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Anadarko Petroleum Corporation 

AIR QUALITY DISPERSION MODELING ANALYSIS REPORT 

BLACKHORNET EGOM DRILLING, COMPLETION, AND MAINTENANCE 

PROJECT		

Prepared	By:	

TRINITY CONSULTANTS

301	Main	Street,	Suite	900		

Baton	Rouge,	LA	70825	

(225)‐346‐4003	

August	2013	

Project No.		

131901.0021
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TABLE OF CONTENTS 

1. INTRODUCTION 1-1

1.1. Modeling Methodologies.....................................................................................................................................1‐2

1.2. Air Quality Analysis Results ...............................................................................................................................1‐3

2. REPRESENTATION OF MODELED SOURCES 2-1

2.1. Emissions Sources and Potential to Emit.......................................................................................................2‐1

2.2. Q/D Analysis............................................................................................................................................................2‐2

2.3. Modeled Parameters ............................................................................................................................................2‐2

2.4. PM Emissions Speciation.....................................................................................................................................2‐4

3. CLASS I AIR QUALITY DISPERSION MODELING REQUIREMENTS 3-1

3.1. Class I Area PSD Increment................................................................................................................................3‐1

3.1.1. Deposition ....................................................................................................................................................................................3‐3

3.1.2. Visibility ........................................................................................................................................................................................ 3‐4

3.1.3. October 2010 FLAG Phase I Revised Report	‐	Calpost (“Method 8”)................................................................... 3‐5

3.1.4. Ozone.............................................................................................................................................................................................. 3‐8

4. CLASS II AIR QUALITY DISPERSION MODELING REQUIREMENT 4-1

4.1. PSD Signinficant Analysis....................................................................................................................................4‐1

4.1.1. Pre‐	Construction Monitoring Analysis........................................................................................................................... 4‐2

4.1.2. Special Considerations for PM2.5.........................................................................................................................................4‐3

4.2. Additional Impacts Analysis ..............................................................................................................................4‐6

4.2.1. Growth analysis.........................................................................................................................................................................4‐6

4.2.2. Soils and vegetation analysis...............................................................................................................................................4‐6

4.2.3. Visibility analysis.......................................................................................................................................................................4‐6

5. CLASS I AND II AREA MODELING METHODOLOGY 5-1

5.1. Model Selection......................................................................................................................................................5‐1

5.2. Modeling Domains.................................................................................................................................................5‐1

5.3. Receptor Locations ...............................................................................................................................................5‐3

5.3.1. Receptors locations for Class I areas................................................................................................................................5‐3

5.3.2. Receptors locations for Class II areas............................................................................................................................... 5‐4

5.4. Terrain Processing FOR CLASS II Analysis ....................................................................................................5‐4

5.5. Building Downwash..............................................................................................................................................5‐4

5.6. CALMET Meteorological Processing ................................................................................................................5‐4

5.7. CALPUFF Model Processing................................................................................................................................5‐5

5.7.1. Ozone.............................................................................................................................................................................................. 5‐5

5.7.2. Ammonia.......................................................................................................................................................................................5‐6

5.8. CALPOST Postprocessing Analysis...................................................................................................................5‐6

6. SUMMARY OF DISPERSION MODELING RESULTS 6-1

6.1. Class I Area PSD Increment Results.................................................................................................................6‐1

6.2. Deposition................................................................................................................................................................6‐2

6.3. Visibility ...................................................................................................................................................................6‐2

6.4. Class II Area PSD SIL Results..............................................................................................................................6‐4

6.4.1. Ozone Impact Analysis............................................................................................................................................................6‐4

6.5. Additional Impact Analysis ................................................................................................................................6‐6

6.5.1. Growth analysis.........................................................................................................................................................................6‐6
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6.5.2. Soils and vegetation analysis...............................................................................................................................................6‐6

6.5.3. Visibility Analysis......................................................................................................................................................................6‐7

APPENDIX A: AREA MAP AND WORST-CASE DRILLSHIP LOCATION RELATIVE TO CLASS I AREAS 

APPENDIX B: WORST-CASE DRILLSHIP AND SUPPLY BOAT LOCATION RELATIVE TO CLASS II AREA 

APPENDIX C: LIST OF ALL LEASE BLOCKS WITHIN THE WEDGE 

APPENDIX D: MODEL INPUT PARAMETERS 

APPENDIX D1: CLASS I MODEL INPUT PARAMETERS 

APPENDIX D2: CLASS II MODEL INPUT PARAMETERS 

APPENDIX E: MODEL FILES ON DVD 

APPENDIX F: Q/D ANALYSIS SUMMARY 

APPENDIX G: SUMMARY OF EMISSION ESTIMATES 

APPENDIX H: WORST- CASE DRILLSHIP AND SUPPLY BOAT LOCATION 

		
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LIST OF FIGURES 

Figure	2‐1.		Particulate	Matter	Speciation	 2‐4

Figure	5‐1.		VISTAS	RHR	Model	Domains	 5‐2

	 	
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 LIST OF TABLES 

Table	1‐1.		Location	of	Anadarko’s	Project	Lease	Blocks	Relative	to	Class	I	Areas	 1‐1

Table	1‐2.		Location	of	Anadarko’s	Project	Lease	Blocks	Relative	to	Class	II	Areas	 1‐2

Table	2‐1.		Emission	Rates	Comparison	 2‐1

Table	2‐2.		Worst‐Case	Modeled	Locations	for	the	Drillship	 2‐3

Table	2‐3.		Worst‐Case	Modeled	Locations	for	the	Supply	Boats	 2‐3

Table	2‐4.		Stack	Parameters	for	Proposed	Operations	 2‐4

Table	2‐5	Drillship	PM	Speciation	Summary	 2‐5

Table	2‐6.		Supply	Boat	PM	Speciation	Summary	 2‐6

Table	2‐7.		Geometric	Dimensions	for	PM	Species	 2‐6

Table	3‐1.		Class	I	Area	PSD	Increments	and	Modeling	SILs	 3‐1

Table	3‐2.		Modeled	Emission	Rates	 3‐2

Table	3‐3.		Monthly	fS(RH),	fL(RH)	and	fSS(RH)	for	Breton	NWR	 3‐6

Table	3‐4.		Monthly	fS(RH),	fL(RH)	and	fSS(RH)	for	St.	Marks	NWR	 3‐7

Table	3‐5.		Annual	Average	Background	Values	for	Breton	&	St.	Marks	 3‐7

Table	4‐1.		Applicable	PSD	Air	Quality	Levels	 4‐1

Table	5‐1.		Vertical	Grid	Structure	 5‐3

Table	6‐1.		Air	Dispersion	Modeling	Results	‐	Class	I	Area	SILs	 6‐1

Table	6‐2.		Nitrogen	and	Sulfur	Deposition	 6‐2

Table	6‐3.		Method	8	‐	98th	Percentile	Extinction	Change	For	Drilling	Operations	 6‐3

Table	6‐4.		Air	Dispersion	Modeling	Results	‐	Class	II	Area	SILs	 6‐4

Table	6‐5.		2008	Emissions	of	NOx	and	VOCs	from	Point	Sources	in	the	Gulf	of	Mexico	 6‐5

Table	6‐6.		State‐	Level	Total	NOx	Emissions	for	Gulf	States	in	the	2008	NEI	 6‐6

Table	6‐7	Level	I	VISCREEN	Analysis	Input	Emission	Rates	 6‐7

Table	6‐8	Level	I	VISCREEN	Analysis	Input	Parameters	 6‐8
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Table	6‐9	Level	I	VISCREEN	Analysis	Results	 6‐8
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1. INTRODUCTION 

Anadarko	Petroleum	Corporation	(Anadarko)	is	applying	for	a	pre‐construction	and	operating	

permit	for	conducting	exploratory	drilling	activities	on	the	Outer	Continental	Shelf	(OCS)	of	the	Gulf	

of	Mexico	(GOM).		The	proposed	project	will	consist	of	the	initial	drilling	phase,	a	well	completion	

phase	and	a	maintenance	operation	phase.	The	exploratory	drilling	activity	is	planned	to	be	

conducted	at	various	lease	blocks	within	the	“wedge”	using	a	dynamically	positioned	drillship	

BlackHornet	and	associated	support	vessels	in	the	EGOM.		A	map	outlining	the	EGOM	“wedge”	is	

provided	in	the	Section	1	of	this	report.		A	list	of	all	the	lease	blocks	contained	within	the	“wedge”	is	

presented	in	Appendix	C.			

As	discussed	previously	in	this	report,	the	proposed	OCS	source	will	be	subject	to	requirements	of	

the	PSD	program.		The	PSD	review	will	be	required	for	PM10,	PM2.5,	NOX,	VOC,	GHGs,	and	CO.		Air	

quality	modeling	analyses	of	impacts	on	federally	protected	Class	I	areas	are	an	essential	component	

of	PSD	review,	and	are	performed	to	demonstrate	compliance	with	PSD	Class	I	area	Increment	

standards	and	AQRV.		Additionally,	as	a	part	of	the	PSD/Title	V	application	for	a	5‐year	permit,	an	air	

quality	modeling	analysis	needs	to	demonstrate	that	the	proposed	project	will	not:	

cause	or	significantly	contribute	to	a	violation	of	the	National	Ambient	Air	Quality	Standards	

(NAAQS);	

cause	ambient	concentrations	that	exceed	PSD	Increments,	or	

cause	any	other	adverse	impacts	to	the	surrounding	area	[i.e.	impacts	on	soil	and	vegetation,	

visibility	degradation,	etc.].		

This	air	dispersion	modeling	analysis	report	has	been	prepared	to	demonstrate	compliance	with	

PSD	Class	I	area	Increment	standards	and	AQRV	thresholds	in	the	three	federally	protected	Class	I	

areas	located	within	300	kilometers	(km)	of	the	project	lease	blocks,	as	summarized	in	Table	1‐1.		

Anadarko	has	identified	all	lease	blocks	currently	available	for	drilling	operations	in	EGOM	within	

the	“wedge”	and	has	determined	which	of	these	lease	blocks	are	closest	to	nearby	Class	I	and	Class	II	

areas.	The	Class	I	areas	being	considered	are	as	follows:		

1. Breton	National	Wildlife	Refuge	(Breton	NWR),	

2. St.	Marks	National	Wildlife	Refuge	(St.	Marks	NWR),	and	

3. Bradwell	Bay	Wilderness	Area.	

Table 1‐1.		Location of Anadarko’s Project Lease Blocks Relative to Class I Areas

Class I Area, State Distance

(km) Direction Federal Land Manager

Breton	National	Wildlife	Refuge,	LA	

(Breton	NWR)	 167	 NW	 U.S.	Fish	&	Wildlife	Service	(FWS)	

St.	Marks	National	Wildlife	Refuge,	

FL	(St.	Marks	NWR)	 285	 NE	 U.S.	Fish	&	Wildlife	Service	(FWS)	

Bradwell	Bay	Wilderness,	FL	 281	 NE	 U.S.	Forest	Service	(FS)	
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This	air	dispersion	modeling	analysis	report	is	provided	to	the	FLM	for	each	Class	I	area	listed	in	

Table	1‐1,	as	well	as	to	the	U.S.	EPA	Region	4	for	review	as	part	of	the	PSD	application	review	

process.	

To	assess	the	impacts	of	the	proposed	project	on	the	nearest	Class	II	area,	the	Class	II	area	receptors	

were	established	25	nautical	miles	from	the	nearest	corresponding		state’s	seaward	boundary	

extending	shoreward.		Specifically,	these	Class	II	area	receptors	were	positioned	at	the	boundary	

separating	the	Inner	and	Outer	OCS.		For	this	project	the	nearest	Class	II	area	receptor	is	more	than	

50	km	from	the	closest	drilling	location	as	summarized	below	in	Table	1‐2.	

Table 1‐2.		Location of Anadarko’s Project Lease Blocks Relative to Class II Areas

Class II Area, State Distance

(km) Direction US EPA

Inner/Outer	OCS	Boundary	 94.9	 NW	 US	EPA	Region	4	

1.1. MODELING METHODOLOGIES 

Air	quality	modeling	analyses	of	impacts	on	federally	protected	Class	I	areas	are	an	essential	

component	of	PSD	review,	and	are	performed	to	demonstrate	compliance	with	PSD	Class	I	

Increment	standards	and	AQRV	thresholds	for	regional	haze	and	deposition.		In	accordance	with	

40	CFR	52.21(p),	“the Federal Land Manager (FLM) has an affirmative responsibility to protect the air

quality related values (AQRVs) (including visibility) of Class I areas, and to consider whether a

proposed major emitting facility will have an adverse impact on such values.”		Therefore,	the	FLM	has	

the	authority	to	request	that	proposed	PSD	major	sources	perform	Class	I	area	modeling	to	

demonstrate	that	the	AQRVs	of	Class	I	areas	are	not	adversely	affected.		

Based	on	discussions	between	Trinity	and	the	FLMs	for	Breton	NWR,	St.	Marks	NWR,	and	Bradwell	

Bay	Wilderness,	Class	I	area	modeling	analyses	were	performed	to	demonstrate	that	the	proposed	

project	will	not	adversely	impact	the	AQRVs	at	any	of	the	three	Class	I	areas.1		Class	I	area	modeling	

analyses	were	also	performed	to	demonstrate	that	the	proposed	project	will	not	cause	or	contribute	

to	any	violations	of	allowable	PSD	Increments	within	affected	Class	I	areas.		The	CALPUFF	air	

dispersion	modeling	system	was	used	for	the	modeling	analysis.		The	CALPUFF	air	dispersion	

modeling	system	is	currently	the	U.S.	EPA	recommended	model	for	assessment	of	long‐range	

pollutant	transport	and	chemical	transformation.2			

This	modeling	analysis	has	been	completed	in	a	manner	that	conforms	to	the	applicable	rules	and	

guidance	documents	for	Class	I	and	Class	II	area	air	dispersion	modeling.		The	methodology	and	data	

resources	used	for	conducting	this	modeling	analysis	were	discussed	with	the	FLMs	for	Breton	

NWR,	St.	Marks	NWR,	and	Bradwell	Bay	Wilderness	via	email	and	phone	conversations	and	were	

approved	by	all	FLMs.		The	modeling	methodologies	were	also	discussed	via	email	and	phone	

																																																															

1

 Based on Personal Communication: Phone conversation between Ms. Jill Webster (FWS) and Mr. Rahul Pendse 

(Trinity) on October 12, 2012; E-mail from Ms. Jill Webster (FWS) to Mr. Dhesikan Venkatesan (Trinity) sent on 

October 10, 2012; E-mail correspondence between Mr. Rahul Pendse (Trinity), Ms. Jill Webster (FWS) and Ms. 

Melanie Pitrolo (FS) sent on August 15, 2013, and Phone conversation between Ms. Melanie Pitrolo (FS) and Mr. 

Rahul Pendse (Trinity) on August 15, 2013. 

2

 40 CFR Part 51, Appendix A to Appendix W (Revised, November 9, 2005). 
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conversations	with	U.S.	EPA	Region	4	and	have	been	approved	there	upon.	1,3			Input	parameters	

used	in	this	analysis	are	presented	in	Appendix	D.	

