298
			Determine emissions using population counts											$0
10				Natural Gas Transmission Pipeline reporters 17,18,25	4.50	3.0	13.50	22		290.3				$22,636
		Blowdown Vent Stacks 1												$0
			Calculate emissions											$0
1				Onshore Natural Gas Processing reporters 7,19,20,22,23	1.00	4.0	4.00	337	1,346.4		134.6	67.3		$173,768
5				Onshore Petroleum and Natural Gas Production reporters 7,19,21,22	1.00	6.0	6.00	478	2,868.0		286.8	143.4		$370,148
3				Underground Natural Gas Storage reporters 7,19,20,22	1.00	4.0	4.00	49	196.0		19.6	9.8		$25,296
8				LNG Storage reporters 7,19,20,22	1.00	4.0	4.00	5	20.0		2.0	1.0		$2,581
7				Natural Gas Distribution reporters 7,19,21,22,23	1.00	4.0	4.00	163	652.0		65.2	32.6		$84,148
9				Onshore Petroleum and Natural Gas Gathering and Boosting reporters	1.00	6.0	6.00	301	1,808.4		180.8	90.4		$233,394
		Other large release events 1												$0
			Collect the necessary data and calculate emissions											$0
1				Onshore Natural Gas Processing reporters 7,24,26,28	20.00	1.0	20.00	4.5	90.0		9.0	4.5		$11,616
2				Onshore Natural Gas Transmission Compression reporters 7,24,26,28	20.00	1.0	20.00	5.3	106.0		10.6	5.3		$13,680
3				Underground Natural Gas Storage reporters 7,24,26,28	20.00	1.0	20.00	0.5	10.0		1.0	0.5		$1,291
4				LNG Import and Export Equipment reporters 7,24,26,28	20.00	1.0	20.00	0.1	2.0		0.2	0.1		$258
5				Onshore Petroleum and Natural Gas Production reporters 7,24,27,29	20.00	2.0	40.00	14.9	596.0		59.6	29.8		$76,920
7				Natural Gas Distribution reporters 7,24,27,29	20.00	2.0	40.00	5.1	204.0		20.4	10.2		$26,328
8				LNG Storage reporters 7,24,26,28	20.00	1.0	20.00	0.1	2.0		0.2	0.1		$258
9				Onshore Petroleum and Natural Gas Gathering and Boosting reporters 7,24,27,29	20.00	2.0	40.00	9.6	384.0		38.4	19.2		$49,560
10				Natural Gas Transmission Pipeline reporters 7,24,27,29	20.00	2.0	40.00	1.0	40.0		4.0	2.0		$5,162
11				Offshore Petroleum and Natural Gas Production reporters 7,24,26,28	20.00	1.0	20.00	1.4	28.0		2.8	1.4		$3,614
		Combustion Emissions
			Determine fuel consumption through company records and calculate emissions
5				Onshore Petroleum and Natural Gas Production reporters 1,7,19,31,72	0.50	1	0.50	478	239.0		23.9	12.0		$30,846
9				Onshore Petroleum and Natural Gas Gathering and Boosting reporters 1,7,19,31,72	0.50	1	0.50	354	177.0		17.7	8.9		$22,844
7				Natural Gas Distribution reporters 1,7,19,31,72	0.50	1	0.50	163	81.5		8.2	4.1		$10,518
		Crankcase venting 1
			Gather information and calculate emissions
5				Onshore Petroleum and Natural Gas Production reporters 7,19,73	2.00	1	2.00	478	956.0		95.6	47.8		$123,383
9				Onshore Petroleum and Natural Gas Gathering and Boosting reporters 7,19,73	2.00	1	2.00	354	708.0		70.8	35.4		$91,375
7				Natural Gas Distribution reporters 7,19,73	2.00	1	2.00	163	326.0		32.6	16.3		$42,074
1				Onshore Natural Gas Processing reporters 7,19,73	2.00	1	2.00	454	908.0		90.8	45.4		$117,188
2				Onshore Natural Gas Transmission Compression reporters 7,19,73	2.00	1	2.00	624	1,248.0		124.8	62.4		$161,068
3				Underground Natural Gas Storage reporters 7,19,73	2.00	1	2.00	49	98.0		9.8	4.9		$12,648
4				LNG Import and Export Equipment reporters 7,19,73	2.00	1	2.00	11	22.0		2.2	1.1		$2,839
8				LNG Storage reporters 7,19,73	2.00	1	2.00	5	10.0		1.0	0.5		$1,291
		Dehydrators												$0
			Gather data for simulation run (large dehydrators) (M1)											$0
