Burden Tables

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Overview

labor_rates
respondent_costs
Agency_cost
Ex 6.1
Ex 6.2
Ex 6.3
Ex 6.4

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Sheet 1: labor_rates

ICR Labor Category	BLS Citation	Icenhour, Melissa K.: http://www.bls.gov/oes/current/oessrci.htm Labor Rates for the 2018 Renewal ICR (Proposal)
		Wages & Salaries (2021$)	Loaded Hourly Rates for Renewal ICR (2021$)
Middle Manager	NAICS 211 (Oil and Gas Extraction); SOC 11-1021 (Gen & Op Mngr)	$76.54	$123.46
Senior Manager	NAICS 211 (Oil and Gas Extraction); SOC 11-3051 (Industrial Production Managers)	$82.03	$132.31
Engineers	NAICS 211 (Oil and Gas Extraction); SOC 17-2112 (Ind. Engineers)	$68.30	$110.10
Technicians	NAICS 211 (Oil and Gas Extraction); SOC 17-3024 (Electro-Mechanical Technicians)	$48.35	$77.99
Lawyer	NAICS 211 (Oil and Gas Extraction); SOC 23-1011 (Lawyers)	$99.27	$158.83
	Updated labor rates--4/12/23

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Sheet 2: 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	(H) Cost/Year (Using 2% consumption discount rate) ($2021)
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								-	-	-	-	-
		Incremental costs accounted for at the end of this section
	B. Required Activities
		Acid Gas Removal Units 1
			Gather CEMS data for e-GGRT reporting (M1)
8				LNG Storage reporters 4,5,6,7	1.00	2.0	2.00	1	2.0		0.2	0.1		$267
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		$267
			Conduct quarterly gas sampling (M2)
8				LNG Storage reporters 5,6,7,9	0.67	2.2	1.47	1	1.5		0.1	0.1		$196
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		$196
			Perform engineering calculation (M3)
8				LNG Storage reporters 5,7,10,11	0.17	3.0	0.50	2	1.0		0.1	0.1		$133
4				LNG Import and Export Equipment reporters 5,7,8,12	0.17	3.0	0.50	3	1.5		0.2	0.1		$200
			Perform simulation run using AspenTech HYSYS®, or API 4679 AMINECalc (M4)
8				LNG Storage reporters 6,7,13	0.42	2.1	0.88	1	0.9		0.1	0.0		$117
4				LNG Import and Export Equipment reporters 6,7,8,13	0.42	2.1	0.88	1	0.9		0.1	0.0		$117
		Nitrogen Removal Units 1
			Gather CEMS data for e-GGRT reporting (M1)
1				Onshore Natural Gas Processing reporters 4,7,14,15	1.00	2.0	2.00	1	2.0		0.2	0.1		$267
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		$133
8				LNG Storage reporters 4,7,14,15	1.00	2.0	2.00	1	2.0		0.2	0.1		$267
4				LNG Import and Export Equipment reporters 4,7,14,15	1.00	2.0	2.00	1	2.0		0.2	0.1		$267
			Conduct quarterly gas sampling (M2)
1				Onshore Natural Gas Processing reporters 7,9,13,15	0.67	1.3	0.87	56	48.5		4.9	2.4		$6,477
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		$89
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		$1,957
8				LNG Storage reporters 7,9,13,15	0.67	2.2	1.47	1	1.5		0.1	0.1		$196
4				LNG Import and Export Equipment reporters 7,9,13,15	0.67	2.2	1.47	1	1.5		0.1	0.1		$196
			Perform engineering calculation (M3)
1				Onshore Natural Gas Processing reporters 7,10,14,15	0.17	1.5	0.25	125	31.3		3.1	1.6		$4,170
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		$240
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		$1,802
8				LNG Storage reporters 7,10,14,15	0.17	3.0	0.50	2	1.0		0.1	0.1		$133
4				LNG Import and Export Equipment reporters 7,10,14,15	0.17	3.0	0.50	3	1.5		0.2	0.1		$200
			Perform simulation run using AspenTech HYSYS®, or API 4679 AMINECalc (M4)
1				Onshore Natural Gas Processing reporters 7,13,14,15	0.42	1.6	0.67	76	50.7		5.1	2.5		$6,761
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		$556
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		$2,802
8				LNG Storage reporters 7,13,14,15	0.42	2.1	0.88	1	0.9		0.1	0.0		$117
4				LNG Import and Export Equipment reporters 7,13,14,15	0.42	2.1	0.88	1	0.9		0.1	0.0		$117
		Equipment Leaks 1
			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		$34,430
			Determine emissions using population counts
10				Natural Gas Transmission Pipeline reporters 17,18,25	4.50	3.0	13.50	22		290.3				$23,406
		Blowdown Vent Stacks 1
			Calculate emissions
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		$179,678
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		$382,736
3				Underground Natural Gas Storage reporters 7,19,20,22	1.00	4.0	4.00	49	196.0		19.6	9.8		$26,156
8				LNG Storage reporters 7,19,20,22	1.00	4.0	4.00	5	20.0		2.0	1.0		$2,669
7				Natural Gas Distribution reporters 7,19,21,22,23	1.00	4.0	4.00	163	652.0		65.2	32.6		$87,010