The	modeling	methods	used	in	this	analysis	have	been	developed	based	on	guidance	provided	in	the	

following	documents:		

U.S.	EPA:	Guideline	on	Air	Quality	Models,	40	CFR	Part	51	‐	Appendix	W	(Revised,	November	9,	

2005)	(referred	to	hereafter	as	Guideline),	

The	applicable	guidance	memorandum	from	Support	Center	for	Atmospheric	Modeling	(SCRAM)	

website,	the	Draft New Source Review Workshop Manual 4 ,	

The	Interagency	Workgroup	on	Air	Quality	Modeling	(IWAQM)	Phase 2 Summary Report 5,	

Reassessment	of	the	Interagency	Workgroup	on	Air	Quality	Modeling	(IWAQM)	Phase	2	

Summary	Report:	Revisions	to	Phase	2	recommendations(Draft	2009	report)	6,		

The	Federal	Land	Managers’	Air	Quality	Related	Values	Workgroup	(FLAG)	Revised Phase I

Report (FLAG	2010	report)	7,		

The	U.S.	EPA’s	Guidance	for	Estimating	Natural	Visibility	Conditions	under	the	Regional	Haze	

Rule8,		

The	U.S.	EPA’s	Regional	Haze	Regulations	and	Guidelines	for	Best	Available	Retrofit	Technology	

(BART)	Determinations9,		

Previous	communications	between	Trinity	and	EPA	Region	4,10	and	Previous	communications	

between	Trinity	and	the	FLM	for	the	three	Class	I	areas.	

1.2. AIR QUALITY ANALYSIS RESULTS 

The	results	of	the	air	quality	dispersion	modeling	analyses	presented	in	this	report	can	be	

summarized	as	follows:	

The	proposed	project	will	not	cause	adverse	impacts	to	the	ambient	air	quality	in	Class	I	areas	

based	on	the	Class	I	area	PSD	Increment	analysis	completed	for	the	three	Class	I	areas	that	are	

located	within	300	kilometers	from	the	project’s	worst‐case	lease	blocks	‐	Breton	NWR,	St.	

Marks	NWR,	and	Bradwell	Bay	Wilderness.		The	modeled	concentrations	for	NOX	(annual	

averaging	period),	PM2.5	(24‐hour	and	annual	averaging	periods)	and	PM10	(24‐hour	and	annual	

averaging	periods)	were	all	less	than	their	corresponding	significant	impact	levels	(SILs).	

The	proposed	project	will	not	cause	adverse	impacts	to	AQRV	in	the	three	Class	I	areas	based	on	

analysis	conducted	as	follows:	

																																																															

3

 Based on Personal Communication: Phone conversation between Mr. Stanley Krivo (EPA Region IV) and Mr. Rahul 

Pendse (Trinity) on October 10, 2012, July 9, 2013 and August 15, 2013; and E-mail correspondence between Mr. 

Stanley Krivo (EPA Region IV) and Mr. Rahul Pendse (Trinity) sent on October 11, 2012, July 10, 2013 and August 15, 

2013, respectively. 

4 EPA’s New Source Review Workshop Manual (DRAFT) (1990). 

5

 U.S. EPA, IWAQM Phase 2 Summary Report and Recommendations for Modeling Long-Range Transport Impacts, 

Research Triangle Park, North Carolina, EPA-454/R-95-006, December 1998. 

6

 U.S. EPA, Reassessment of IWAQM Phase 2 Summary Report: Revisions to Phase 2 Recommendations, Research 

Triangle Park, North Carolina, EPA-454/R-09-XXX, May 2009 Draft. 

7

 U.S. Forest Service – Air Quality Program, National Park Service – Air Resources Division, U.S. Fish and Wildlife 

Service – Air Quality Branch, Phase I Report of the Federal Land Managers’ Air Quality Related Values Workgroup 

(FLAG)--Revised, 2010.

8

 U.S. EPA, Guidance for Estimating Natural Visibility Conditions under the Regional Haze Rule, September 2003. 9

 U.S EPA, Regional Haze Regulations and Guidelines for Best Available Retrofit Technology (BART) Determinations, 

July 6, 2005.

10 Based on Personal Communication: Phone conversation between Mr. Stan Krivo (EPA Region 4) and Mr. Rahul 

Pendse (Trinity) on September 21, 2012. 
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 Visibility	and	deposition	analysis	(for	nitrogen	(N)	and	sulfur	(S))	completed	for	Breton	

NWR	and	St.	Marks	NWR.	

 Deposition	analysis	(for	N	and	S)	and	qualitative	ozone	analysis	conducted	for	Bradwell	Bay	

Wilderness.	

The	proposed	project	will	not	cause	or	significantly	contribute	to	a	violation	of	the	NAAQS;	

cause	ambient	concentrations	that	exceed	PSD	Increments,	or	cause	any	other	adverse	impacts	

to	the	surrounding	areas	[i.e.	impacts	on	soil	and	vegetation,	visibility	degradation,	etc.]	based	

on	the	Class	II	area	modeling	analysis	conducted	at	the	Inner/Outer	OCS	boundary	which	is	

located	25	nautical	miles	from	nearest	state	seawards	boundaries.		The	modeled	concentrations	

for	CO	(1‐hour	and	8‐hour),	PM10	(24‐hour),	PM2.5	(24‐hour	and	annual),	and	NO2	(1‐hour	and	

annual)	were	all	less	than	their	corresponding	Class	II	SILs.		

An	electronic	data	storage	disc	contains	all	relevant	model	input	and	output	files	for	the	Class	I	and	

Class	II	area	modeling	analysis	is	enclosed	with	this	report.		Refer	to	Appendix	E	for	a	list	of	all	files	

included	on	the	disc.	

The	remainder	of	this	modeling	report	is	organized	as	follows:	

Section	2	provides	a	brief	description	of	the	representation	of	the	modeled	sources,		

Section	3	describes	the	modeling	analyses	and	procedures	that	are	required	to	be	conducted	as	

part	of	Class	I	area	modeling	for	PSD	permit	applications,	

Section	4	describes	the	modeling	analyses	and	procedures	that	are	required	to	be	conducted	as	

part	of	Class	II	area	modeling	for	PSD	permit	applications,	

Section	5	describes	the	selection	of	an	appropriate	air	dispersion	model	and	the	inputs	required	

for	the	chosen	model	for	the	Class	I	and	Class	II	area	modeling	analysis,		

Section	6	provides	the	dispersion	modeling	results	for	the	Class	I	and	Class	II	area	air	quality	

analysis,		

Appendix	A	includes	an	area	map	showing	the	worst‐case	location	of	the	drillship	relative	to	the	

Class	I	areas,			

Appendix	B	includes	the	worst‐case	drillship	and	supply	boat	location	used	for	the	air	

dispersion	modeling,	

Appendix	C	includes	a	list	of	all	lease	blocks	contained	within	the	“wedge”,			

Appendix	D	includes	model	input	parameters	used	in	this	analysis,			

Appendix	E	includes	a	list	of	all	files	included	on	the	enclosed	disc,			

Appendix	F	includes	a	copy	of	the	Q/d	analysis	described	in	Section	2	is	presented	in	of	this	

modeling	report,				

Appendix	G	includes	a	summary	of	the	proposed	maximum	hourly,	daily,	and	annual	emissions,	

and			

Appendix	H	includes	calculations	for	the	worst‐case	location	of	the	drillship	and	supply	boat.	
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2. REPRESENTATION OF MODELED SOURCES 

2.1. EMISSIONS SOURCES AND POTENTIAL TO EMIT 

The sources of emissions for the proposed project primarily consist of internal combustion engines, 

painting operation, welding operation, dust collectors, mud-degassing, water blasting operation, 

miscellaneous equipment, and fuel storage tanks. For the support vessels, the only emission sources 

are internal combustion engines and fuel storage tanks. Anadarko will use the “worst-case” 

potential-to-emit scenario among all the operating scenario discussed in the Section 3 for assessing 

air quality impacts to demonstrate compliance with the Class I Increments, AQRVs and Class II SILs. 

This will give Anadarko the flexibility to drill and operate at any location within the worse-case lease 

block (nearest to respective Class I and Class II areas) or at any other location further away from a 

Class I area within the “wedge.” 

As described in the Section 3 of this report, the project includes six possible operating scenario or an 

equivalent combination thereof. Refer to Section 3 for the details of each operating scenario and the 

proposed air emission sources and their operating conditions associated with it. 

Among all the support vessels, the supply boats will be very frequently used. All other support 

vessels such as well evaluation vessels, stimulation vessels, tugs, and barges, will be used in a 

specific operating scenario. Moreover, the supply boats generate higher emissions when they are in 

transit arriving/departing from the drill ship than emissions generated when the supply boats are 

located adjacent to the drill ship during loading/unloading operations. The other support vessels 

generally generate more emissions during performing operations in the vicinity of the drill ship 

when compared against the emissions generated during their transit. Hence, placing a supply boat 

source at a distance of 25 nautical miles from the worst-case drillship location in the direction of 

nearest receptor should represent the worst case support vessel emission scenario for air 

dispersion modeling analysis. The worst-case support vessels emissions (i.e., supply boats with 

highest PTE) were utilized for this modeling analysis. 

For performing air dispersion analysis, maximum total emissions (i.e., sum of the drillship and 

supply boat emissions) for each pollutant were considered. Table 2-1 compares the emissions from 

different operational scenarios and modeled emission rates. The modeled emission rates represent 

the worst case combination among the different operating scenario. 

Table 2-1. Emission Rates Comparison 

Pollutant Source Emission Rates (lb/hr)

Model

ed 

Gas 

Flowbac

k

Scenario

Oil 

Flowback

Scenario

Stimulat

ion

Vessel

Scenario

General 

Well 

Completi

on 

Scenario

Well 

Evaluatio

n Vessel

Scenario

Drilling 

NOx

Supply 

Boats 84 41 41 41 82 41 82

Drill 

ship 540 566 582 575 513 573 534

Total 624 607 623 616 595 614 617

PM10 Supply 3 1 1 1 2 1 2
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Pollutant Source Emission Rates (lb/hr)

Model

ed 

Gas 

Flowbac

k

Scenario

Oil 

Flowback

Scenario

Stimulat

ion

Vessel

Scenario

General 

Well 

Completi

on 

Scenario

Well 

Evaluatio

n Vessel

Scenario

Drilling 

Boats

Drill 

ship 27 26 26 13 9 12 10

Total 30 27 25 14 11 13 12 

SO2

Supply 

Boats 0.5 <0.1 <0.1 <0.1 0.1 <0.1 <0.1

Drill 

ship 1.5 <2 <1 <0.5 0.4 0.4 0.4

Total 2 <2 <1 <0.5 2 0.5 0.5

CO

Supply 

Boats 100 24 24 24 48 24 48

Drill 

ship 1,000 1,061 779 191 177 181 182

Total 1,100 1,086 804 215 225 205 232

2.2. Q/D ANALYSIS 

Anadarko has completed a Q/d calculation to assess potential impacts of the proposed drilling and 

well completion operations on the nearest Class I area. The Q/d analysis compares the ratio of the 

sum of proposed annualized maximum 24-hour emission rates of all visibility impairing pollutants 

(in tons per year) and the distance to the nearest Class I area (in km) to a threshold value of 10, as 

determined by the FLM. The “Q” is the combined emissions increase from a source of SO2, NOX, 

PM10, and H2SO4 in tons per year (tpy) based on the maximum hourly emissions and “d” is the 

nearest distance to a Class I area in km from the source. 11 Emissions from sources that operate 

intermittently or seasonally will be adjusted to account for year round operation. The emissions 

represented in the Q/d analysis are conservatively based on the highest emissions between the 

drilling and well completion operations. Based on the results, a Class I area AQRV analysis is 

required for the project because the Q/d ratio for the proposed source is greater than 10. A copy of 

the Q/d analysis is provided in Appendix F.

2.3. MODELED PARAMETERS 

As mentioned previously, Anadarko is requesting the flexibility to drill and complete one or more 

wells in any of the lease blocks within the “wedge” while complying with any operational and 

emission limitations prescribed in the air permits that will be issued. Therefore, the Class I area 

modeling analysis was performed for each Class I area with the drillship assumed to be located at 

the closest point within the “wedge” of the project (worst-case location) to the Class I areas. 

For Breton-NWR, the NW corner of the Desoto Canyon lease block 141 was determined to be the 

worst-case drillship location. For St. Marks NWR and Bradwell Bay Wilderness, the NE corner of the 

Desoto Canyon lease block 149 was determined to be the worst-case drillship location. Similarly, 

 

11 U.S. Forest Service – Air Quality Program, National Park Service – Air Resources Division, U.S. Fish and Wildlife 

Service – Air Quality Branch, Phase I Report of the Federal Land Managers’ Air Quality Related Values Workgroup 

(FLAG)--Revised, 2010. 
Anadarko Petroleum Corporation 2-3 Trinity Consultants 

 

modeling	analysis	was	performed	for	the	Class	II	receptors		established	25	nautical	miles	from	

nearest	corresponding		state’s	seaward	boundary,	extending	shoreward.		The	locations	of	the	

associated	support	also	can	affect	the	impacts	at	the	receptors.			

The	calculations	for	the	worst‐case	location	of	the	drillship	are	presented	in	Appendix	H.		Table	2‐2	

and	summarizes	the	coordinates	of	the	worst‐case	drillship	locations	for	the	three	closest	Class	I	

areas	and	a	Class	II	area.		Table	2‐3	provides	the	distances	of	the	nearest	receptor	from	the	worst‐	

supply	boat	locations.	

	 		Table 2‐2.		Worst‐Case Modeled Locations for the Drillship		 	

Modeling Impact

Areas

Worst‐case Drillship Location (NAD 83)

Minimum

Distance (km)

Latitude (deg)

(North)

Longitude (deg)

(West)

Breton	NWR	 28.85298	 87.52278	 167	

St.	Marks	NWR		 28.85397	 86.68162559	 285	

Bradwell	Bay	

Wilderness	 28.85397	 86.68162559	 281	

Class	II	(Inner/Outer	

OCS	Boundary)	 28.85298	 87.52278	 94.90	

Table 2‐3.		Worst‐Case Modeled Locations for the Supply Boats

Modeling Impact

Areas

Worst‐case Supply Boat Location (NAD

83)

Minimum

Distance (km)

Latitude (deg)

(North)

Longitude (deg)

(West)

Nearest	Class	II	

Receptor	(Inner/Outer	

OCS	Boundary)

29.243385 87.5435355 48.6

St.	Marks	NWR	 29.2229722	 86.9505536	 55.07	

Anadarko	has	modeled	the	PM10,	PM2.5,	and	NOX	emissions	from	the	worst‐case	drillship	location	

assuming	that	all	emissions	would	be	emitted	through	a	single	stack	on	the	drillship.		This	approach	

results	in	concentrating	the	exhaust	through	the	single	stack	and	hence,	results	in	the	worst	case	

dispersion	modeling	scenario.		The	stack	parameters	for	this	single	stack	were	based	on	the	stacks	

associated	with	the	main	engines	on	the	drillship,	which	are	the	largest	sources	of	emissions	from	

the	proposed	operations.		A	similar	source	characteristic	approach	was	utilized	for	the	modeling	the	

worst‐case	supply	boat	emissions.		

The	stack	gas	exit	velocity	was	calculated	based	on	the	CFD	analysis	performed	on	the	main	engines.		