1				Onshore Natural Gas Processing reporters 17,30,31	1	1.8	1.80	262		471.6				$36,779
5				Onshore Petroleum and Natural Gas Production reporters 17,30,31	1	19.8	19.80	142		2,811.6				$219,273
2				Onshore Natural Gas Transmission Compression reporters 1,5,17,30	1	19.8	19.80	227		4,494.6				$350,527
3				Underground Natural Gas Storage 1,5,17,30	1	19.8	19.80	25		485.1				$37,832
9				Onshore Petroleum and Natural Gas Gathering and Boosting reporters 1,5,17,30	1	11.8	11.76	287		3,375.0				$263,211
			Equipment counts and population emission factors (small dehydrators) (M2)											$0
2				Onshore Natural Gas Transmission Compression reporters 1,5,10,17,30	0.17	27.0	4.50	227		1,021.5				$79,665
3				Underground Natural Gas Storage 1,5,10,17,30	0.17	27.0	4.50	25		110.3				$8,598
		Condensate storage tanks (formerly transmission storage tanks) 1												$0
		Underground Storage												$0
3			Screen for leaks using optical gas imaging instrument 7,32,34,35,36		0.17	1.5	0.24	39	9.7		1.0	0.5		$1,247
3			Screen for leaks using acoustic leak detection device 7,32,34,35,36		0.17	1.5	0.24	0	-		-	-		$0
3			Screen and quantify leaks using calibrated bag 7,33,34,35,36		0.25	1.5	0.37	0	-		-	-		$0
3			Screen and quantify leaks using flow meter 7,33,34,35,36		0.17	1.5	0.24	0	0.0		0.0	0.0		$2
3			Screen and quantify leaks using high volume sampler 7,33,34,35,36		0.25	1.5	0.37	1	0.3		0.0	0.0		$41
3			Quantify leaks using high volume sampler after screening with optical gas imaging instrument or flow meter 7,33,34,35,36		0.25	1.5	0.37	8	2.9		0.3	0.1		$376
3			Quantify leaks using acoustic leak detection after screening with optical gas imaging instrument or flow meter 7,33,34,35,36		0.25	1.5	0.37	5	1.7		0.2	0.1		$219
3			Quantify leaks using calibrated bags after screening with optical gas imaging instrument or flow meter 7,33,34,35,36		0.25	1.5	0.37	0	0.1		0.0	0.0		$15
3			Quantify leaks using flowmeter after screening with optical gas imaging instrument or flow meter 7,33,34,35,36		0.25	1.5	0.37	3	1.0		0.1	0.0		$126
3			Calculate emissions 7,33,34,35,36,37		0.17	1.5	0.24	11	2.8		0.3	0.1		$362
		Hydrocarbon liquid Storage Tanks (formerly atmospheric storage tanks)												$0
			Determine emissions by calculating flashing emissions with software program, such as AspenTech HYSYS® or API 4697 E&P Tank (M1)											$0
1				Onshore Natural Gas Processing reporters 5,7,30	0.50	439.8	219.90	151	33,278.2		3,327.8	1,663.9		$4,294,925
			Determine emissions by sampling and analyzing separator oil composition (M2)											$0
1				Onshore Natural Gas Processing reporters 5,7,30	0.02	571.6	9.53	151	1,441.7		144.2	72.1		$186,071
			Determine emissions using equipment counts and population emission factors (M3)											$0
1				Onshore Natural Gas Processing reporters 5,7,30	0.01	430.7	3.59	151		543.2				$42,360
		Dump valves 1
			Yearly inspections of dump valves (per separator)											$0
5				Onshore Petroleum and Natural Gas Production reporters 5,17,38	0.17	23.5	3.92	164		643.0				$50,147
9				Onshore Petroleum and Natural Gas Gathering and Boosting reporters 5,17,38	0.17	1.6	0.27	22		6.0				$468
1				Onshore Natural Gas Processing reporters 5,17,38	0.17	23.5	3.92	160		627.2				$48,917
		Thief hatches 1
			Yearly inspections of thief hatches (per tank)											$0
5				Onshore Petroleum and Natural Gas Production reporters 17,38,39	0.17	427.0	71.17	738		52,519.8				$4,095,946