9				Onshore Petroleum and Natural Gas Gathering and Boosting reporters 7,19,21,22	1.00	6.0	6.00	301	1,808.4		180.8	90.4		$241,332
		Other large release events 1
			Collect the necessary data and calculate emissions
1				Onshore Natural Gas Processing reporters 7,24,26,28	20.00	1.0	20.00	4.5	90.0		9.0	4.5		$12,011
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		$14,146
3				Underground Natural Gas Storage reporters 7,24,26,28	20.00	1.0	20.00	0.5	10.0		1.0	0.5		$1,335
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		$267
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		$79,537
7				Natural Gas Distribution reporters 7,24,27,29	20.00	2.0	40.00	5.1	204.0		20.4	10.2		$27,224
8				LNG Storage reporters 7,24,26,28	20.00	1.0	20.00	0.1	2.0		0.2	0.1		$267
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		$51,245
10				Natural Gas Transmission Pipeline reporters 7,24,27,29	20.00	2.0	40.00	1.0	40.0		4.0	2.0		$5,338
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		$3,737
		Combustion Emissions
			Determine fuel consumption through company records and calculate emissions
5				Onshore Petroleum and Natural Gas Production reporters 1,7,19,31,45,60	1.00	3	3.44	15,296	52,618.2		5,261.8	2,630.9		$7,021,936
9				Onshore Petroleum and Natural Gas Gathering and Boosting reporters 1,7,19,31,47,60	1.00	1	1.00	15,930	15,930.0		1,593.0	796.5		$2,125,868
7				Natural Gas Distribution reporters 1,7,19,31,60	1.00	1	1.00	163	163.0		16.3	8.2		$21,752
			Edits to 98.36(c)(1) and 98.26(c)(3)											$0
1				Onshore Natural Gas Processing reporters 7,69,70	10.00	1	13.00	454	5,902.0		590.2	295.1		$787,626
2				Onshore Natural Gas Transmission Compression reporters 7,69,71	10.00	1	9.40	624	5,865.6		586.6	293.3		$782,768
3				Underground Natural Gas Storage reporters 7,69,72	10.00	1	13.20	49	646.8		64.7	32.3		$86,316
4				LNG Import and Export Equipment reporters 7,69,73	10.00	1	10.90	11	119.9		12.0	6.0		$16,001
8				LNG Storage reporters 7,69,74	10.00	2	16.00	5	80.0		8.0	4.0		$10,676
		Crankcase venting 1
			Gather information and calculate emissions
5				Onshore Petroleum and Natural Gas Production reporters 7,19,61	2.00	1	2.00	478	956.0		95.6	47.8		$127,579
9				Onshore Petroleum and Natural Gas Gathering and Boosting reporters 7,19,61	2.00	1	2.00	354	708.0		70.8	35.4		$94,483
7				Natural Gas Distribution reporters 7,19,61	2.00	1	2.00	163	326.0		32.6	16.3		$43,505
1				Onshore Natural Gas Processing reporters 7,19,61	2.00	1	2.00	454	908.0		90.8	45.4		$121,173
2				Onshore Natural Gas Transmission Compression reporters 7,19,61	2.00	1	2.00	624	1,248.0		124.8	62.4		$166,546
3				Underground Natural Gas Storage reporters 7,19,61	2.00	1	2.00	49	98.0		9.8	4.9		$13,078
4				LNG Import and Export Equipment reporters 7,19,61	2.00	1	2.00	11	22.0		2.2	1.1		$2,936
8				LNG Storage reporters 7,19,61	2.00	1	2.00	5	10.0		1.0	0.5		$1,335
		Dehydrators
			Gather data for simulation run (large dehydrators) (M1) 62
1				Onshore Natural Gas Processing reporters 17,30,31	1	1.8	1.80	262		471.6				$38,030
5				Onshore Petroleum and Natural Gas Production reporters 17,30,31	1	19.8	19.80	142		2,811.6				$226,730
2				Onshore Natural Gas Transmission Compression reporters 1,5,17,30	1	19.8	19.80	227		4,494.6				$362,449
3				Underground Natural Gas Storage 1,5,17,30	1	19.8	19.80	25		485.1				$39,119
9				Onshore Petroleum and Natural Gas Gathering and Boosting reporters 1,5,17,30	1	11.8	11.76	287		3,375.0				$272,163
			Equipment counts and population emission factors (small dehydrators) (M2) 62
2				Onshore Natural Gas Transmission Compression reporters 1,5,10,17,30	0.17	27.0	4.50	227		1,021.5				$82,375
3				Underground Natural Gas Storage 1,5,10,17,30	0.17	27.0	4.50	25		110.3				$8,891
		Condensate storage tanks (formerly transmission storage tanks) 1
		Underground Storage
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		$1,290
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		$3
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		$42
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		$388
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		$227
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		$131
3			Calculate emissions 7,33,34,35,36,37		0.17	1.5	0.24	11	2.8		0.3	0.1		$374
		Hydrocarbon liquid Storage Tanks (formerly atmospheric storage tanks) 1
			Determine emissions by calculating flashing emissions with software program, such as AspenTech HYSYS® or API 4697 E&P Tank (M1)
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		$4,440,996