Similarly,	as	a	conservative	estimate	the	lowest	temperature	measured	across	all	operating	loads	

from	the	IMO	performance	test	data	was	used	in	the	modeling	analysis.12			The	stack	height	

																																																															

12 Based on Personal Communication: Phone conversation between Mr. Stanley Krivo (EPA Region IV) and Mr. Rahul 

Pendse (Trinity) on October 10, 2012. 
Anadarko Petroleum Corporation 2-4 Trinity Consultants 

 

represents	the	height	above	the	sea	level	(water	line)	to	the	main	engine	stack.			A	similar	approach	

was	utilized	for	obtaining	the	worst‐case	supply	boat	model	input	parameters.		A	summary	of	the	

stack	parameters	used	in	the	modeling	analysis	is	presented	in	Table	2‐4.	

Table 2‐4.		Stack Parameters for Proposed Operations

Source

Stack Height *

(m)

Stack Inside

Diameter

(m)

Stack Gas

Exit Velocity

(m/sec)

Stack Gas

Temperature

(K)

Drillship	 28.60	 1.1	 20.3	 593	

Supply	Boat	 5	 0.706	 0.64	 293	

				*	The	stack	height	represents	the	height	above	the	sea	level	(water	line).

2.4. PM EMISSIONS SPECIATION 

Modeling	of	visibility	impairment	due	to	PM	emissions	requires	that	the	components	of	the	exhaust	

stream	be	speciated	because	different	sizes	and	phases	of	particulate	matter	affect	visibility	to	

varying	extents.		The	amount	by	which	a	mass	of	a	certain	species	scatters	or	absorbs	light	is	termed	

the	extinction efficiency or	extinction coefficient,	and	varies	considerably	from	coarse	particulate	

matter	to	elemental	carbon.		Fine	particulate	matter	and	organic	aerosols	scatter	light	with	

intermediate	efficiencies,	and	ammonium	sulfate	and	ammonium	nitrate	(that	form	from	precursor	

SO2	and	NOX	emissions	in	the	presence	of	ambient	ammonia)	are	hygroscopic	species	that	scatter		

light	efficiently	in	the	presence	of	ambient	water	vapor.		Figure	2‐1depicts	the	speciation	of	

visibility‐affecting	pollutant	emissions	as	represented	in	the	VISTAS BART Modeling Protocol.

13

Figure 2‐1.		Particulate Matter Speciation

																																																															

13 VISTAS; Protocol for the Application of the CALPUFF Model for Analyses of Best Available Retrofit Technologies 

(BART), Revision 3.2 (August 31, 2006), Figure 4-3. http://www.vistassesarm.org/documents/BARTModelingProtocol_rev3.2_31Aug06.pdf
Anadarko Petroleum Corporation 2-5 Trinity Consultants 

 

Anadarko	estimated	speciated	PM	emissions	associated	with	the	proposed	operations	based	on	the	

AP‐42	emission	factors,	manufacturer	provided	data,	and	conservative	engineering	estimates.			

Total	PM10	(TPM10)	emissions	from	the	drillship	were	calculated	as	the	summation	of	TPM10

emissions	from	all	emission	sources	on	the	drillship.		TPM10	emissions	for	the	individual	emission	

sources	on	the	drillship	were	calculated	as	the	sum	of	filterable	PM10	(FPM10)	emissions	and	

condensable	particulate	emissions	(CPM).		As	described	in	Section	2.1	of	this	report,	the	emission	

sources	used	for	the	proposed	project	will	primarily	comprise	of	large	diesel	fired	engines.		

Although	the	drillship	will	also	have	a	few	small	diesel‐fired	engines,	the	large	diesel‐fired	engines	

will	contribute	a	vast	majority	of	the	emissions	from	the	proposed	drilling	operations.		Therefore,	

Anadarko	used	the	particle	size‐specific	emission	factors	for	large	diesel	fired	engines	from	AP‐42	to	

speciate	TPM10	into	FPM10	and	CPM.14		Filterable	particulate	less	than	3	μm	was	used	as	a	surrogate

for	filterable	PM2.5	(PMF).		No	representative	data	or	emission	factors	were	available	for	

determining	inorganic	(sulfates	(SO4)	and	nitrates	(NO3))	condensable	emissions.		Therefore,	

inorganic	condensable	emissions	from	the	drillship	were	assumed	to	be	zero.		Based	on	guidance	

provided	in	the	Procedure for Speciation of Emissions for VISTAS BART Modeling,	100%	of	non‐H2SO4

condensable	particulate	mass	was	assumed	to	be	organic	condensable	(OC).15		The	percentage	of	

coarse	filterable	particulate	matter	(PMC)	in	TPM10	was	calculated	as	the	difference	between	the	

percentages	of	FPM10	and	filterable	PM2.5	(PMF).		Consistent	with	the	previous	modeling	reports	

submitted	to	EPA	Region	4	for	similar	projects,	an	elemental	carbon	was	assumed	to	be	0%	due	to	

lack	of	representative	data	or	emission	factors.	

Table	2‐5	summarizes	the	particulate	speciation	breakdown	as	a	percent	of	total	PM10	emissions,	

and	provides	the	maximum	pound	per	hour	(lb/hr)	modeled	emissions	for	each	speciated	PM	

category	based	on	the	worst	case	1‐hour	averaging	period	for	the	proposed	project.	

Table 2‐5 Drillship PM Speciation Summary

Emissions Speciation*		

Percentage		

(% of Total

PM10)		

Modeled Emissions

lb/hr		

Total PM10 (TPM10)		 100%	 27.00	

Condensable portion of TPM10 (CPM) 13.4%	 3.63	

				Organic	portion	of	CPM	(SOA)	 13.4%	 3.63	

	Inorganic	portion	of	CPM		 0.0%	 0.00	

Filterable portion of TPM10 (FPM10)		 86.6%	 23.37	

	Coarse	Filterable	(PMC)		 3.0%	 0.80	

	Fine	Filterable	(PMF)		 83.6%	 22.57	

	Elemental	Carbon	(EC)		 0.0%	 0.00	

*Values	in	italics	are	not	modeled	in	CALPUFF	directly,	but	instead	are	shown	for	informative	purposes.

																																																															

14 AP-42, Table 3.4-2, Particulate and Particle-sizing Emission Factors for Large Uncontrolled Stationary Diesel 

Engines (October 1996). 15 Procedure for Speciation of Emissions for VISTAS BART Modeling, July 18, 2006.
Anadarko Petroleum Corporation 2-6 Trinity Consultants 

 

Table	2‐6	summarizes	the	particulate	speciation	breakdown	as	a	percent	of	total	PM10	emissions,	

and	provides	the	maximum	pound	per	hour	(lb/hr)	modeled	emissions	for	each	speciated	PM	

category	for	the	supply	boat	associated	operations.	

Table 2‐6.		Supply Boat PM Speciation Summary

Emissions Speciation*		

Percentage		

(% of Total

PM10)		

Modeled Emissions

lb/hr		

Total PM10 (TPM10)		 100%	 3.00

Condensable portion of TPM10 (CPM) 13.4%	 0.4

				Organic	portion	of	CPM	(SOA)	 13.4%	 0.4

	Inorganic	portion	of	CPM		 0.0%	 0.00

Filterable portion of TPM10 (FPM10)		 86.6%	 2.60

	Coarse	Filterable	(PMC)		 3.0%	 0.09

	Fine	Filterable	(PMF)		 83.6%	 2.51

	Elemental	Carbon	(EC)		 0.0%	 0.00

*Values	in	italics	are	not	modeled	in	CALPUFF	directly,	but	instead	are	shown	for	informative	purposes

The	average	particle	diameter	for	each	non‐default	speciated	particulate	(PM)	category	(PMF,	PMC)	

was	taken	as	the	geometric	mass	mean	diameter	for	that	category.

16		Geometric	standard	deviation	

was	assumed	to	be	zero	for	both	PMC	and	PMF.		Default	CALPUFF	values	for	geometric	mass	mean	

diameter	and	geometric	standard	deviation	were	used	for	SOA	particles.		A	summary	of	the	

geometric	mass	mean	diameter	and	geometric	standard	deviation	is	presented	in	Table	2‐7.	

Table 2‐7.		Geometric Dimensions for PM Species

Species

Geometric Mass

Mean Diameter

(microns)

Geometric Standard

Deviation (microns)

Filterable	Coarse	Particles	‐	PMC	

(PM3	to	PM10)	 6.5	 0.0	

Filterable	Fine	Particles	‐	PMF	

(PM0.5	to	PM3)	 1.75	 0.0	

Organic	Condensable	PM	‐	SOA	 0.48	 2.0	

																																																															

16 Methodology used is in accordance with the methodology presented in Example Screening BART Simulation using 

the VISTAS Regional Domain, Earth Tech, Inc., Concord, Massachusetts, June 9, 2006, available online at - 

http://www.src.com/datasets/VISTAS_Files/ExampleBARTSimulation_Guide_R.pdf 
Anadarko Petroleum Corporation 3-1 Trinity Consultants 

 

3. CLASS I AIR QUALITY DISPERSION MODELING REQUIREMENTS 

This	section	of	the	modeling	report	describes	the	procedural	requirements	for	assessing	the	impacts	

of	emissions	from	the	proposed	operations	on	Breton	NWR,	St.	Marks	NWR,	and	Bradwell	Bay	

Wilderness.	

3.1. CLASS I AREA PSD INCREMENT 

In	general,	all	PSD	permit	applications	are	required	to	demonstrate	through	air	quality	modeling	

that	the	emissions	increases	from	the	proposed	project	will	not	cause	or	contribute	to	any	violations	

of	allowable	increments	within	affected	Class	I	areas,	which	are	protected	to	a	greater	degree	(i.e.,	

the	allowable	increments	are	lower)	than	Class	II	areas.		A	significant	contribution	to	Class	I	area	

Increment	consumption	is	defined	as	a	modeled	concentration	in	excess	of	the	SILs	summarized	in	

Table	3‐1,	which	were	originally	developed	as	part	of	the	1996	New	Source	Review	(NSR)	reform	

rulemaking	and	have	subsequently	been	adopted	as	informal	modeling	SILs	for	Class	I	area	analyses	

that	are	used	to	determine	if	a	project	is	likely	to	cause	or	contribute	to	a	Class	I	area	Increment	

violation.	

Table 3‐1.		Class I Area PSD Increments and Modeling SILs

 

Pollutant Averaging Period

Class I

Increment

(g/m3)

Significance Level

(g/m3)

		 	 	

PM10	 24‐hour	 8.0	 0.32	

	 Annual	 4.0	 0.16	

PM2.5	 24‐hour	 2.0	 0.07	

	 Annual	 1.0	 0.06	

NO2	*	 Annual	 2.5	 0.1	

		 	 	

*	 On	 February	 9,	 2010,	 U.S.	 EPA	 Promulgated	 a	 NO2	 NAAQS	 for	 the	 1‐hr	 averaging	 period.	 	 However,	 a	 NO2	 PSD	

Increment	standard	 for	 the	1‐hr	averaging	period	was	not	established	as	part	of	 this	action.		See	75	Fed.	Reg.	6474,	

Primary National Ambient Air Quality Standards for Nitrogen Dioxide	(February	9,	2010).	

Since	the	proposed	OCS	source	will	have	potential	emissions	of	NOX,	PM2.5,	and	PM10	in	excess	of	the	

PSD	SERs,	the	Class	I	area	PSD	Increment	analysis	was	completed	for	each	of	these	pollutants.		

Consistent	with	the	air	dispersion	modeling	report,	the	PM2.5	modeling	analysis	was	conducted	

using	PM10,	and	addressing	fully	speciated	PM10	emissions	(discussed	in	Section	2.4)	including	all	

species	that	contribute	to	PM2.5	(e.g.,	fine	filterable	and	condensable	PM	emissions).	17			

The	modeled	emission	rates	shown	below	in	Table	3‐2,	were	conservatively	modeled	using	the	

maximum	hourly	PTE	rates	for	comparison	with	both	the	24‐hour	and	annual	averaging	period	SILs.	

																																																															

17 VISTAS, Protocol for the Application of the CALPUFF Model for Analyses of Best Available Retrofit Technology 

(BART), Revision3.2, revised August 31, 2006. 

http://www.vistas-sesarm.org/documents/BARTModelingProtocol_rev3.2_31Aug06.pdf
Anadarko Petroleum Corporation 3-2 Trinity Consultants 

 

Table 3‐2.		Modeled Emission Rates

Pollutant

Drillship

Modeled

Emission Rates

(lb/hr)

Supply Boat

Modeled

Emission Rates

(lb/hr)

Nitrogen	Oxides	(NOX)	 540	 84	

Sulfur	Dioxide	(SO2)	 1.5	 0.5	

Organic	portion	of	CPM	(SOA)	 3.63	 0.4	

Coarse	Filterable	(PMC)	 0.80	 0.09	

Fine	Filterable	(PMF)	 22.57	 2.51	

Carbon	Monoxide	(CO)	 1,000	 100	

The	summaries	of	emissions	of	pollutants	applicable	to	this	modeling	analysis	are	included	in	

Appendix	G	of	this	report.				Additionally,	all	NOX	emissions	were	conservatively	modeled	to	

represent	NO2	emissions.		No	puff	depletion	due	to	wet	or	dry	deposition	was	assumed	for	

determining	the	PM2.5,	PM10	and	NOX	concentrations	for	comparison	with	the	SILs.		Class	I	Area	

AQRV	Analyses	

The	FLAG	Phase	I	report	provides	the	following	definitions	relating	to	AQRV:18

Air Quality Related Value	–	A	resource,	as	identified	by	the	FLM	for	one	or	more	Federal

areas	that	may	be	adversely	impacted	by	a	change	in	air	quality.		The	resource	may	

include	visibility	or	a	specific	scenic,	cultural,	physical,	biological,	ecological,	or	

recreational	resource	identified	by	the	FLM	for	a	particular	area.	

Adverse Impact On Visibility	–	Visibility	impairment	which	interferes	with	the	

management,	protection,	preservation,	or	enjoyment	of	a	visitor’s	visual	experience	of	

the	Federal	Class	I	area	or	Class	II	area.		This	determination	must	be	made	on	a	case‐by‐

case	basis	taking	into	account	the	geographic	extent,	intensity,	duration,	frequency	and	

time	of	visibility	impairments,	and	how	these	factors	correlate	with	(1)	times	of	visitor	

use	of	the	Class	I	area,	and	(2)	the	frequency	and	timing	of	natural	conditions	that	

reduce	visibility.		This	term	does	not	include	effects	on	integral	vistas.		[40	CFR	

§51.301]	

Adverse Impact on an AQRV	–	An	unacceptable	effect,	as	identified	by	an	FLM	that	

results	from	current,	or	would	result	from	predicted,	deterioration	of	air	quality	in	a	

Federal	Class	I	or	Class	II	area.		A	determination	of	unacceptable	effect	shall	be	made	on	

a	case‐by‐case	basis	for	each	area	taking	into	account	existing	air	quality	conditions.		It	

should	be	based	on	a	demonstration	that	the	current	or	predicted	deterioration	of	air	

quality	will	cause	or	contribute	to	a	diminishment	of	the	area’s	national	significance,	

impairment	of	the	structure	and	functioning	of	the	area’s	ecosystem,	or	impairment	of	

the	quality	of	the	visitor	experience	in	the	area.	