9				Onshore Petroleum and Natural Gas Gathering and Boosting reporters 17,38,39	0.17	114.8	19.14	421		8,057.0				$628,354
1				Onshore Natural Gas Processing reporters 17,38,39	0.17	427.0	71.17	454		32,308.9				$2,519,728
		Produced water tanks 1												$0
			Determine emissions using equipment counts and population emission factors											$0
5				Onshore Petroleum and Natural Gas Production reporters 17,30,31,40	0.01	430.7	3.59	367		1,317.2				$102,728
9				Onshore Petroleum and Natural Gas Gathering and Boosting reporters 17,30,31,40	0.01	45.3	0.38	214		80.8				$6,303
1				Onshore Natural Gas Processing reporters 17,30,31,40	0.01	430.7	3.59	151		543.2				$42,360
		Well Venting for Liquids Unloading 1												$0
			Measure flow rate (M1)											$0
5				Onshore Petroleum and Natural Gas Production reporters 7,30,31,41	0.08	536.0	44.67	159	7,116.9		711.7	355.8		$918,514
			Calculate emissions (M1)											$0
5				Onshore Petroleum and Natural Gas Production reporters 7,30,31,41	0.17	536.0	89.33	159	14,233.8		1,423.4	711.7		$1,837,029
			Determine well counts, number of events, well depth, calculate pressure, calculate flow (M2 and M3)											$0
5				Onshore Petroleum and Natural Gas Production reporters 7,30,31,42,43	0.17	168.9	28.15	319	8,970.5		897.0	448.5		$1,157,739
		Mud degassing 1
		Use mudlogging data to calculate emissions (M1)
5			Onshore Petroleum and Natural Gas Production reporters 68, 69, 70		1.00	65.6	65.60	170	11,119.2		1,111.9	556.0		$1,435,058
		Use emission factor to calculate emissions (M2)
5			Onshore Petroleum and Natural Gas Production reporters 70,71		0.17	65.6	10.93	170	1,853.2		185.3	92.7		$239,176
		Plugged wells 1
		Gather quantites related to plugged wells (quantities of natural gas, crude oil, and condensate produced that is sent to sale)
5			Onshore Petroleum and Natural Gas Production reporters 75,76		0.50	3.3	1.64	478	783.9		78.4	39.2		$101,174
	C. Create Information (Included in 4B)													$0
	D. Gather Existing Information (Included in 4E)													$0
	E. Write Report													$0
			Changing to reporting at the well-pad level or site ID											$0
5				Onshore Petroleum and Natural Gas Production reporters 44,45	12.00	1.0	12.00	478	5,736.0	478.0	956.0			$786,837
9				Onshore Petroleum and Natural Gas Gathering and Boosting reporters 46,47	3.00	1.0	3.00	354	1,062.0	354.0	354.0			$188,238
			Annual Compliance Reporting through e-GGRT and QA
			Incremental costs accounted for at the end of this section
5. RECORDKEEPING REQUIREMENTS
	A. Read Instructions (Included in 4A)
	B. Plan Activities (Included in 4B)
	C. Implement Activities (Included in 4B)
	D. Recordkeeping
	E. Time to Transmit or Disclose Information (included in 4E)
	F. Time to Train Personnel (included in 4A)
	G. Time for Audits (Not Applicable)
Incremental labor costs due to new sources
1		Onshore Natural Gas Processing reporters						53						$1,278,188
2		Onshore Natural Gas Transmission Compression reporters						364						$2,150,673
3		Underground Natural Gas Storage reporters						16						$79,270
4		LNG Import and Export Equipment reporters						0						$0
5		Onshore Petroleum and Natural Gas Production reporters						309						$16,411,333
7		Natural Gas Distribution reporters						0						$0
8		LNG Storage reporters						2						$9,205
9		Onshore Petroleum and Natural Gas Gathering and Boosting reporters						0						$0
10		Natural Gas Transmission Pipeline reporters						4						$26,499