			Determine emissions by sampling and analyzing separator oil composition (M2)
1				Onshore Natural Gas Processing reporters 5,7,30	0.02	571.6	9.53	151	1,441.7		144.2	72.1		$192,399
			Determine emissions using equipment counts and population emission factors (M3)
1				Onshore Natural Gas Processing reporters 5,7,30	0.01	430.7	3.59	151		543.2				$43,801
		Dump valves 1
			Yearly inspections of dump valves (per tank)
5				Onshore Petroleum and Natural Gas Production reporters 5,17,38	0.17	427.0	71.17	738		52,519.8				$4,235,250
9				Onshore Petroleum and Natural Gas Gathering and Boosting reporters 5,17,38	0.17	114.8	19.14	421		8,057.0				$649,724
1				Onshore Natural Gas Processing reporters 5,17,38	0.17	427.0	71.17	160		11,384.9				$918,087
		Thief hatches 1
			Yearly inspections of thief hatches (per tank)
5				Onshore Petroleum and Natural Gas Production reporters 17,38,39	0.17	427.0	71.17	738		52,519.8				$4,235,249
9				Onshore Petroleum and Natural Gas Gathering and Boosting reporters 17,38,39	0.17	114.8	19.14	421		8,057.0				$649,724
1				Onshore Natural Gas Processing reporters 17,38,39	0.17	427.0	71.17	454		32,308.9				$2,605,424
		Produced water tanks 1
			Determine emissions using equipment counts and population emission factors
5				Onshore Petroleum and Natural Gas Production reporters 17,30,31,40	0.01	430.7	3.59	367		1,317.2				$106,222
9				Onshore Petroleum and Natural Gas Gathering and Boosting reporters 17,30,31,40	0.01	45.3	0.38	214		80.8				$6,517
1				Onshore Natural Gas Processing reporters 17,30,31,40	0.01	430.7	3.59	151		543.2				$43,801
		Well Venting for Liquids Unloading 1
			Measure flow rate (M1)
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		$949,753
			Calculate emissions (M1)
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		$1,899,506
			Determine well counts, number of events, well depth, calculate pressure, calculate flow (M2 and M3)
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		$1,197,114
		Mud degassing 1
		Use mudlogging data to calculate emissions (M1)
5			Onshore Petroleum and Natural Gas Production reporters 7,31,56,57,58		1.00	65.6	65.60	170	11,119.2		1,111.9	556.0		$1,483,864
		Use emission factor to calculate emissions (M2)
5			Onshore Petroleum and Natural Gas Production reporters 7,31,58,59		0.17	88.0	14.67	170	2,486.0		248.6	124.3		$331,758
		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 63,64		1.00	3.3	3.28	478	1,567.8		156.8	78.4		$209,229
		Flare Stacks--determine feed gas composition annually
5			Onshore Petroleum and Natural Gas Production reporters 75,76,77		0.17	6.3	1.05	478	501.9		50.2	25.1		$66,979
9			Onshore Petroleum and Natural Gas Gathering and Boosting reporters 75,78		0.17	1.0	0.17	248	41.3		4.1	2.1		$5,516
		Flare stacks - pilot monitoring 2
1			Onshore Natural Gas Processing reporters 31, 64, 65		12.00	2.3	28.09	384		10,788.0				$869,955
2			Onshore Natural Gas Transmission Compression reporters 31,64, 65		12.00	1.3	15.16	19		288.0				$23,225
3			Underground Natural Gas Storage reporters 31, 64, 65		12.00	2.9	34.67	9		312.0				$25,160
4			LNG Import and Export Equipment reporters 31, 64, 65		12.00	3.6	42.67	9		384.0				$30,966
5			Onshore Petroleum and Natural Gas Production reporters 31, 64, 65		12.00	146.2	1,754.16	378		663,072.0				$53,470,757
9			Onshore Petroleum and Natural Gas Gathering and Boosting reporters 31, 64, 65		12.00	20.6	247.40	248		61,356.0				$4,947,806
	C. Create Information (Included in 4B)
	D. Gather Existing Information (Included in 4E)
	E. Write Report
			Changing to reporting at the well-pad level or site ID
5				Onshore Petroleum and Natural Gas Production reporters 44,45	75.00	1.0	75.00	478	35,850.0	3,585.0	3,585.0			$4,828,062
9				Onshore Petroleum and Natural Gas Gathering and Boosting reporters 46,61,67	36.00	1.0	36.00	354	12,744.0	1,274.4	1,274.4			$1,716,285
			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						$1,602,708
2		Onshore Natural Gas Transmission Compression reporters						364						$2,632,836
3		Underground Natural Gas Storage reporters						16						$116,648
4		LNG Import and Export Equipment reporters						0						$0
5		Onshore Petroleum and Natural Gas Production reporters						309						$61,214,637
7		Natural Gas Distribution reporters						0						$0
8		LNG Storage reporters						2						$13,550
9		Onshore Petroleum and Natural Gas Gathering and Boosting reporters						0						$0
10		Natural Gas Transmission Pipeline reporters						4						$26,693