																																																															

18 U.S. Forest Service – Air Quality Program, National Park Service – Air Resources Division, U.S. Fish and Wildlife 

Service – Air Quality Branch, Phase I Report of the Federal Land Managers’ Air Quality Related Values Workgroup 

(FLAG)--Revised, 2010.. 
Anadarko Petroleum Corporation 3-3 Trinity Consultants 

 

AQRV	indicators	typically	identified	by	FLM	include	nitrogen	deposition,	sulfur	deposition,	and	

visibility	degradation.		Based	on	discussion	with	FWS,	Anadarko	performed	AQRV	analyses	for	all	

three	indicators	mentioned	above	for	Breton	NWR	and	St.	Marks	NWR.19		Based	on	guidance	

received	from	FS,	the	AQRV	analysis	for	Bradwell	Bay	Wilderness	was	performed	for	nitrogen	

deposition,	sulfur	deposition,	and	ozone.20		An	AQRV	analysis	for	visibility	at	Bradwell	Bay	

Wilderness	was	not	required.21

The	following	sections	provide	further	details	on	the	AQRVs	that	were	addressed	for	this	project.	

3.1.1. Deposition 

In	the	deposition	analysis,	the	contribution	of	Anadarko’s	proposed	operations	to	the	deposition	of	

chemical	species	in	the	Class	I	area	was	evaluated	against	the	deposition	assessment	threshold	

(DAT)	values	for	sulfate	and	nitrate	set	by	the	FLM.		The	DAT	represents	“the additional amount of N

or S deposition within a Class I area, below which estimated impacts from a proposed new or modified

source are considered insignificant.”		The	threshold	is	not	necessarily	an	adverse	impact	threshold	

and	coastal	ecosystems	have	evolved	under	naturally	higher	sulfur	deposition	rates.		FLM	guidance	

for	assessment	of	deposition	impacts	suggests	that	an	appropriate	sulfur	and	nitrogen	DAT	is	0.005	

kg/ha/yr	and	0.01	kg/ha/yr	respectively,	for	Class	I	areas	in	the	Eastern	United	States.22

The	procedures	specified	in	the	FLAG	Phase	I	Report	(revised	2010)	were	used	to	model	nitrogen	

and	sulfur	deposition.	23,	24		For	sulfur,	both	wet	and	dry	fluxes	of	SO2	and	sulfates	(SO4)	were	

modeled.		The	sum	of	wet	and	dry	deposition	fluxes	for	SO2	and	SO4	represents	the	total	sulfur	

deposition	as	shown	in	Equation	1.	

	 	

									

Equation 1

Direct	SO4	emissions	from	the	proposed	project	are	very	small	(<0.01	lb/hr),	so	all	sulfur	in	the	fuel	

resulting	in	SO2	emissions	alone	have	been	modeled.		However,	SO2	can	chemically	transform	into	

SO4	over	time,	therefore,	wet	and	dry	fluxes	of	both	SO2	and	SO4	were	used	to	estimate	sulfur	

deposition.	

																																																															

19 Based on Personal Communication, Phone conversation between Ms. Jill Webster (FWS) and Mr. Rahul Pendse 

(Trinity) on October 12, 2012; and E-mail from Ms. Jill Webster (FWS) to Mr. Dhesikan Venkatesan (Trinity) sent on 

October 10, 2012. 

20 Based on Personal Communication, Phone conversation between Ms. Melanie Pitrolo (FS) and Mr. Rahul Pendse 

(Trinity) on October 18, 2012. 

21 Based on Personal Communication, Phone conversation between Ms. Melanie Pitrolo (FS) and Mr. Rahul Pendse 

(Trinity) on October 18, 2012, visibility has not been established as an AQRV for Bradwell Bay. 

22 U.S. National Park Service (NPS) - Air Resources Division and U.S. Fish and Wildlife Service - Air Quality Branch, 

Interagency Guidance on Nitrogen and Sulfur Deposition Analyses, accessed on November, 2011 via NPS website -

www.nature.nps.gov/air/Pubs/pdf/flag/nsDATGuidance.pdf. 23 Based on Personal Communication, Phone conversation between Ms. Jill Webster (FWS) and Mr. Rahul Pendse 

(Trinity) on October 12, 2012; and E-mail from Ms. Jill Webster (FWS) to Mr. Dhesikan Venkatesan (Trinity) sent on 

October 10, 2012. 

24 U.S. Forest Service – Air Quality Program, National Park Service – Air Resources Division, U.S. Fish and Wildlife 

Service – Air Quality Branch, Phase I Report of the Federal Land Managers’ Air Quality Related Values Workgroup 

(FLAG)--Revised, 2010. 

 

  2 4 2 4 dry

2 4 2 4 wet

 flux[SO ] flux[(NH ) SO ]

Sulfur Deposition (kg/ha/yr) flux [SO ] flux [(NH ) SO ]



  
Anadarko Petroleum Corporation 3-4 Trinity Consultants 

 

For	nitrogen,	the	dry	flux	for	NOX,	and	wet	and	dry	deposition	fluxes	for	nitrates	(NO3),	nitric	acid	

(HNO3),	and	ammonium	ion	(NH4)	from	ammonium	nitrate	(NH4NO3)	and	ammonium	sulfate	

(NH4)2SO4)	were	modeled.		Therefore,	the	sum	of	dry	flux	for	NOX	and	wet	and	dry	deposition	fluxes	

for	NO3,	HNO3,	and	ammonium	ion	(NH4)	from	ammonium	nitrate	and	ammonium	sulfate	represents	

the	total	nitrogen	deposition,	as	shown	in	Equation	2.	

							

Equation 2

There	will	be	no	HNO3,	(NH4)2SO4,	or	(NH4)NO3	emissions	from	the	proposed	project,	however,	SO2

and	NOX	can	chemically	transform	into	SO4	and	NO3	respectively	over	time,	which	in	turn	can	form	

(NH4)2SO4,	(NH4)NO3,	or	HNO3.		Therefore,	the	dry	flux	of	NOX,	and	wet	and	dry	fluxes	of	(NH4)2SO4,	

(NH4)NO3,	and	HNO3	were	used	to	estimate	nitrogen	deposition.	

In	accordance	with	the	FLAG	Phase	I	report,	gas	phase	deposition	was	modeled	for	SO2,	NOX,	and	

HNO3,	and	particle	phase	deposition	was	modeled	for	SO4	and	NO3.		The	contributions	of	the	

proposed	project	to	the	deposition	of	nitrogen	and	sulfur	species	in	the	Class	I	area	were	estimated	

as	part	of	the	modeling	analysis,	and	were	assessed	against	the	appropriate	DAT.		Although	the	

sulfur	and	nitrogen	DATs	are	specified	based	on	an	annual	averaging	period,	1‐hour	maximum	

emission	rates	for	the	pollutants	were	conservatively	modeled	to	estimate	deposition	impacts.		

Despite	the	conservative	approach	used,	the	DATs	were	not	exceeded	for	either	nitrogen	or	sulfur,	

based	on	results	presented	in	Section	6	of	this	modeling	report.				

3.1.2. Visibility 

Visibility	can	be	affected	by	plume	impairment	(heterogeneous)	or	regional	haze	(homogeneous).		

Plume	impairment	results	when	there	is	a	contrast	or	color	difference	between	the	plume	and	a	

viewed	background	(the	sky	or	a	terrain	feature).		Plume	impairment	is	generally	only	of	concern	

when	the	Class	I	area	is	less	than	50	km	from	the	proposed	source.		Since	the	distance	between	the	

worst‐case	drillship	location	of	proposed	operations	and	the	nearest	Class	I	area	is	greater	than	50	

km,	only	regional	haze	was	considered	in	this	analysis.	

Regional	haze	occurs	at	distances	where	the	plume	has	become	evenly	dispersed	into	the	

atmosphere	such	that	there	is	no	definable	plume.		The	primary	causes	of	regional	haze	are	sulfates	

(SO4)	and	nitrates	(NO3)	(primarily	as	ammonium	salts),	which	are	formed	from	emissions	of	SO2

and	NOX	through	chemical	reactions	in	the	atmosphere.		These	reactions	take	time,	hence	distance.		

Near	the	emissions	source	little	NOX	or	SO2	will	have	formed	nitrate	or	sulfate,	whereas	far	from	a	

source	nearly	all	SO2	will	have	formed	sulfate	and	most	NOX	will	have	formed	nitrate.		Particulate	

emissions	also	contribute	to	regional	haze	but	to	a	lesser	extent	since	sulfates	and	nitrates	are	

hygroscopic	species	that	increasingly	reduce	visibility	with	increased	relative	humidity.	

Regional	haze	is	measured	using	the	light	extinction	coefficient	(bext).		To	determine	a	change	in	

regional	haze,	the	percentage	change	of	the	light	extinction	coefficient	(Δbext)	was	evaluated	as	

shown	in	the	following	Equation	3:	

	 																																																																																				Equation 3

 

 (flux[NOx] flux[NH NO ] flux[HNO ] flux[(NH ) SO ]) 

Nitrogen Deposition (kg/ha/yr) flux[NH NO ] flux[HNO ] flux[(NH ) SO ]

4 3 3 4 2 4 dry

4 3 3 4 2 4 wet

   

  

ext background

ext project

ext b

b

b

,

,  
Anadarko Petroleum Corporation 3-5 Trinity Consultants 

 

The	Δbext	value	attributable	to	a	single	facility	that	is	generally	acceptable	to	the	FLM	is	5%	on	a	

24‐hour	average	basis.		There	are	a	number	of	available	methods	that	can	be	used	to	estimate	the	

percentage	change	of	light	extinction	coefficient	associated	with	an	emissions	source.		The	peak	

24‐hour	average	visibility	impairment	as	predicted	by	the	air	quality	model	is	one	conservative	

measure	used	to	attribute	visibility	affects	to	a	single	source.		However,	as	stated	in	the	preamble	of	

the	U.S.	EPA’s	Regional Haze Regulations and Guidelines for Best Available Retrofit Technology (BART)

Determinations, the	CALPUFF	model	uses	a	simplified	chemistry	that	“...tends to magnify the actual

visibility effects”	of	a	source. 25		Therefore,	the	U.S.	EPA	recommends	the	consideration	of	the	98th

percentile	of	modeled	visibility	values	to	assess	visibility	impacts,	and	states	in	the	preamble,	“...we

believe it is appropriate to use the 98th percentile—a more robust approach that does not give undue

weight to the extreme tail of the distribution.		The use of the 98th percentile of modeled visibility values

would appear to exclude roughly 7 days per year from consideration.		In our judgment, this approach

will effectively capture the sources that contribute to visibility impairment in a Class I area, while

minimizing the likelihood that the highest modeled visibility impacts might be caused by unusual

meteorology or conservative assumptions in the model.”		The	use	of	the	98th	percentile	approach	has	

also	been	formalized	in	the	FLAG	Phase	I	report	(revised	2010).26

According	to	the	December	2000	FLAG	Phase	I	Report,	the	background	extinction	coefficient	bext,	

background	is	affected	by	various	chemical	species	and	the	Rayleigh	scattering	phenomenon	and	can	be	

calculated	using	Equation	5	shown	on	Page	37	of	the	December	2000	FLAG	Phase	I	Report.27		In	the	

revised	FLAG	Phase	I	Report	(revised	2010),	FLAG	has	proposed	a	new	algorithm	for	calculating	the	

background	extinction	coefficient	based	on	the	revised	method	in	the	Interagency	Monitoring	of	

Protected	Visual	Environments	(IMPROVE)	protocol.		IMPROVE	protocols	for	reconstructing	

ambient	light	extinction	from	measured	aerosol	species	are	used	in	evaluating	compliance	under	the	

Regional	Haze	Rule	(RHR)	and	also	are	relied	on	for	conducting	Class	I	area	AQRV	analyses.			The	

algorithm	based	on	the	IMPROVE	protocols	is	recommended	as	the	regulatory	default	background	

extinction	calculation	methodology	by	the	June	2008	FLAG	Phase	I	Report	(revised	2010),	and	

therefore,	Trinity	utilized	the	procedures	specified	in	the	FLAG	Phase	I	Report	(revised	2010)	to	

calculate	the	background	extinction	coefficient,	as	explained	below.	

3.1.3. October 2010 FLAG Phase I Revised Report - Calpost (“Method 8”) 

In	CALPOST	“Method	8”,	bext	is	computed	using	a	monthly average	relative	humidity	adjustment	

particular	to	each	Class	I	area,	applied	to	background	and	modeled	concentrations	of	large	and	small	

sulfates	and	nitrates,	and	sea	salt.		Because	a	monthly	average	is	used,	no	cap	on	f(RH)	is	necessary	

and	the	results	tend	to	be	smoothed,	since	peak	short‐term	humidity	events	are	not	considered.			

Procedures	specified	in	the	FLAG	Phase	I	Report	(revised	2010)	was	used	to	determine	the	

background	extinction	using	“Method	8”.The	background	extinction	coefficient	bext,background	is	

																																																															

25 U.S. EPA, Regional Haze Regulations and Guidelines for Best Available Retrofit Technology (BART) 

Determinations, July 6, 2005. 26 U.S. Forest Service – Air Quality Program, National Park Service – Air Resources Division, U.S. Fish and Wildlife 

Service – Air Quality Branch, Phase I Report of the Federal Land Managers’ Air Quality Related Values Workgroup 

(FLAG)--Revised, 2010. 

27 U.S. Forest Service – Air Quality Program, National Park Service – Air Resources Division, U.S. Fish and Wildlife 

Service – Air Quality Branch, Phase I Report of the Federal Land Managers’ Air Quality Related Values Workgroup 

(FLAG), December 2000. 
Anadarko Petroleum Corporation 3-6 Trinity Consultants 

 

calculated	using	the	IMPROVE	equation	for	calculating	light	extinction,	as	shown	in	Equation	4	

obtained	from	Figure	5	of	the	FLAG	Phase	I	Report	(revised	2010):	28

bext,	background	=	2.2	×	fS(RH)	×	[Small	Sulfate]	+	4.8	×	fL(RH)	×	[Large	Sulfate]		

			+	2.4	×	fS(RH)	×	[Small	Nitrate]	+	5.1	×	fL(RH)	×	[Large	Nitrate]		

			+	2.8	×	[Small	Organic	Mass]	+	6.1	×	[Large	Organic	Mass]		

			+	10	×	[Elemental	Carbon]	+	1	×	[Fine	Soil]	+	0.6	×	[Coarse	Mass]		

			+	1.7	×	fSS(RH)	×	[Sea	Salt]	+	Rayleigh	Scattering	(Site	Specific)	+	0.1755	×	[NO2]		

	 	 	 										Equation 4

where:	

[	]	indicates	concentrations	in	μg/m3		

fS(RH)	=	Relative	humidity	adjustment	factor	for	small	sulfate	and	nitrate		

fL(RH)	=	Relative	humidity	adjustment	factor	for	large	sulfate	and	nitrate		

fSS(RH)	=	Relative	humidity	adjustment	factor	for	sea	salt		

Monthly	average	fL(RH),	fS(RH)	and	fSS(RH)	values	for	Breton	NWR	are	shown	in	Table	3‐3,	as	

obtained	from	Tables	7,	8,	and	9	respectively	of	the	FLAG	Phase	I	Report	(revised	2010).			