11		Offshore Petroleum and Natural Gas Production reporters						7						$179
TOTAL ANNUAL LABOR BURDEN AND COST														$41,413,037
												417,821.0
""
Year 1-3					(A) Hours per Occurrence	(B) Occurrences/ Respondent/Year	(C) Hours/ Respondent/ Year (A x B)	(D) Respondents/ Year	Engineer Hours/Year (C x D)	Technician Hours/Year	Middle Manager Hours/Year	Senior Manager Hours/Year	Lawyer Hours/Year	(H) Cost/ Year
ANNUAL COSTS (O&M)
	Acid gas removal units
		Quarterly gas samples and analyses
8			LNG Storage reporters 31,48			8.8		1						$3,520
4			LNG Import and Export Equipment reporters 31,48			8.8		1						$5,867
	Acid gas removal units
		Flow rate measurement for simulation (M4)
1			Onshore Natural Gas Processing reporters 5,49,50			1.0		76.0						$114,000
5			Onshore Petroleum and Natural Gas Production reporters 5,49,50			1.0		5.0						$7,500
9			Onshore Petroleum and Natural Gas Gathering and Boosting reporters 5,49,50			1.0		24.0						$36,000
8			LNG Storage reporters 5,49,50			1.0		1						$1,500
4			LNG Import and Export Equipment reporters 5,49,50			1.0		1.0						$1,500
	Nitrogen removal units
		Quarterly gas samples and analyses (M2)
1			Onshore Natural Gas Processing reporters 14,48			5.2		56.0						$116,480
5			Onshore Petroleum and Natural Gas Production reporters 14,48			4.0		1.0						$1,600
9			Onshore Petroleum and Natural Gas Gathering and Boosting reporters 14,48			8.8		10.0						$35,200
8			LNG Storage reporters 14,48			8.8		1.0						$3,520
4			LNG Import and Export Equipment reporters 14,48			8.8		1.0						$5,867
	Nitrogen removal units
		Flow rate measurement for simulation
1			Onshore Natural Gas Processing reporters 14,49,50			1.0		76.0						$114,000
5			Onshore Petroleum and Natural Gas Production reporters 14,49,50			1.0		5.0						$7,500
9			Onshore Petroleum and Natural Gas Gathering and Boosting reporters 14,49,50			1.0		24.0						$36,000
8			LNG Storage reporters 14,49,50			1.0		1						$1,500
4			LNG Import and Export Equipment reporters 14,49,50			1.0		1.0						$1,500
	Glycol dehydrators
		Flow rate measurement for simulation (M1)
1			Onshore Natural Gas Processing reporters 5,49,50			1.0		262						$393,000
5			Onshore Petroleum and Natural Gas Production reporters 5,49,50			1.0		142						$213,000
2			Onshore Natural Gas Transmission Compression reporters 5,49,50			1.0		227						$340,500
3			Underground Natural Gas Storage 5,49,50			1.0		25						$36,750
9			Onshore Petroleum and Natural Gas Gathering and Boosting reporters 5,49,50			1.0		287						$430,500
	Centrifugal and Reciprocating Compressors--contractor to perform compressor leak measurements 2
5		Onshore Petroleum and Natural Gas Production reporters 51,52				2.0		478						$570,933
9		Onshore Petroleum and Natural Gas Gathering and Boosting reporters 51,52				2.0		354						$422,825
	Hydrocarbon liquid Storage Tanks
		Simulation software yearly cost
1			Onshore Natural Gas Processing reporters 49,53			1.0		151						$30,267
	Pneumatic Devices-measure volumetric flow rate regularly 2
1			Onshore Natural Gas Processing reporters 54,55,56			250		454						$1,362,000
7			Natural Gas Distribution reporters 56,57,58			33		163						$161,370
2			Onshore Natural Gas Transmission Compression reporters 31,56,58			33		624						$624,480
3			Underground Natural Gas Storage reporters 31,56,59			73		49						$71,600
5			Onshore Petroleum and Natural Gas Production reporters 31,55,56			1,765		478						$10,122,492