11		Offshore Petroleum and Natural Gas Production reporters						7						$186
TOTAL ANNUAL LABOR BURDEN AND COST														$169,446,958
												1,902,792.0
""
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						$3,640
4			LNG Import and Export Equipment reporters 31,48			8.8		1						$6,066
	Acid gas removal units
		Flow rate measurement for simulation (M4)
1			Onshore Natural Gas Processing reporters 5,49,50			1.0		76.0						$117,877
5			Onshore Petroleum and Natural Gas Production reporters 5,49,50			1.0		5.0						$7,755
9			Onshore Petroleum and Natural Gas Gathering and Boosting reporters 5,49,50			1.0		24.0						$37,224
8			LNG Storage reporters 5,49,50			1.0		1						$1,551
4			LNG Import and Export Equipment reporters 5,49,50			1.0		1.0						$1,551
	Nitrogen removal units
		Quarterly gas samples and analyses (M2)
1			Onshore Natural Gas Processing reporters 14,48			5.2		56.0						$120,442
5			Onshore Petroleum and Natural Gas Production reporters 14,48			4.0		1.0						$1,654
9			Onshore Petroleum and Natural Gas Gathering and Boosting reporters 14,48			8.8		10.0						$36,397
8			LNG Storage reporters 14,48			8.8		1.0						$3,640
4			LNG Import and Export Equipment reporters 14,48			8.8		1.0						$6,066
	Nitrogen removal units
		Flow rate measurement for simulation
1			Onshore Natural Gas Processing reporters 14,49,50			1.0		76.0						$117,877
5			Onshore Petroleum and Natural Gas Production reporters 14,49,50			1.0		5.0						$7,755
9			Onshore Petroleum and Natural Gas Gathering and Boosting reporters 14,49,50			1.0		24.0						$37,224
8			LNG Storage reporters 14,49,50			1.0		1						$1,551
4			LNG Import and Export Equipment reporters 14,49,50			1.0		1.0						$1,551
	Glycol dehydrators
		Flow rate measurement for simulation (M1)
1			Onshore Natural Gas Processing reporters 5,49,50			1.0		262						$406,366
5			Onshore Petroleum and Natural Gas Production reporters 5,49,50			1.0		142						$220,244
2			Onshore Natural Gas Transmission Compression reporters 5,49,50			1.0		227						$352,080
3			Underground Natural Gas Storage 5,49,50			1.0		25						$38,000
9			Onshore Petroleum and Natural Gas Gathering and Boosting reporters 5,49,50			1.0		287						$445,141
	Centrifugal and Reciprocating Compressors--contractor to perform compressor leak measurements on new compressor sources 2
1		Onshore Natural Gas Processing reporters 68				2.0		345						$426,090
2		Onshore Natural Gas Transmission Compression reporters 68				2.0		526						$649,632
3		Underground Natural Gas Storage reporters 68				2.0		48						$59,282
4		LNG Import and Export Equipment reporters 68				2.0		9						$11,116
8		LNG Storage reporters 68				2.0		2						$2,470
5		Onshore Petroleum and Natural Gas Production reporters 68				2.0		478						$590,351
9		Onshore Petroleum and Natural Gas Gathering and Boosting reporters 68				2.0		354						$437,205
	Hydrocarbon liquid Storage Tanks
		Simulation software yearly cost
1			Onshore Natural Gas Processing reporters 49,51			1.0		151						$31,296
	Pneumatic Pumps-measure volumetric flow rate regularly 2
5			Onshore Petroleum and Natural Gas Production reporters 31,52,53			134		478						$396,992
9			Onshore Petroleum and Natural Gas Gathering and Boosting reporters 31,53,54			41		354						$224,153
	Flare stacks - annual feed gas sampling and analysis
5			Onshore Petroleum and Natural Gas Production reporters 76,77			6.3		478						$984,957
9			Onshore Petroleum and Natural Gas Gathering and Boosting reporters 79			1		248						$102,574
Incremental O&M costs due to new sources 55
1		Onshore Natural Gas Processing reporters						53						$1,556,798
2		Onshore Natural Gas Transmission Compression reporters						364						$4,890,074
3		Underground Natural Gas Storage reporters						16						$272,993
4		LNG Import and Export Equipment reporters						0						$0
5		Onshore Petroleum and Natural Gas Production reporters						309						$1,483,855
7		Natural Gas Distribution reporters						0						$0
8		LNG Storage reporters						2						$12,038
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
YEAR 1-3 COSTS
TOTAL ANNUAL LABOR BURDEN AND COST														169,446,958
												1,902,792.0
""
TOTAL ANNUALIZED CAPITAL COST														$0
TOTAL ANNUAL LABOR COST														$169,446,958
TOTAL ANNUAL O&M COSTS														$14,103,716
TOTAL ANNUAL COSTS (Labor, O&M, and annualized capital)														$183,550,674
				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 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.