								Table 3‐3.		Monthly fS(RH), fL(RH) and fSS(RH) for Breton NWR

Month Average fs (RH) Average fL(RH)

Average fss

(RH)

January	 4.08	 2.91	 4.10	

February	 3.82	 2.76	 3.89	

March	 3.79	 2.74	 3.87	

April	 3.74	 2.72	 3.85	

May	 3.94	 2.83	 4.02	

June	 4.12	 2.94	 4.21	

July	 4.41	 3.10	 4.44	

August	 4.37	 3.07	 4.38	

September	 4.18	 2.97	 4.23	

October	 3.92	 2.82	 3.99	

November	 3.93	 2.83	 4.01	

December	 4.06	 2.90	 4.11	

Monthly	average	fL(RH),	fS(RH)	and	fSS(RH)	values	for	St.	Marks	are	shown	in	Table	3‐4,	as	obtained	

from	Tables	7,	8,	and	9	respectively	of	the	FLAG	Phase	I	Report	(revised	2010).			

						

																																																															

28	U.S.	Forest	Service	–	Air	Quality	Program,	National	Park	Service	–	Air	Resources	Division,	U.S.	Fish	and	

Wildlife	Service	–	Air	Quality	Branch,	Phase	I	Report	of	the	Federal	Land	Managers’	Air	Quality	Related	

Values	Workgroup	(FLAG)‐‐Revised,	2010.
Anadarko Petroleum Corporation 3-7 Trinity Consultants 

 

		Table 3‐4.		Monthly fS(RH), fL(RH) and fSS(RH) for St. Marks NWR

Month Average fs (RH) Average fL(RH)

Average fss

(RH)

January	 4.24	 2.98	 4.18	

February	 3.89	 2.78	 3.89	

March	 3.79	 2.73	 3.82	

April	 3.72	 2.69	 3.76	

May	 3.79	 2.74	 3.85	

June	 4.32	 3.04	 4.30	

July	 4.56	 3.17	 4.49	

August	 4.63	 3.21	 4.54	

September	 4.43	 3.1	 4.39	

October	 4.19	 2.96	 4.19	

November	 4.16	 2.94	 4.15	

December	 4.39	 3.06	 4.30	

Additionally,	 the	most	 recent	 values	 for	 the	 annual	 average	 background	 concentrations	 at	 Breton	

and	 St.	 Marks	 obtained	 from	 Table	 6	 of	 the	 FLAG	 Phase	 I	 Report	(revised	 2010)	 are	 provided	 in	

Table	3‐5.29		These	values	were	used	to	calculate	background	extinction.	

Table 3‐5.		Annual Average Background Values for Breton & St. Marks

Species

Breton

(g/m3)

St. Marks

(g/m3)

	 		

Ammonium	Sulfate	 0.23	 0.23	

Ammonium	Nitrate	 0.10	 0.10	

Organic	Carbon	Mass	 1.78	 1.80	

Elemental	Carbon	 0.02	 0.02	

Soil	 0.48	 0.50	

Coarse	Mass	 3.01	 3.00	

Sea	Salt	 0.19	 0.10	

Rayleigh	Scattering	 11	Mm‐1	 11	Mm‐1

	 		

The	methodology	presented	in	Figure	5	of	the	FLAG	Phase	I	Report	(revised	2010)	was	used	to	

calculate	large	and	small	nitrates,	large	and	small	sulfates,	and	large	and	small	organic	mass.	

The	extinction	coefficient	attributable	to	emissions	increases	from	the	proposed	project	bext,project

was	also	calculated.		The	extinction	resulting	from	the	project	was	calculated	as	shown	in	Equation	

5:	

bext,	project	=		2.2	×	fS(RH)	×	[Small	Sulfate]	+	4.8	×	fL(RH)	×	[Large	Sulfate]		

+	2.4	×	fS(RH)	×	[Small	Nitrate]	+	5.1	×	fL(RH)	×	[Large	Nitrate]		

																																																															

29 U.S. Forest Service – Air Quality Program, National Park Service – Air Resources Division, U.S. Fish and Wildlife 

Service – Air Quality Branch, Phase I Report of the Federal Land Managers’ Air Quality Related Values Workgroup 

(FLAG)--Revised, 2010. 
Anadarko Petroleum Corporation 3-8 Trinity Consultants 

 

+	2.8	×	[Small	Organic	Mass]	+	6.1	×	[Large	Organic	Mass]	+	10	×	[Elemental	

Carbon]	

+	1	×	[Fine	Soil]	+	0.6	×	[Coarse	Mass]	+	0.1755	×	[NO2]		

	 	 																				Equation 5

where:	

[	]	indicates	concentrations	in	μg/m3		

fS(RH)	=	Relative	humidity	adjustment	factor	for	small	sulfate	and	nitrate		

fL(RH)	=	Relative	humidity	adjustment	factor	for	large	sulfate	and	nitrate	

“Method	8”	was	used	to	compute	visibility	impairment	in	terms	of	Δbext	from	modeled	pollutant	

concentrations	using	the	CALPOST	processor.		In	Method	8,	bext	is	computed	using	a	monthly

average	relative	humidity	adjustment	particular	to	each	Class	I	area,	applied	to	background	and	

modeled	concentrations	of	large	and	small	sulfates	and	nitrates,	and	sea	salt.		Because	a	monthly	

average	is	used,	no	cap	on	f(RH)	is	necessary	and	the	results	tend	to	be	smoothed,	since	peak	short‐

term	humidity	events	are	not	considered.			

The	98th	percentile	Δbext	percentage	change	results	using	Method	8	are	presented	in	Section	5	of	the	

report.		If	the	change	in	light	extinction	as	a	result	of	the	proposed	project	is	between	5%and	10%,	a	

case‐by‐case	determination	should	be	requested.	

3.1.4. Ozone 

Ozone	is	a	toxic	air	pollutant	that	is	formed	on	warm,	sunny	days	when	its	precursors	NOx	and	VOC	

react	in	the	presence	of	sunlight.		Because	ozone	is	a	regional	pollutant,	precursor	sources	both	near	

and	far	from	Class	I	areas	can	contribute	to	ozone	formation.		However,	due	to	the	complex	

photochemical	reactions	that	are	involved	in	the	formation	of	ozone,	it	is	difficult	to	quantify	specific	

relationships	between	precursor	emissions	and	ambient	ozone	concentrations	at	a	Class	I	area,	and	

also	to	quantify	the	specific	relationship	between	ambient	ozone	at	a	Class	I	area	and	vegetation	

response.		Therefore,	FLAG	has	chosen	to	focus	on	the	effects	of	ozone	on	vegetation	and	the	levels	

of	ozone	generally	known	to	be	phytotoxic	in	Class	I	areas	as	indicators	of	concern	regarding	ozone	

impacts	on	AQRVs.		Based	on	discussions	with	FS,	Anadarko	has	addressed	the	impacts	of	ozone	

exposure	as	a	result	of	the	proposed	operations	on	vegetation	at	Bradwell	Bay.30

Based	on	review	of	available	dispersion	models	and	discussion	with	FS,	it	has	been	found	that	there	

are	currently	no	dispersion	models	available	that	can	relate	emissions	from	a	single	source	to	

changes	in	ozone	concentrations	at	particular	receptor	locations.		However,	as	discussed	with	FS,	

since	single	source	attribution	modeling	is	possible	for	both	visibility	and	deposition,	Anadarko	is	

demonstrating	compliance	with	the	deposition	thresholds	at	Bradwell	Bay	as	a	method	of	

addressing	impacts	of	ozone	on	the	vegetation	at	Bradwell	Bay.	31,32

Demonstrating	compliance	with	the	deposition	thresholds	shall	provide	an	indication	of	whether	

the	proposed	project	operations	NOX	emissions	are	likely	to	cause	an	adverse	impact	on	soils,	

																																																															

30 Based on Personal Communication, Phone conversation between Ms. Melanie Pitrolo (FS) and Mr. Rahul Pendse 

(Trinity) on October 18, 2012. 

31 Based on Personal Communication, Phone conversation between Ms. Melanie Pitrolo (FS) and Mr. Rahul Pendse 

(Trinity) on October 18, 2012. 

32 Per discussion with Ms. Melanie Pitrolo (FS) and and Mr. Rahul Pendse (Trinity) on October 18, 2012, visibility has 

not been established as an AQRV for Bradwell Bay. 
Anadarko Petroleum Corporation 3-9 Trinity Consultants 

 

and/or	surface	waters.		Since	the	results	of	deposition	modeling	are	below	the	DATs,	it	

demonstrates	that	the	project’s	NOX	emissions	do	not	cause	any	adverse	impacts	on	soils	and/or	

surface	water,	and	since	all	FLM	areas	are	assumed	to	be	NOX‐limited	for	formation	of	ozone,	it	can	

be	deduced	that	there	are	no	ozone	impacts	on	the	vegetation	at	Bradwell	Bay	Wilderness.33		It	

should	also	be	noted	that	the	PSD	Class	I	area	modeling	analysis	demonstrated	that	Class	I	area	SILs	

are	not	exceeded	for	NO2	(as	discussed	in	Section	6),	which	provides	additional	demonstration	that	

no	significant	impact	on	ozone	levels	at	Bradwell	Bay	would	occur.	

																																																															

33 Per Section 3.4.5 of Phase I Report of the Federal Land Managers’ Air Quality Related Values Workgroup (FLAG)--

Revised, 2010. 
Anadarko Petroleum Corporation 4-1 Trinity Consultants 

 

4. CLASS II AIR QUALITY DISPERSION MODELING REQUIREMENT 

4.1. PSD SIGNINFICANT ANALYSIS 

An	air	quality	analysis	was	performed	to	demonstrate	that	emissions	of	these	pollutants	do	not	

cause	or	contribute	to	a	violation	of	a	NAAQS	or	exceed	a	Class	II	area	PSD	Increment.		A	Class	II	PSD	

Air	Dispersion	Modeling	Analysis	consisted	of	two	distinct	phases:	

The	first	phase,	PSD	significance	analysis,	is	a	screening	analysis.		The	significance	analysis	

considers	only	the	emissions	associated	with	the	proposed	project	to	determine	if	the	net	

emissions	changes	will	have	a	significant	impact	upon	the	surrounding	area.		A	“significant”	

impact	occurs	when	the	modeled	ambient	concentration	resulting	from	the	modeled	emission	

rates	equals	to	or	exceeds	applicable	SILs	and	Modeling	Significance	Levels	(MSLs).		If	the	

project	impact	is	less	than	corresponding	SILs	then	no	further	analysis	is	required.			

The	second	phase	is	a	“full	impact”	or	“cumulative”	analysis.		For	pollutants	with	modeled	

concentrations	equal	to	or	greater	than	the	SIL,	PSD	regulations	require	a	NAAQS	analysis	and	a	

PSD	Increment	analysis.		

Table	4‐1	lists	the	SILs,	NAAQS,	and	PSD	Increments	for	all	relevant	PSD‐regulated	pollutants	for	

this	dispersion	modeling	analysis.			

							Table 4‐1.		Applicable PSD Air Quality Levels

Pollutant Averaging

Period

PSD Modeling

SIL		(μg/m3)

Primary and

Secondary

NAAQS

(μg/m3)

Class II Area

PSD

Increment

(μg/m3)

Significant

Monitoring

Concentration

(μg/m3)

CO	 1‐hour	 200	 40,000	(35	ppm)1	 ‐‐	 ‐‐	

8‐hour	 500	 10,000	(9	ppm)1	 ‐‐	 575	

SO2	 3‐hour	 25	 1,300	(0.5	ppm)1	 512	 ‐‐	

24‐hour	 5	 ‐‐	 91	 13	

Annual	 1	 ‐‐	 20	 ‐‐	

1‐hour8	 ‐‐	 196	(0.075	ppm)4	 ‐‐	 ‐‐	

NO2	 Annual	 1	 100	(0.053	ppm)2	 25	 14	

1‐hour7	 ‐‐	 188	(0.100	ppm)4	 ‐‐	 ‐‐	

PM10	 24‐hour	 5	 1503	 30	 10	

Annual	 1	 ‐‐	 17	 ‐‐	

PM2.5	 24‐hour	 1.2	 355	 9	 4	

Annual	 0.3	 126	 4	 ‐‐	

1	Not	to	be	exceeded	more	than	once	per	year.	

2	 Annual	arithmetic	average.	

3	 Not	to	be	exceeded	more	than	once	per	year	on	average	over	3	years.	

4	 3‐year	average	of	the	98th	percentile	of	the	annual	distribution	of	daily	maximum	1‐hour	concentrations.	

5	 98th	percentile	of	concentrations	in	a	given	year,	averaged	over	3	years.	

6	 Annual	arithmetic	mean	from	single	or	multiple	monitors,	averaged	over	3	years.	

7	 PSD	Increments,	Modeling	SILs,	and	Monitoring	De	Minimis	Concentration	level	for	the	1‐hour	NO2

standard	have	not	been	proposed	yet.		However,	interim	modeling	significance	levels	of	4	ppb	was	provided	

by	EPA	in	general	guidance	implementation	memo	dated	June	28,	2010.	
Anadarko Petroleum Corporation 4-2 Trinity Consultants 

 

8	 PSD	Increments,	Modeling	SILs,	and	Monitoring	De	Minimis	Concentration	level	for	the	1‐hour	SO2	standard	

have	not	been	proposed	yet.		However,	interim	modeling	significance	levels	of	3	ppb	was	provided	by	EPA	

in	general	guidance	implementation	memo	dated	August	23,	2010.	

9		The	existing	annual	and	24‐hour	SO2	standards	will	be	revoked	one	year	after	the	effective	date	in	areas	

with	a	designated	status	for	the	revised	SO2	NAAQS,	per	40	CFR	50.4I.	

Each	of	the	applicable	principle	steps	involved	in	a	PSD	Air	Dispersion	Modeling	analysis	are	

discussed	in	detail	below.		The	dispersion	modeling	analysis	was	conducted	in	a	manner	that	

conforms	to	the	applicable	rules	and	requirements	for	dispersion	modeling	issued	by	the	U.S.	

Environmental	Protection	Agency	(EPA).34

4.1.1. Pre- Construction Monitoring Analysis 

In	addition	to	determining	whether	the	applicant	can	forego	further	modeling	analyses,	the	PSD	

Significance	Analysis	is	also	used	to	determine	whether	the	applicant	is	exempt	from	ambient	

monitoring	requirements.		To	determine	whether	pre‐construction	monitoring	should	be	

considered,	the	maximum	impacts	attributable	to	the	emissions	increases	from	a	project	are	

compared	with	the	Significant	Monitoring	Concentrations	(SMCs)	shown	in	Table	4‐1.		If	either	the	

predicted	modeled	impact	from	an	emissions	increase	or	the	existing	ambient	concentration	is	less	

than	the	SMC,	an	applicant	is	exempt	from	pre‐construction	ambient	monitoring.		If	the	predicted	

modeled	impact	is	equal	to	or	greater	than	the	SMC,	an	applicant	may	provide	existing	data	

representative	of	ambient	air	quality	in	the	affected	area	or,	if	such	data	are	not	available,	collect	

background	air	quality	data.35			

Additionally,	although	no	SMCs	have	been	established	for	ozone,	40	CFR	52.21(i)(5)(i)	specifies	that	

for	any	net	emissions	increase	of	100	tons	per	year	or	more	of	VOC	or	NOX	subject	to	PSD,	an	

applicant	would	be	required	to	perform	an	ozone	impact	analysis.		As	the	NOX	emissions	from	the	

proposed	OCS	source	are	greater	than	100	tons	per	year,	the	proposed	project	will	be	subject	to	the	

requirements	of	40	CFR	52.21(i)(5)(i).			