9			Onshore Petroleum and Natural Gas Gathering and Boosting reporters 31,55,56			407		354						$1,727,016
	Pneumatic Pumps-measure volumetric flow rate regularly 2
5			Onshore Petroleum and Natural Gas Production reporters 31,60,61			134		478						$383,934
9			Onshore Petroleum and Natural Gas Gathering and Boosting reporters 31,61,62			41		354						$216,780
Incremental O&M costs due to new sources 67
1		Onshore Natural Gas Processing reporters						53						$1,663,008
2		Onshore Natural Gas Transmission Compression reporters						364						$4,868,646
3		Underground Natural Gas Storage reporters						16						$276,608
4		LNG Import and Export Equipment reporters						0						$0
5		Onshore Petroleum and Natural Gas Production reporters						309						$7,364,715
7		Natural Gas Distribution reporters						0						$0
8		LNG Storage reporters						2						$10,913
9		Onshore Petroleum and Natural Gas Gathering and Boosting reporters						0						$0
10		Natural Gas Transmission Pipeline reporters						4						$187
11		Offshore Petroleum and Natural Gas Production reporters						7						$0
""
ANNUALIZED CAPITAL COSTS
	Flare stacks - continuous parameter monitoring 3
1			Onshore Natural Gas Processing reporters 31,63,64,65			2		454						$128,355
2			Onshore Natural Gas Transmission Compression reporters 31,63,64,65			1		624						$123,014
3			Underground Natural Gas Storage reporters 31,63,64,65			4		49						$24,418
4			LNG Import and Export Equipment reporters 31,63,64,65			3		11						$3,915
5			Onshore Petroleum and Natural Gas Production reporters 31,63,64,65			157		478						$10,708,030
9			Onshore Petroleum and Natural Gas Gathering and Boosting reporters 31,63,64,65			22		354						$1,108,836
	Incremental annualized capital costs due to new sources
1		Onshore Natural Gas Processing reporters						53						$14,984
2		Onshore Natural Gas Transmission Compression reporters						364						$71,758
3		Underground Natural Gas Storage reporters						16						$7,973
4		LNG Import and Export Equipment reporters						0						$0
5		Onshore Petroleum and Natural Gas Production reporters						309						$6,922,137
7		Natural Gas Distribution reporters						0						$0
8		LNG Storage reporters						2						$0
9		Onshore Petroleum and Natural Gas Gathering and Boosting reporters						0						$0
10		Natural Gas Transmission Pipeline reporters						4						$0
11		Offshore Petroleum and Natural Gas Production reporters						7						$0
""
YEAR 1-3 COSTS
TOTAL ANNUAL LABOR BURDEN AND COST														41,413,036.7
												417,821.0
""
TOTAL ANNUALIZED CAPITAL COST														$19,113,421
TOTAL ANNUAL LABOR COST														$41,413,037		$50,897,998
TOTAL ANNUAL O&M COSTS														$31,784,577
TOTAL ANNUAL COSTS (Labor, O&M, and annualized capital)														$92,311,035
				Assumptions
				1 New emission source for the listed industry segment(s).
				2 New measurement requirements for the listed industry segment(s).
				3 New equipment purchase requirements for the listed industry segment(s).
				4 Assumed 1 hour per year to gather CEMS data.
				5 Number of occurrences per respondent based on maximum average number reported by segment and by calculation method for RY2019 for other industry segments for this emission source.
				6 Assumed 1 reporter would use this method.
				7 For each hour of an Engineer's time, assumed 0.1 hours of a Middle Manager's time and 0.05 hours of a Senior Manager's time for oversight and review.