				10 Assumed activity takes 10 minutes (based on similar activity in December 2010 EIA for GHGRP).
				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].
				14 Assumed same average number of NRUs per reporter as AGRUs in RY2019 for each 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 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 6 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.
				23 Assumed 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 half of reporters 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.
				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 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 and 32 well-pads per sub-basin and 9 sub-basins per facility from subpart W data.
				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 activity occurs once per year per reporter for simulation software.
				50 Assumed one-time costs of Aspen HYSYS of $2,000 or $666.67 per year over the three years of the ICR.
				51 Assumed one time license costs of E&P Tanks of $600 over the three-year period or $200 per year.
				52 Based on average number of pneumatic pumps per facility, assumed would test 1/5 of pumps every year.
				53 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.
				54 Based on average number of pneumatic pumps per facility, assumed would test 1/2 of pumps every year.
				55 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.
				56 Assumed 1 hour per well to gather mudlogging data and calculate emissions.
				57 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.
				58 Assumed half of affected reporters would use Method 1 for mud degassing emissions and half would use Method 2.
				59 Assumed 10 minutes per well to calculate emissions from mud degassing using the emission factor.
				60 Assumed an additional 1.0 hours per year to incorporate combustion slip into existing calculations.
				61Assumed 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.
				62 Assumed half of reporters would use simulation software for dehydrators and half would use population emission factors.
				63 Assumed 1.0 hours per site to gather plugged well data annually.
				64 Assumed an hour of a technician's time per flare to inspect the pilot light
				65 Assumed pilot light inspection occurs once per month.
				66 Assumed 90 hours per reporter per year to report by well-pad instead of by sub-basin (75 hours of an Engineer's time, 7.5 hours of a Middle Manager's time and 7.5 hours of a Technician's time).
				67 Assumed 36 hours per reporter and twice per year to report by G&B site instead of by county (30 hours of an Engineer's time, 3 hours of a Middle Manager's time and 3 hours of a Senior Manager's time).
				68 Assumed an average of 2 compressors per reporter would be in one of the new compressor source modes
				69 Assumed 2 hours per year per each aggregation of units/common pipe reported under Subpart C. Assumed 5 fuel units per aggregation of units/common pipe reported.
				70 Based on 2019 data, 447 facilities in this industry segment reported 581 total CS, GP, and CP units to subpart C, resulting in an average of 1.3 aggregations of units/common pipe per facility reported under Subpart C.
				71 Based on 2019 data, 612 facilities in this industry segment reported 576 total CS, GP, and CP units to subpart C, , resulting in an average of 0.94 aggregations of units/common pipe per facility reported under Subpart C.
				72 Based on 2019 data, 41 facilities in this industry segment reported 54 total CS, GP, and CP units to subpart C, resulting in an average of 1.32 aggregations of units/common pipe per facility reported under Subpart C.
				73 Based on 2019 data, 11 facilities in this industry segment reported 12 total CS, GP, and CP units to subpart C, resulting in an average of 1.09 aggregations of units/common pipe per facility reported under Subpart C.
				74 Based on 2019 data, 5 facilities in this industry segment reported 8 total CS, GP, and CP units to subpart C, resulting in an average of 1.6 aggregations of units/common pipe per facility reported under Subpart C.
				75 Assumed sampling was equal to calculation (10 minutes per flare stack).
				76 Assumed 30% of sub-basins are involved in a custody transfer where gas samples are taken monthly. Only 70% requires sampling.
				77 Assumed 9 sub-basins per facility.
				78 Assumed analysis is per facility instead of per flare.