Due	to	the	remote	offshore	location	of	the	proposed	operations,	very	minimal	contribution	in	the	

formation	of	ozone	is	expected	from	the	proposed	operation.		Since	an	adequate	ozone	formation	

model	is	not	available	for	this	type	of	a	single	source	application,	Anadarko	addressed	this	

requirement	in	Section	6	using	qualitative	approach	as	described	in	the	preliminary	statement	of	

basis	for	permit	no.	OCS‐EPA‐R4006	and	OCS‐EPA‐R4012	prepared	by	the	EPA	Region	4.	36	,	37

																																																															

34 40 CFR 51, Appendix W, Revision to Guideline on Air Quality Models, November 9, 2005; and EPA’s New Source 

Review Workshop Manual (DRAFT) (1990). 35 U.S. EPA New Source Review Workshop Manual (Draft, 1990), pages C.18–19. 36 U.S. EPA Region 4, Preliminary Determination & Statement of Basis Outer Continental Shelf Air Permit OCS-EPAR4006, August 19, 2011. 

37 U.S. EPA Region 4, Preliminary Determination & Statement of Basis Outer Continental Shelf Air Permit OCS-EPAR4012, August 9, 2013. 
Anadarko Petroleum Corporation 4-3 Trinity Consultants 

 

4.1.2. Special Considerations for PM2.5

On	January	22,	2013,	the	U.S.	Court	of	Appeals	for	the	District	of	Columbia	Circuit	vacated	the	SMC	

for	PM2.5	and	two	provisions	in	EPA’s	PSD	regulations	containing	SILs	for	PM2.5.

	38		The	Court	

concluded	that	the	PM2.5	SMC	provisions	(40	CFR	51.166(i)(5)(c)	and	40	CFR	52.21(i)(5)(i)(c))	were	

inconsistent	with	the	requirements	of	Section	165(e)(2)	of	the	CAA.		The	Court	granted	the	EPA’s	

request	to	remand	and	vacate	the	SIL	provisions	in	Sections	40	CFR	51.166(k)(2)	and	40	CFR	

52.21(k)(2)	of	the	regulations	so	that	the	EPA	could	correct	an	error	in	these	provisions	that	came	to	

the	EPA’s	attention	after	the	court	challenge	was	filed.			

The	EPA	released	draft	guidance	(EPA	draft	guidance	for	PM2.5	modeling)	for	PM2.5	modeling	which	

reflects	EPA's	preliminary	recommendations	for	how	a	stationary	source	seeking	a	PSD	permit	may	

demonstrate	that	it	will	not	cause	or	contribute	to	a	violation	of	the	NAAQS	and	PSD	increments	for	

PM2.5,	as	required	under	Section	165(a)(3)	of	the	CAA	and	40	CFR	51.166(k)	and	40	CFR	52.21	(k).		

The	draft	Guidance	for	PM2.5	permit	modeling	incorporates	the	modeling	procedures	and	

recommendations	from	the	March	23,	2010,	guidance	memorandum	"Modeling	Procedures	for	

Demonstrating	Compliance	with	PM2.5	NAAQS,"	and	further	clarifies	procedures	for	adequately	

addressing	primary	and	secondary	PM2.5	in	a	NAAQS	compliance	demonstration	under	the	PSD	

program.		Due	to	lack	of	other	final	guidance,	Anadarko	has	modeled	PM2.5	emissions	consistent	with	

the	recommendations	prescribed	in	the	draft	guidance	document.	

Per	EPA	draft	guidance	for	PM2.5	modeling:	

“...The vacated provisions of the regulations inadvertently restricted the discretion of permitting

authorities to conduct or require more than a screening analysis in some circumstances where the EPA

had called for permitting authorities to consider whether additional analysis was needed to make the

demonstration required by Section 165(a)(3) of the CAA.		Due to the court decision, the EPA will not

rely, and advised permitting authorities with State Implementation Plan (SIP) approved PSD programs

not to rely, on the SMCs for PM2.5 to exempt permit applicants from compiling preconstruction

monitoring data for PM2.5 in accordance with Sections 40 CFR 51.166(m) and 40 CFR 52.21(m).		

However, the EPA believes PSD permit applicants may continue to meet the preconstruction

monitoring requirements in these regulations by using data from existing monitors that are

determined by the applicable permitting authority to be representative of background conditions in the

affected area. The court decision does not preclude the use of SILs for PM2.5, but requires that EPA

correct the error in the SIL regulations for PM2.5 at 40 CFR 51.166(k)(2) and 40 CFR 52.21(k)(2).		In the

interim, the EPA believes permitting authorities may continue to apply SILs for PM2.5 to support a PSD

permitting decision, but permitting authorities should take care to ensure that SILs are not used in a

manner that is inconsistent with the requirements of Section 165(a)(3) of the CAA....” 39			

Per	EPA	draft	guidance	for	PM2.5	modeling:		

“...Any permitting authority wishing to use a particular SIL value as a screening tool in a significant

impact analysis should determine whether a substantial portion of the NAAQS has already been

consumed.		Preconstruction monitoring data (or adequately representative onshore monitoring data

from an existing onshore monitoring network) should be evaluated against the respective PM2.5 NAAQS.		

If the difference between the NAAQS and the measured or representative PM2.5 background in the area

																																																															

38 Sierra Club v. EPA, No. 10-1413 (D.C. Circuit), 2013 WL 216018. 

39 http://www.epa.gov/scram001/guidance/guide/Draft_Guidance_for_PM25_Permit_Modeling.pdf.
Anadarko Petroleum Corporation 4-4 Trinity Consultants 

 

is greater than the applicable SIL value, then the EPA believes it would be sufficient in most cases for

permitting authorities to conclude that a source with an impact below that SIL value will not cause a

new NAAQS violation...”			

In	the	submitted	air	dispersion	modeling	protocol,	Anadarko	proposed	to	subtract	background	PM2.5

concentrations	from	the	NAAQS	standards	to	assess	whether	a	substantial	portion	of	NAAQS	has	

already	been	consumed.		If	the	difference	between	the	NAAQS	standard	and	the	background	

concentration	is	greater	than	the	respective	PM2.5	SIL	then	Anadarko	is	proposed	to	compare	

modeled	PM2.5	concentrations	against	the	respective	PM2.5	SILs.		Also,	Anadarko	proposed	to	

address	the	impact	of	the	secondary	PM2.5	formation	qualitatively.			

Air	emission	sources	complying	with	the	federal	PSD	rules	are	required	to	assess	the	influence	of	

not	only	primary	PM2.5,	but	also	impacts	of	potential	formation	of	secondary	PM2.5.		Precursors	

include	NOX,	SOX,	and	VOCs.		These	precursors,	under	specific	atmospheric	conditions	and	in	the	

presence	of	other	chemicals	integral	to	the	photochemical	processes	that	form	secondary	PM2.5,	may	

coagulate	on	existing	particles	or	nucleate	into	new	particles.		Understanding	the	state	of	

atmospheric	conditions	and	chemical	composition	near	a	PSD	source	is	essential	to	assessing	the	

influence	that	the	PSD	source	could	have	on	secondary	PM2.5	formation.	

The	EPA	draft	guidance	for	PM2.5	modeling	allows	for	a	qualitative	assessment	of	secondary	PM2.5

formation	for	PSD	sources.	The	intent	is	for	the	assessment	to	provide	sufficient	qualitative	evidence	

that	the	potential	for	the	formation	of	secondary	PM2.5	would	not	result	in	overall	PM2.5	levels	that	

exceed	the	NAAQS,	and	that	ultimately	a	quantitative	assessment	will	not	be	required	to	evaluate	the	

formation	of	secondary	PM2.5.		As	indicated	in	the	EPA	draft	guidance	for	PM2.5	modeling	document,	

precursors	can	be	addressed	either	by	a	qualitative	assessment	of	the	state	of	atmospheric	

chemistry	for	a	region,	or	by	use	of	photochemical	modeling.		However,	if	a	qualitative	assessment	

provides	ample	evidence	that	precursors	will	not	cause	primary	and	secondary	PM2.5	emissions	to	

exceed	or	approach	the	NAAQS,	then	the	application	of	photochemical	models	may	not	be	required.	

Investigations	of	the	Southeastern	Aerosol	Research	and	Characterization	(SEARCH)	monitoring	

network	have	provided	detailed	information	on	the	trends	and	speciation	of	the	regional	pollutants.

40,41		The	SEARCH	network	encompasses	the	EGOM	and	has	operated	since	mid‐1998	assessing	

numerous	pollutants	relevant	to	the	development	of	secondary	PM2.5.		Recently	published	studies	of	

SEARCH	have	shown	that	secondary	formation	of	PM2.5	is	due	largely	to	reactions	of	SO2	and	NOX

with	NH3	in	the	atmosphere	resulting	in	increased	sulfate	and	nitrate	composition	in	atmosphere.			

Blanchard	et.al,	concluded	that	particulate	sulfate	concentration	decreased	in	tandem	with	decrease	

in	SO2	emissions.			Similar	decreases	in	emissions	have	also	been	observed	within	Clean	Air	Status	

and	Tends	Network	(CASTNet).		The	formation	of	particulate	nitrate	is	a	function	of	NOX,	NH3,	and	

SO4	interactions	as	well	as	atmospheric	conditions	such	as	temperature	and	humidity,	thus	causing	

additional	complexity	in	understanding	the	relationships	associated	with	particulate	formation.		

																																																															

40 Blanchard,C.L., Hidy, G.M., Tanenbaum, S., Edgerton, E.S., & Hartsell, B.E.. (2013a) The Southeastern Aerosol 

Research and Characterization (SEARCH) study: Spatial variations and chemical climatology, 1999-2010. Journal of 

Air & Waste Management Association, 63(3), 260-275. Doi:10.1080/10962247.2012.749816. 

41 Blanchard,C.L., Hidy, G.M., Tanenbaum, S., Edgerton, E.S., & Hartsell, B.E.. (2013a) The Southeastern Aerosol 

Research and Characterization (SEARCH) study: Temporal trends in gas and PM concentrations and compositions, 

1999-2010. Journal of Air & Waste Management Association, 63(3), 247-259. Doi:10.1080/10962247.2012.748523. 
Anadarko Petroleum Corporation 4-5 Trinity Consultants 

 

Blanchard	et.al,	concluded	that	formation	of	nitrate	is	limited	by	the	availability	of	NH3.

	42		Typically	

with	a	reduction	in	SO2	emissions	there	is	potentially	an	increase	in	availability	of	NH3	for	nitrate	

conversion	from	NOX.		However,	as	noted	by	Blanchard	et	al	decrease	in	sulfate	concentration	did	

not	result	in	increase	in	nitrate	concentration	(reciprocal	increase	in	nitrate)	indicating	that	despite	

reduction	in	SO2	emissions,	the	reaction	of	SO2	with	NH3	dominated	in	the	EGOM	region.		This	is	

further	validated	by	the	correlation	of	decreasing	sulfate	particulates	and	ammonium	particulate	

concentrations	within	the	SEARCH	network.		This	concludes	that	the	secondary	PM2.5	in	EGOM	is	

dominated	by	ammonium	sulfate	and	not	ammonium	nitrate.			

Due	to	the	competition	for	available	ammonia	between	NOX	and	SO2,	increase	in	the	NOX	emissions	

in	the	region	is	unlikely	to	bring	about	corresponding	increases	in	PM2.5.		Additionally,	the	

background	concentrations	of	certain	chemical	species	that	participate	in	photochemical	reactions	

to	form	secondary	PM2.5,	including	ammonia,	is	expected	to	be	negligible	in	the	offshore	air	masses	

where	the	project	is	proposed.			

There	are	several	other	conservative	assumptions	incorporated	in	the	modeling	of	primary	PM2.5	

including	modeling	two	point	sources	at	the	worst‐case	location	closest	to	nearest	receptor,	

modeling	performed	at	max	lb/hr	emissions	and	the	temporary	nature	of	the	source	activity	

(drillship)	at	worst‐case	modeled	location.		Therefore,	the	addition	of	a	new	source	of	NOX	from	the	

proposed	project	operations	would	likely	have	little	impact	on	the	formation	of	secondary	nitrate.		

Hence,	Anadarko	concludes	that	the	project	emissions	will	have	very	little	to	no	impact	on	

secondary	PM2.5	formation.		Based	on	these	factors,	and	consistent	with	EPA	draft	guidance	for	PM2.5	

modeling,	Anadarko	believes	that	an	adequate	assessment	has	been	made	to	demonstrate	that	the	

PM2.5	NAAQS	will	be	protected,	accounting	for	primary	PM2.5	impacts	and	potential	contributions	

due	to	PM2.5	precursors	from	the	proposed	project,	and	that	it	is	not	necessary	to	use	a	

photochemical	model	to	further	evaluate	secondary	PM2.5	formation	in	this	application.	

Anadarko	reviewed	the	available	PM2.5	air	quality	monitoring	data	for	the	EGOM.		Although	there	are	

no	existing	PM2.5	measurements	in	the	vicinity	of	projects	worst‐case	lease	blocks,	there	are	a	

number	of	shore‐based	monitors.		Because	of	the	scarcity	of	PM2.5	sources	in	the	EGOM	and	the	

project’s	large	distance	from	land‐based	sources,	the	background	ambient	PM2.5	concentration	in	the	

EGOM	OCS	are	expected	to	be	lower	than	any	onshore	concentrations.		Therefore,	the	existing	

onshore	ambient	monitoring	data	should	provide	conservative	background	ambient	PM2.5	

concentrations	for	the	project	location.			

EPA	Region	4	had	recently	concluded	in	the	preliminary	statement	of	basis	for	permit	no.	OCS‐EPA‐

R4012 	that	the	maximum	PM2.5	24‐hour	and	annual	concentration	from	the	18	existing	EGOM	

shore‐based	monitors	for	the	2009‐2011	period	were	28	and	10.4	ug/m3,	respectively.	43		The	PM2.5

24‐hour	NAAQS	is	35	ug/m3	and	the	PSD	Class	II	SIL	is	1.2	ug/m3.		The	annual	NAAQS	is	12	ug/m3

and	the	Class	II	SIL	is	0.3	ug/m3.		The	difference	between	the	PM2.5	NAAQS	and	the	conservative	

ambient	background	concentrations	as	presented	in	preliminary	statement	of	basis	for	permit	no.	

OCS‐EPA‐R4012 	are	greater	than	the	respective	PM2.5	Class	II	SILs.			Hence,	Anadarko	believes	that	

the	proposed	project	will	qualify	for	use	of	comparison	of	modeled	PM2.5	concentrations	against	the	

respective	PM2.5	SILs	for	a	Class	II	area.	

																																																															

42 Blanchard,C.L., Tanenbaum, S., Hidy, G.M. (2007). Effect of Sulfur Dioxide and Oxide of Nitrogen Emission 

Reductions on Fine Particulate Matter Mass Concentrations: Regional Comparisons. Journal of Air & Waste 

Management Association, 57(11), 1337-1350. Doi:10.3155/1047-3289.57.11.1337. 