				8 Only LNG exporters use AGRU.
				9 Assumed activity takes 10 minutes (based on similar activity in December 2010 EIA for GHGRP) and multiplied by 4 for quarterly activities. (See https://www.epa.gov/ghgreporting/regulatory-impact-analysis-mandatory-reporting-greenhouse-gas-emissions-final-rule)
				10 Assumed activity takes 10 minutes (based on similar activity in December 2010 EIA for GHGRP). (See https://www.epa.gov/ghgreporting/regulatory-impact-analysis-mandatory-reporting-greenhouse-gas-emissions-final-rule)
				11 Assumed 2 reporters would use this method.
				12 Assumed 3 reporters would use this method.
				13 Assumed same amount of time per AGRU as for dehydrators in December 2010 EIA for GHGRP [10 minutes to compile data + 15 minutes to run simulation, per AGRU]. (See https://www.epa.gov/ghgreporting/regulatory-impact-analysis-mandatory-reporting-greenhouse-gas-emissions-final-rule)
				14 Assumed same average number of NRUs per reporter as AGRUs in RY2019 for each industry segment and calculation method.
				15 Assumed same number of reporters have NRUs as AGRUs in RY2019 for each calculation method.
				16 Assumed 4 hours per year per respondent to schedule contractor, review contractor results, etc.
				17 Activity conducted by a technician.
				18 Assumed 4.5 hours in first year. Assumed 10% of 4.5 hours in subsequent years. After the first year, the level of effort (LOE) will only involve accounting for changes from the previous year.
				19 Assumed activity occurs once per year per reporter.
				20 Assumed 4 hours per reporter per year to perform calculations for blowdown vent stacks.
				21 Assumed 4 hours per reporter per year to perform calculations for blowdown vent stacks.
				22 Assumed that each facility would calculate emissions using 98.233(u) and 98.233(v) and assign to the equipment type that represents the largest portion of the emissions by equipment or event type.
				23Assumed that 40% of reporters with desiccant dehydrators will be required to report blowdown vent stacks now that emissions from desiccant dehydrators are no longer being reported to subpart W and are no longer exempt from 98.233(i).
				24 Assumed 20 hours to gather the necessary data to estimate emissions from other large release events and minimal time to calculate the emissions.
				25 Assumed half of reporters would conduct leak surveys and the other half would use population leak factors.
				26 Assumed one large release event per year.
				27 Assumed two large release events per year.
				28 Assumed 1% of reporters have a large release event to report each year.
				29 Assumed 3% of reporters have large release events to report each year.
				30 LOE from December 2010 EIA (See https://www.epa.gov/ghgreporting/regulatory-impact-analysis-mandatory-reporting-greenhouse-gas-emissions-final-rule).
				31 Number of occurrences per respondent based on average number reported by segment for RY2019.
				32 Assumed 10 minutes per tank.
				33 Assumed 15 minutes per tank.
				34 Used average number of transmission tanks per reporter for underground storage segment (1.5 tanks per facility).
				35 Based on RY2019 data from transmission compression facilities, 515 unique facilities tested for leaks from transmission tanks. Of those 515 facilities, 503 used optical gas imaging to screen for leaks, 1 used flow meters to screen for leaks, and 11 used high volume sampling for screening and quantifying leaks. No facilities used calibrated bags or acoustic leak detection to screen and quantify leaks.
				36 Used same ratios from transmission tanks for underground storage condensate storage tanks.
				37 This is the sum of reporters using high volume samplers to quantify leaks and reporters using flowmeters to quantify leaks.
				38 Assumed inspections take 10 minutes per separator or 10 minute per tank.
				39 Number of occurrences based on total number of tanks reported in RY2019.
				40 Assumed the same number of produced water tanks per reporter as hydrocarbon storage tanks reported in RY2019 by industry segment.
				41 Assumed 1/3 of reporters would use M1.
				42 Assumed 2/3 of reporters would use M2 or M3.
				43 Assumed 10 minutes per well.
				44 Assumed 15 hours per reporter per year to report by well-pad instead of by sub-basin (12 hours of an Engineer's time, 2 hours of a Middle Manager's time and 1 hour of a Technician's time).