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Sheet 3: 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.

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Sheet 4: 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	1,902,792	$169,446,958	$14,103,716	$183,550,674

---

Sheet 5: 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 Petroleum and Natural Gas Production	777	1,618,079	2,082	$142,067,785	$3,693,563	$145,761,348
Offshore Petroleum and Natural Gas Production	141	34	0	$3,922	$0	$3,922
Onshore Petroleum and Natural Gas Gathering and Boosting	361	117,979	327	$10,767,359	$1,319,919	$12,087,278
Onshore Natural Gas Processing	515	121,589	236	$11,873,365	$2,776,745	$14,650,110
Onshore Natural Gas Transmission Compression	1,008	38,716	38	$4,064,345	$5,891,787	$9,956,131
Natural Gas Transmission Pipeline	53	881	17	$89,867	$187	$90,054
Underground Natural Gas Storage	68	3,144	46	$319,173	$370,275	$689,448
LNG Import and Export Equipment	11	563	51	$51,729	$26,350	$78,079
LNG Storage	7	262	37	$29,922	$24,890	$54,812
Natural Gas Distribution	164	1,547	9	$179,491	$0	$179,491
TOTAL	3,077	1,902,792	618	$169,446,958	$14,103,716	$183,550,674

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Sheet 6: Ex 6.3

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

---

Sheet 7: Ex 6.4

	Annual Average
Respondent Costs
Number of Respondents	3,077
Total Respondent Labor Hours	1,902,792
Total Respondent Labor Costs	$169,446,958
Non-labor (Capital and O&M) Costs	$14,103,716
Total Respondent Costs	$183,550,674
Agency Costs
Total Agency Burden Hours	2,080
Total Agency Labor Costs	$126,730
Total Burden Hours (Respondents + Agency)	1,904,872
Bottom Line Costs (Respondents + Agency)	$183,677,404