43 U.S. EPA Region 4, Preliminary Determination & Statement of Basis Outer Continental Shelf Air Permit OCS-EPAR4012, August 9, 2013. 
Anadarko Petroleum Corporation 4-6 Trinity Consultants 

 

4.2. ADDITIONAL IMPACTS ANALYSIS 

An	additional	impacts	analysis	was	performed	in	accordance	with	PSD	requirements	in	40	CFR	§	

52.21(o).		The	PSD	application	prepared	for	the	proposed	project	comprises	of		three	additional	

impact	analyses:	1)	an	analysis	of	the	air	quality	impact	projected	for	the	area	as	a	result	of	any	

commercial,	residential,	and	industrial	growth	associated	with	the	proposed	facility,	2)	an	analysis	

of	the	impairment	to	soils,	vegetation,	and	animals	that	may	occur	as	a	result	of	the	proposed	

facility,	and	3)	an	analysis	of	impairment	to	visibility	(haze	at	distant	Class	I	areas	and	plume	

impairment	at	sensitive	Class	II	receptors)	that	may	occur	as	a	result	of	the	proposed	facility.		

4.2.1. Growth analysis 

The	purpose	of	the	growth	analysis	is	to	quantify	project‐associated	growth;	that	is,	to	predict	how	

much	new	growth	is	likely	to	occur	in	order	to	support	the	source	under	review,	and	then	to	

estimate	the	air	quality	impacts	from	this	growth	either	quantitatively	or	qualitatively.		Typically,	

the	amount	of	residential	growth	depends	on	the	size	of	the	available	work	force,	the	number	of	new	

employees,	and	the	availability	of	housing	in	the	area.		Associated	commercial	and	industrial	growth	

consists	of	new	sources	providing	goods	and	services	to	the	new	employees	and	to	the	new	

industrial	source	itself.		The	potential	growth	of	industrial,	commercial,	and	residential	sources	as	a	

result	of	the	proposed	Desoto	Canyon	exploration	activities	is	expected	to	be	minimal.		As	discussed	

in	Section	6	because	of	the	seasonal	and	temporary	nature	of	the	proposed	OCS	source,	Anadarko	

anticipates	that	any	industrial,	commercial	and	residential	growth	will	be	insignificant.		

4.2.2. Soils and vegetation analysis 

The	EPA,	through	the	CAA,	has	promulgated	primary	and	secondary	ambient	air	quality	standards.		

The	primary	air	quality	standards	are	set	at	levels	necessary	to	provide	an	adequate	margin	of	safety	

to	protect	human	health.		The	secondary	standards	are	set	at	levels	to	provide	for	protection	of	

public	welfare,	where	welfare	is	defined	to	include	the	following:		soils,	water,	vegetation,	manmade	

materials,	animals,	wildlife,	weather,	visibility,	climate,	and	damage	to	or	deterioration	of	

property.44	Table	4‐1	shows	the	secondary	NAAQS	for	each	relevant	regulated	air	pollutant	for	this	

modeling	analysis.			

To	satisfy	this	requirement,	Trinity	assessed	the	modeling	results	against	the	secondary	NAAQS,	for	

determination	of	impacts	to	soil	and	vegetation.		If	ambient	air	concentrations	are	found	to	be	less	

than	the	secondary	NAAQS,	it	can	be	presumed	that	emissions	from	the	proposed	sources	will	not	

result	in	harmful	effects	to	either	soil	or	vegetation.45		Moreover,	due	to	the	location	of	the	proposed	

project	activities	being	more	than	100	km	from	the	nearest	shoreline	if	ambient	air	concentrations	

are	found	to	be	less	than	the	SILs,	it	can	be	presumed	that	emissions	from	the	proposed	sources	will	

not	result	in	harmful	effects	to	either	soil	or	vegetation.	

4.2.3. Visibility analysis 

As	per	the	U.S.	EPA	New	Source	Review	Workshop	Manual,	visibility	impairment	analysis	should	be	

performed	for	impacts	that	occur	within	the	area	affected	by	proposed	project.46		The	EPA’s	

																																																															

44 Sections 109 and 302 of the Clean Air Act. 

45 U.S. EPA, Office of Air Quality Planning and Standards, New Source Review Workshop Manual, Research Triangle 

Park, NC, October 1990. 

46 U.S. EPA, New Source Review Workshop Manual (Draft): Prevention of Significant Deterioration and 

Nonattainment Area Permitting, October 1990. 
Anadarko Petroleum Corporation 4-7 Trinity Consultants 

 

Workbook	for	Plume	Visual	Impact	Screening	and	Analysis	(Workbook)	provides	guidance	for	

conducting	a	visibility	impairments	analysis	through	the	use	of	VISCREEN,	a	plume	visibility	impact	

model.47		The	methods	in	this	workbook	are	designed	for	Class	I	area	impacts;	however,	the	

procedures	are	generally	applicable	to	other	areas	as	well.		The	VISCREEN	model	is	recommended	

for	the	first	level	(Level	1)	screening	analysis.			If	predicted	values	from	the	VISCREEN	model	are	less	

than	the	standardized	screening	values,	no	further	analysis	is	required.			

Although	VISCREEN	is	primarily	designed	for	assessing	plume	visual	impacts	in	Class	I	areas,	as	

noted	in	the	Workbook	for	Plume	Visual	Impact	Screening	and	Analysis,	it	can	also	be	applied	in	PSD	

Class	II	areas.		Default	values	have	been	used	for	background	ozone	(0.04	ppm),	stability	class	(6),	

and	wind	speed	(1	m/s).		Per	the	Workbook,	distances	from	the	emission	source	for	the	Class	II	area	

evaluations	can	be	specified	“arbitrarily.”		The	application	of	VISCREEN	is	limited	to	distances	less	

than	or	equal	to	50	km.		Therefore	to	conservatively	estimate	the	potential	visual	impact	in	the	

impact	area	that	is	more	than	50	km	from	the	proposed	project	location,	the	50	km	distance	has	

been	used	in	the	VISCREEN	analysis	as	discussed	in	Section	6.

																																																															

47 U.S. EPA Office of Air Quality Planning and Standards. Workbook for Plume Visual Impact Screening and Analysis. 

Research Triangle Park, NC. EPA-450/4-88-015. 
Anadarko Petroleum Corporation 5-1 Trinity Consultants 

 

5. CLASS I AND II AREA MODELING METHODOLOGY 

This	section	of	the	modeling	report	describes	the	modeling	procedures	and	data	resources	that	were	

utilized	in	the	both	Class	I	and	Class	II	area	air	quality	modeling	analysis.	

5.1. MODEL SELECTION 

The	preferred	model	for	analyzing	long‐range	pollutant	transport	(i.e.,	distances	greater	than	

50	km)	is	the	CALPUFF	modeling	system.		The	EPA‐approved	version	(Version	5.8)	of	the	CALPUFF	

model	was	used	to	determine	the	possible	impacts	of	the	project	on	Class	I	area	PSD	Increment,	

AQRV	at	Breton,	St.	Marks,	and	Bradwell	Bay	and	Significance	analysis	for	Class	II	areas.	

CALPUFF	is	a	multi‐layer,	multi‐species,	non‐steady‐state	Lagrangian	puff	model,	which	can	

simulate	the	effects	of	time‐	and	space‐varying	meteorological	conditions	on	pollutant	transport,	

transformation,	and	removal.		For	this	refined	analysis,	meteorological	fields	generated	by	CALMET	

were	used	as	inputs	to	the	CALPUFF	model	to	ensure	that	the	effects	of	terrain	and	spatially	varying	

surface	characteristics	on	meteorology	were	considered.		In	addition	to	meteorological	data,	the	

CALPUFF	model	uses	several	other	input	files	to	specify	source	and	receptor	parameters.		The	

selection	and	control	of	CALPUFF	options	are	determined	by	user‐specific	inputs	contained	in	the	

control	file.			

The	following	sections	describe	the	modeling	domain,	meteorological	data,	background	

concentrations,	and	model	implementation	that	were	used	for	the	air	quality	impact	analysis	of	the	

proposed	operations.	

5.2. MODELING DOMAINS 

The	Class	I	and	Class	II	modeling	analysis	was	performed	in	the	Lambert	Conformal	Conic	(LCC)	

coordinate	system	based	on	the	design	of	the	VISTAS	Regional	Haze	Rule	(RHR)	modeling,	with	

standard	parallels	of	33o	N	and	45o	N	latitude,	and	reference	latitude	and	longitude	of	40o	N	and	97o	

W	respectively.48		VISTAS	RHR	Model	Domain	2	was	utilized	as	the	CALMET	meteorological	

domain.49		The	different	VISTAS	RHR	Model	Domains	are	shown	in	Figure	5‐1.	50

																																																															

48 VISTAS, Protocol for the Application of the CALPUFF Model for Analyses of Best Available Retrofit Technology 

(BART), December 22, 2005, revised August 31, 2006. 49 Based on Personal Communication, Phone conversation between Ms. Jill Webster (FWS) and Mr. Rahul Pendse 

(Trinity) on October 12, 2012; and E-mail from Ms. Jill Webster (FWS) to Mr. Dhesikan Venkatesan (Trinity) sent on 

October 10, 2012. 

50 Obtained from the Atmospheric Studies Group (ASG) at TRC website - 

http://www.src.com/datasets/VISTAS_Files/VISTAS_Domains.pdf
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Figure 5‐1.		VISTAS RHR Model Domains		

Three	separate	CALPUFF	computational	domains	were	chosen	for	the	two	worst‐case	locations	

listed	in	Table	2‐1.		The	first	computational	domain	(CD1)	encompassed	the	receptors	on	Breton	

NWR,	the	associated	worst‐case	location	of	the	drillship	and	supply	boat,	while	the	second	

computational	domain	(CD2)	encompassed	the	receptors	on	St.	Marks	NWR	and	Bradwell	Bay	

Wilderness,	the	associated	worst‐case	location	of	the	drillship	and	supply	boat,	and	the	third.		

computational	domain	(CD3)	encompassed	the	receptors	on	Class	II	areas	(inner/Outer	OCS	

boundary),	the	associated	worst‐case	location	of	the	drillship	and	supply	boat.		All	three	

computational	domains	were	chosen	as	subsets	of	the	CALMET	meteorological	domain,	and	

provided	sufficient	area	beyond	all	receptors	(i.e.,	50	km)	to	allow	for	the	possible	recirculation	of	

puffs.		The	horizontal	domain	is	comprised	of	grid	cells,	each	containing	a	central	grid	point	at	which	

meteorological	and	computational	parameters	are	calculated	at	each	time	step.		The	grid	resolution	

for	all	three	CD1,	CD2	and	CD3	was	taken	as	4	km.		Given	this	interval,	CD1	extended	over	an	area	of	

256	km	x	224	km,	and	consisted	of	64	by	56	grid	cells,	while	CD2	extended	over	an	area	of	388	km	x	

288	km,	and	consisted	of	97	by	72	grid	cells	and	CD3	extended	over	an	area	of	800	km	x	408	km,	and	

consisted	of	200	by	102	grid	cells.		Calculations	supporting	the	setup	of	the	computational	domain	

are	provided	in	Appendix	D	for	reference.		

Vertical	grid	structure	is	defined	by	the	cell	face	height.		The	cell	face	height	of	each	cell	indicates	its	

vertical	extent.		The	vertical	domain	is	composed	of	terrain‐following	grid	cells,	the	number	and	size	
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of	which	are	chosen	so	as	to	constrain	the	boundary	layer	in	which	dispersion	and	chemical	

transformations	take	place.		Based	on	information	available	in	the	VISTAS	RHR	Modeling	Protocol,	

and	the	IWAQM	guidance	document,	the	vertical	grid	structure	selected	for	this	analysis	is	

presented	below	in	Table	5‐1.51		The	same	cell	face	heights	were	used	for	both	CALMET	and	

CALPUFF.			

Table 5‐1.		Vertical Grid Structure

 

Vertical Grid Cell 

Cell Face Height 

(meters) 

 

1 20 

2 40 

3 80 

4 160 

5 320 

6 640 

7 1,200 

8 2,000 

9 3,000 

10 4,000 

5.3. RECEPTOR LOCATIONS 

The	set	of	receptors	used	for	Class	I	and	Class	II	analysis	are	presented	below.	

5.3.1. Receptors locations for Class I areas52

The	National	Park	Service	(NPS)	Air	Resources	Division	(ARD)	has	developed	a	database	of	

modeling	receptors	for	all	of	the	Class	I	areas	in	the	United	States.53		The	database	provides	the	

location	(lat/long,	decimal	degrees)	coordinates	and	elevation	information	for	receptors	for	each	

Class	I	area.		Receptor	locations	obtained	from	the	database	for	Breton	NWR,	St.	Marks	NWR,	and	

Bradwell	Bay	Wilderness	were	converted	to	the	LCC	coordinate	system	using	appropriate	

conversion	factors	and	used	in	the	Class	I	area	analyses.		Receptor	locations	as	utilized	in	the	model	

are	presented	in	Appendix	D	for	reference.	

																																																															

51 VISTAS, Protocol for the Application of the CALPUFF Model for Analyses of Best Available Retrofit Technology 

(BART), December 22, 2005, revised August 31, 2006, and the U.S. EPA, IWAQM Phase 2 Summary Report and 

Recommendations for Modeling Long-Range Transport Impacts, Research Triangle Park, North Carolina, EPA-454/R95-006, December 1998. 

52 Anadarko5-year permit Modeling Protocol - v5 after EPA Comments 53 http://www.nature.nps.gov/air/maps/receptors/index.cfm
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5.3.2. Receptors locations for Class II areas54

The	seaward	boundaries	and	Air	Quality	Control	Regions	for	Louisiana,	Mississippi	and	Alabama	

extend	for	three	nautical	miles	offshore	and	for	nine	nautical	miles	offshore	Florida.	55		For	the	Class	

II	modeling	analysis,	discrete	receptors	were	located	25	nautical	miles	from	the	seaward	boundaries	

of	Louisiana,	Mississippi,	Alabama	and	Florida.		The	receptors	were	placed	at	1‐km	intervals	as	per	

Guidance	received	from	EPA	Region	4.		The	actual	sets	of	receptors	used	in	Class	II	analysis	were	

provided	by	EPA	Region	4.56		The	location	of	these	receptors	is	shown	in	Appendix	B	above	as	

continuous	dots	(Note:	receptors	may	appear	as	a	solid	line	in	Appendix	B	due	to	low	resolution).		

Because	all	of	these	receptors	are	over	water,	terrain	elevations	were	assigned	an	elevation	of	0	m	

(i.e.,	sea	level)	for	Class	II	impact	analysis.			

5.4. TERRAIN PROCESSING FOR CLASS II ANALYSIS 

As	the	proposed	OCS	source	is	located	in	the	GOM	and	corresponding	Class	II	receptors	will	be	

placed	25	miles	away	from	respective	state	seaward	boundary,	the	entire	modeling	domain	will	be	

located	completely	over	water	in	the	Gulf	of	Mexico.		Therefore,	all	modeled	sources	and	Class	II	

receptors	are	assumed	to	be	situated	at	sea	level	and	the	elevations	for	off‐property	sources	and	

receptors	will	be	set	to	zero	for	the	Class	II	modeling	analysis.			