				45 Assumed an average of 3.44 wells per well-pad from NSPS OOOOb TSD.
				46 Assumed 5 hours per reporter per year to report by G&B site instead of by county (3 hours of an Engineer's time, 1 hour of a Middle Manager's time and 1 hour of a Technician's time).
				47 Assumed an average of 45 sites per Gathering and Boosting facility (15 centralized production, 15 compressor stations, and 15 other).
				48 Assumed testing costs of $400 per AGRU/NRU.
				49 Assumed flow measurement activity occurs once per year per AGRU/NRU facility.
				50 Based on OGI crew costs, assumed it would cost $300 to show up (travel, + set up) + $150/hr for measurements. Assuming 8 hour day for testing for $1,500.
				51 Assumed an average of 6 compressors per reporter (based on average number of reciprocating compressors per reporter from RY2019). NOD measurements are only required once every 3 years, so 2 compressors per year over the 3 year period of the ICR.
				52 Assumed costs only apply to NOD measurements. Only requiring volumetric measurements for Onshore Production and Gathering and Boosting if the compressors are subject to NSPS OOOOb. The NSPS only requires measurements when compressors are in operating or standby pressurized modes.
				53 Assumed one time license costs of E&P Tanks of $600 over the three-year period or $200 per year.
				54 Assumed 250 pneumatic devices per facility.
				55 Based on average number of pneumatic devices per facility, assumed would test 1/5 of devices every year.
				56 Assuming the testing crew would cost $300 to show up (travel, + set up) + $150/hr for measurements. Vent measurements are 15 minute long, so max 4 device measurements/hour, and 25-28 total devices could be measured in an 8 hour day and would cost about $1,500. Second day costs would be similar, since multi-day monitoring would incur hotel and additional per diem costs. Based on 25 devices at the site, an average cost of about $60 per device for the vent measurements
				57 Assumed 33 pneumatic devices per facility, same as Transmission Compression facilities.
				58 Based on average number of pneumatic devices per facility, assumed would test 1/2 of devices every year.
				59 Based on average number of pneumatic devices per facility, assumed would test 1/3 of devices every year.
				60 Based on average number of pneumatic pumps per facility, assumed would test 1/5 of pumps every year.
				61 Based on OGI crew costs, I estimate it would cost $300 to show up (travel, + set up) + $150/hr for measurements. Vent measurements are 5 minutes long, so max 12 device measurements/hour, and something like 50 total pumps could be measured in an 8 hour day and would cost about $1,500. Second day costs would be similar, since multi-day monitoring would incur hotel and additional per diem costs. Based on 50 pumps at the site, an average cost of about $30 per device for the vent measurements.
				62 Based on average number of pneumatic pumps per facility, assumed would test 1/2 of pumps every year.
				63 Assumed one continuous parameter monitoring device per flare stack.
				64 Estimated that 80% of oil and gas industry already monitors flow rate, so the need for continuous parameter monitoring is reduced.
				65 Assumed that continuous parameter monitoring device would cost $5,000 per flare. Assuming 10 year life and 7% interest, annualized cost is $712 per flare.
				66 Assumed an additional 0.5 hours per year per reporter to incorporate combustion slip into existing calculations.
				67 There are a total of 755 new sources expected to be required to comply with subpart W as a result of this rulemaking and the change in global warming potentials in the supplemental proposal.
				68 Assumed 1 hour per well to gather mudlogging data and calculate emissions.
				69 Assumed mudlogging is already being used so no costs for measurement equipment. If mudlogging is not already being used, would use method 2 instead of purchasing measurement equipment.
				70 Assumed half of affected reporters would use Method 1 for mud degassing emissions and half would use Method 2.
				71 Assumed 10 minutes per well to calculate emissions from mud degassing using the emission factor.
				72 Assumed an additional 0.5 hours per year to incorporate combustion slip into existing calculations.
				73 Assumed 2 hours per year to gather information (determine concentration of CH4 in gas stream entering the engine, determine total number of crank case vents on reciprocating internal combustion engines, and total operating hours per year for reciprocating internal combustion engines) and calculate emissions.
				74 Assumed half of reporters would use simulation software for dehydrators and half would use population emission factors.
				75 Assumed 0.5 hours per well per site to gather plugged well data annually.
				76 Assumed 5% of wells would be plugged per year.

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Sheet 2: Agency_cost

Information Collection Activity	Annual Responses	Total Annual Burden Hours	Labor Cost ($K)	Non-Labor Cost ($K)	Total Annual Cost ($K)										Information Collection Activity	Annual Responses	Total Annual Burden	Labor Cost	Non-Labor Cost	Total Annual Cost
W. Petroleum and Natural Gas Systems	1	2,080	$127	$0	$127		Agency in $K								W. Petroleum and Natural Gas Systems	1	10400	$545	$0	$545		Agency in $K
TOTAL	1	2,080	$127	$0	$127										TOTAL	1	10400	$545	$0	$545
Information Collection Activity	Annual Responses	Total Annual Burden	Labor Cost	Non-Labor Cost	Total Annual Cost		Agency in $								Information Collection Activity	Annual Responses	Total Annual Burden	Labor Cost	Non-Labor Cost	Total Annual Cost		Agency in $
W. Petroleum and Natural Gas Systems	1	2,080	$126,730	$0	$126,730										W. Petroleum and Natural Gas Systems	1	10400	$544,648	$0	$544,648
TOTAL	1	2,080	$126,730	$0	$126,730										TOTAL	1	10400	$544,648	$0	$544,648
					109000
Labor Rates
Managerial	$60.93	(GS-13, Step 1, + 60%)
Previous estimate was 5 FTE for 10 segments. Assumed that the addition of these significant changes to subpart W would be equivalnet to one FTE.

---

Sheet 3: Ex 6.1

Years 1-3	Number of Respondents	Total Labor Hours	Labor Costs	Non-Labor Costs (Annualized Capital/Startup and O&M)	Total Costs
	3,077	417,821	$41,413,037	$50,897,998	$92,311,035

---

Sheet 4: Ex 6.2

Industry Segment	Annual Number of Respondents	Total Hours	Annual Average Burden Per Respondent	Labor Costs	O&M and Capital Costs	Total Costs
Onshore Natural Gas Processing	515	52,560	102	$8,768,994	$3,936,094	$12,705,088
Onshore Natural Gas Transmission Compression	1,008	27,579	27	$2,755,614	$6,028,399	$8,784,013
Underground Natural Gas Storage	68	1,744	26	$167,324	$417,348	$584,673
LNG Import and Export Equipment	11	41	4	$4,605	$18,649	$23,254
Onshore Petroleum and Natural Gas Production	777	277,639	357	$27,957,105	$36,301,841	$64,258,946
Natural Gas Distribution	164	1,453	9	$163,069	$161,370	$324,439
LNG Storage	7	133	19	$14,714	$20,953	$35,667
Onshore Petroleum and Natural Gas Gathering and Boosting	361	16,886	47	$1,490,222	$4,013,157	$5,503,379
Natural Gas Transmission Pipeline	53	881	17	$87,596	$187	$87,783
Offshore Petroleum and Natural Gas Production	141	34	0	$3,793	$0	$3,793
TOTAL	3,077	417,821	123	$41,413,037	$50,897,998	$92,311,035

---

Sheet 5: Ex 6.3

Total Annual Burden Hours	Labor Costs ($2021)
2,080	$126,730

---

Sheet 6: Ex 6.4

	Annual Average
Respondent Costs
Number of Respondents	3,077
Total Respondent Labor Hours	417,821
Total Respondent Labor Costs	$41,413,037
Non-labor (Capital and O&M) Costs	$50,897,998
Total Respondent Costs	$92,311,035
Agency Costs
Total Agency Burden Hours	2,080
Total Agency Labor Costs	$126,730
Total Burden Hours (Respondents + Agency)	419,901
Bottom Line Costs (Respondents + Agency)	$92,437,765