5.5. BUILDING DOWNWASH 

Building	downwash	accounts	for	the	effects	of	nearby	structures	on	the	flow	of	emissions	from	their	

respective	release	structures.		However,	building	downwash	effects	were	not	included	in	the	

modeling	as	they	will	not	significantly	affect	concentrations	when	the	nearest	receptors	are	located	

more	than	50	km	from	the	worst‐case	drillship	location.		Hence,	due	to	the	relatively	large	distance	

of	the	proposed	drillship	from	the	Class	I	and	Class	II	area,	building	downwash	will	not	be	enabled.57		

5.6. CALMET METEOROLOGICAL PROCESSING 

CALMET	is	the	meteorological	preprocessor	that	compiles	meteorological	data	from	raw	

observations	of	surface	and	upper	air	conditions,	precipitation	measurements,	mesoscale	model	

output,	and	geophysical	parameters	into	a	single	hourly,	gridded	data	set	for	input	to	CALPUFF.		

Based	on	guidance	from	the	FLM	and	EPA	Region	4,	three	years	of	mesoscale	meteorological	(MM)	

data	in	the	form	of	CALPUFF‐ready	meteorological	files	for	the	period	2001‐2003	(for	VISTAS	

Domain	2)	were	obtained	from	the	Florida	Department	of	Environmental	Protection	(DEP)	and	used	

in	this	analysis.58		No	additional	meteorological	data	processing	was	performed	for	this	analysis.	

																																																															

54 Anadarko5-year permit Modeling Protocol - v5 after EPA Comments

55 U. S. Commission on Ocean Policy. Primer on Ocean Jurisdictions: Drawing Lines in the Water. Final Report. 56 Based on Personal Communication, E-mail from Mr. Stan Krivo (EPA Region 4) and Mr. Rahul Pendse (Trinity) on 

October 1, 2012. 

57 Per guidance provided on Pg. 45 of the VISTAS, Protocol for the Application of the CALPUFF Model for Analyses of 

Best Available Retrofit Technology (BART), December 22, 2005, revised August 31, 2006. 58 Based on Personal Communication; Phone conversation between Ms. Jill Webster (FWS) and Mr. Rahul Pendse 

(Trinity) on October 12, 2012; Phone conversation between Mr. Stanley Krivo (EPA Region IV) and Mr. Rahul Pendse 

(Trinity) on October 10, 2012; and E-mail from Ms. Jill Webster (FWS) to Mr. Dhesikan Venkatesan (Trinity) sent on 

October 10, 2012. The meteorological data was obtained from Mr. Tom Rogers, Florida DEP, based on instructions 

from EPA Region 4. 
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5.7. CALPUFF MODEL PROCESSING 

Using	the	data	provided	by	CALMET,	CALPUFF	simulates	the	dispersion,	deposition,	and	chemical	

transformation	of	discrete	puffs	of	mass	from	emission	sources.		Each	puff	contains	emissions	of	CO,	

NOX,	SO2,	and	PM10	and	is	advanced	throughout	the	domain	while	deposition	and	chemical	

transformation	processes	take	place.		CALPUFF	is	a	Lagrangian	puff	model,	the	principal	advantages	

of	which	are	that	pollutant	plumes	can	evolve	dynamically	and	chemically	over	time	and	can	

respond	to	complex	winds	caused	by	terrain	effects,	stagnation,	or	recirculation.			

The	emissions	data	input	into	CALPUFF	for	sources	modeled	was	discussed	in	Section	2	of	this	

report.		Because	of	the	large	distance	from	the	source	to	the	Class	I	and	Class	II	areas,	building	

downwash	was	not	enabled.59				

The	analysis	was	performed	with	the	deposition	and	chemical	transformation	algorithms	enabled	

for	Class	I	AQRV	analysis	and	disabled	for	the	PSD	Class	I	and	Class	II	analysis	as	requested	by	EPA	

Region	4.		Default	values	obtained	from	the	CALPUFF	model	library	species	was	used	in	the	

modeling	to	perform	deposition	analysis.		A	full	resistance	model	is	provided	in	CALPUFF	for	the	

computation	of	dry	deposition	rates	of	gases	and	particulate	matter	as	a	function	of	geophysical	

parameters,	meteorological	conditions,	and	pollutant	species.		An	empirical	scavenging	coefficient	

approach	using	default	options	was	enabled	in	CALPUFF	to	compute	the	depletion	and	wet	

deposition	fluxes	resulting	from	precipitation	scavenging.	

The	CALPUFF	model	is	capable	of	simulating	linear	chemical	transformation	effects	by	using	

pseudo‐first‐order	chemical	reaction	mechanisms	for	the	conversions	of	SO2	to	SO4,	and	NOX,	which	

consists	of	nitric	oxide	(NO)	and	nitrogen	dioxide	(NO2),	to	NO3	and	HNO3.		In	this	analysis,	chemical	

transformations	involving	five	species	(SO2,	SO4,	NOX,	HNO3,	and	NO3)	were	modeled	using	the	

MESOPUFF	II	chemical	transformation	scheme,	in	accordance	with	IWAQM	guidance.	60		In	addition,	

two	user‐selected	input	parameters	are	available	that	affect	the	MESOPUFF	II	chemical	

transformation:	ammonia	concentrations	and	ozone	concentrations.		The	selection	of	each	

parameter	is	discussed	separately.	

5.7.1. Ozone 

Ambient	ozone	concentrations	can	be	input	to	the	model	as	a	background	level	or	using	hourly,	

spatially	varying	observations.		For	this	modeling	analysis,	data	from	the	ozone	monitor	in	Sumatra,	

Florida	(code	‐	SUM	156)	was	used	due	to	its	proximity	to	the	modeling	domain,	as	well	as	due	to	the	

availability	of	complete	data	from	this	station.		Information	on	the	monitoring	station	was	obtained	

from	the	CASTNET	website.61		

																																																															

59 VISTAS, Protocol for the Application of the CALPUFF Model for Analyses of Best Available Retrofit Technology 

(BART), December 22, 2005, revised August 31, 2006. 60 U.S. EPA, IWAQM Phase 2 Summary Report and Recommendations for Modeling Long-Range Transport Impacts, 

Research Triangle Park, North Carolina, EPA-454/R-95-006, December 1998. 

61 Information on the site monitor is available at www.epa.gov/castnet/sites/sum156.html. Information on ozone 

data available at EPA’s CASNET website – www.epa.gov/castnet/data.html. 
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5.7.2. Ammonia 

IWAQM	guidance	document	recommends	the	use	of	spatially	constant	background	ammonia	

concentrations	to	participate	in	the	MESOPUFF	II	chemical	transformation	mechanism.62		In	the	

absence	of	an	extensive	monitoring	network	for	ammonia	and	because	of	the	limitation	of	CALPUFF	

to	simulate	only	a	single,	domain‐average	background	ammonia	level	for	each	month	of	analysis,	a	

single	value	was	used.		The	IWAQM	guidance	recommends	the	ammonia	value	be	set	between	0.5	

parts	per	billion	(ppb)	for	forested	areas	and	10	ppb	for	grasslands.		Based	on	guidance	received	

from	the	FLM	for	Breton	NWR,	the	ammonia	background	level	for	the	analysis	was	set	at	3	ppb.63		

The	same	background	ammonia	concentration	was	utilized	for	Class	I	and	Class	II	PSD	significance	

analysis.	

5.8. CALPOST POSTPROCESSING ANALYSIS 

The	CALPOST	postprocessor	(Version	6.221)	was	used	to	compute	the	ambient	concentrations	of	

PM10,	PM2.5,	and	NO2	at	Class	I	and	Class	II	areas	for	assessment	against	the	PSD	Class	I	area	

Increment	modeling	SILs	and	Class	II	SILs,	the	total	deposition	of	sulfur	and	nitrogen	within	each	

Class	I	area	for	assessment	against	the	DAT,	and	the	98th	percentile	of	the	24‐hour	average	change	in	

light	extinction	using	Method	8.	

For	PM10	assessment	against	the	PSD	Class	I	and	Class	II	area	SILs,	POSTUTIL	was	first	used	to	

combine	the	speciated	PM	(PMC,	PMF,	and	SOA)	to	calculate	total	PM10	concentration.		The	PM10

concentration	was	then	processed	using	CALPOST	and	compared	to	the	appropriate	Class	I	area	and	

Class	II	area	SILs.	

For	estimating	the	extent	of	nitrogen	and	sulfur	deposition,	POSTUTIL	was	first	used	to	combine	the	

appropriate	wet	and	dry	fluxes	of	nitrogen‐	and	sulfur‐bearing	species	deposited	as	particles	and	

gases.		These	combined	fluxes	were	then	processed	using	CALPOST	to	obtain	the	nitrogen	and	sulfur	

deposition	values.	

To	determine	the	change	in	light	extinction	from	the	proposed	project,	the	Ammonia	Limiting	

Method	(ALM)	was	first	used	to	repartition	the	nitrate	mass	and	recompute	HNO3	and	NO3

concentrations.		This	methodology	estimates	the	amount	of	ammonia	available	for	the	formation	of	

ammonium	nitrates	after	the	preferential	consumption	of	ammonia	from	the	formation	of	

ammonium	sulfates.		The	ALM	was	applied	based	on	guidance	provided	in	the	VISTAS BART

Modeling Protocol.

64		Visibility	change	was	then	computed	using	“Method	8”,	and	results	are	

reported	for	the	98th	percentile	of	24‐hour	average	impacts	for	“Method	8”,	for	each	of	the	three	

years	of	meteorological	data	modeled.	

																																																															

62 U.S. EPA, IWAQM Phase 2 Summary Report and Recommendations for Modeling Long-Range Transport Impacts, 

Research Triangle Park, North Carolina, EPA-454/R-95-006, December 1998. 

63 Based on Personal Communication; Phone conversation between Ms. Jill Webster (FWS) and Mr. Rahul Pendse 

(Trinity) on October 12, 2012; and E-mail from Ms. Jill Webster (FWS) to Mr. Dhesikan Venkatesan (Trinity) sent on 

October 10, 2012. 

64 VISTAS; Protocol for the Application of the CALPUFF Model for Analyses of Best Available Retrofit 

Technologies (BART). December 22, 2005. 

http://www.vistas-sesarm.org/documents/BARTModelingProtocol_rev3.2_31Aug06.pdf 
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6. SUMMARY OF DISPERSION MODELING RESULTS 

This	section	summarizes	the	results	of	the	Class	I	and	Class	II	area	dispersion	modeling	analysis,	and	

demonstrates	that	the	proposed	project	does	not	cause	or	contribute	to	an	exceedance	of	the	Class	I	

area	PSD	Increments,	and	does	not	adversely	affect	any	AQRV	at	any	Class	I	area.				

6.1. CLASS I AREA PSD INCREMENT RESULTS 

Impacts	were	predicted	at	the	receptors	at	Breton	NWR,	St.	Marks	NWR,	and	Bradwell	Bay	

Wilderness,	and	were	compared	to	the	Class	I	area	modeling	SILs.		Maximum	hourly	emission	rates	

were	conservatively	modeled	for	comparison	with	both	the	24‐hour	and	annual	averaging	period	

SILs,	and	no	puff	depletion	due	to	wet	or	dry	deposition	was	accounted	for.		Additionally,	all	NOX

emissions	were	conservatively	modeled	to	represent	NO2	emissions.		A	comparison	of	the	pollutant	

concentrations	with	the	Class	I	area	SILs	for	all	averaging	periods	is	presented	in	Table	6‐1.		As	

shown	in	Table	6‐1,	predicted	concentrations	of	NOX	and	PM10	do	not	exceed	the	SILs.		Therefore,	no	

further	modeling	with	regard	to	the	Class	I	area	PSD	Increments	was	conducted.			

Given	the	conservative	emission	rates	and	release	location	(i.e.,	nearest	possible	distance	to	Class	I	

ambient	receptor),	and	small	number	of	other	possible	increment	consuming	PM2.5	emission	sources	

in	the	EGOM,	the	use	of	the	PM2.5	SIL	should	not	jeopardize	PSD	Class	I	increment	at	this	area.		The	

fact	that	the	maximum	modeled	project	emissions	are	lower	than	the	SIL	(i.e.,	maximum	project	

impacts	are	91%	of	the	24‐hour	and	4%	of	the	annual	PM2.5	SIL)	further	supports	the	use	of	the	

PM2.5	SIL	as	an	indicator	of	insignificant	project	impacts	in	this	application.	

Table 6‐1.		Air Dispersion Modeling Results	‐	Class I Area SILs		

Class I Area Parameter Class I Area

Modeling

Significance

Level (μg/m3)

Year

2001

(μg/m3)

2002

(μg/m3)

2003

(μg/m3)

Breton	NWR	

NO2	‐	Annual	 0.1	 0.0162 0.0279 0.0268

PM2.5	‐	24	hour	 0.07	 0.0639 0.0361 0.0606

PM2.5	‐	Annual	 0.06	 0.0022 0.0035 0.0042

PM10	‐	24	hour	 0.32	 0.0738 0.0417 0.0700

PM10	‐	Annual	 0.16	 0.0025 0.0041 0.0049

St.	Marks	NWR	

and	Bradwell	Bay	

Wilderness	*	

NO2	‐	Annual	 0.1	 0.0027 0.0014 0.0025

PM2.5	‐	24	hour	 0.07	 0.0139 0.0205 0.0146

PM2.5	‐	Annual	 0.06	 0.0007 0.0005 0.0007

PM10	‐	24	hour	 0.32	 0.0160 0.0236 0.0168

PM10	‐	Annual	 0.16	 0.0008 0.0006 0.0008

*	St.	Marks	NWR	and	Bradwell	Bay	Wilderness	were	modeled	together	by	including	all	receptors	from	both	of	these	

Class	I	areas.		Therefore,	the	concentration	values	presented	here	represent	the	worst‐case	pollutant	concentrations	

for	both	Class	I	areas	considered	together.		Individual	worst‐case	concentrations	for	the	two	Class	I	areas	are	equal	to	

or	lower	than	this	estimate.	
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6.2. DEPOSITION 

Potential	nitrogen	and	sulfur	deposition	impacts	at	Breton	NWR,	St.	Marks	NWR,	and	Bradwell	Bay	

Wilderness	were	calculated	using	the	methodology	described	in	Section	3.2.1,	and	compared	to	the	

DATs.		Although	the	sulfur	and	nitrogen	DATs	are	specified	based	on	an	annual	averaging	period,	

maximum	hourly	emission	rates	for	the	pollutants	were	conservatively	modeled	to	estimate	

deposition	impacts.			

The	maximum	deposition	for	both	nitrogen	and	sulfur	is	shown	in	Table	6‐2.		Predicted	values	did	

not	exceed	the	respective	Nitrogen	and	Sulfur	DAT	values.		Therefore,	no	adverse	impact	on	these	

Class	I	areas	is	expected	from	sulfur	or	nitrogen	deposition.	

Table 6‐2.		Nitrogen and Sulfur Deposition		

Class I Area Parameter

Class I DAT Values

(Kg/ha/yr)

Year

2001

(Kg/ha/yr)

2002

(Kg/ha/yr)

2003

(Kg/ha/yr)

Breton	NWR	 Nitrogen	 0.01	 0.0033 0.0065 7.16E‐03	

Sulfur	 0.005	 0.0001 0.0001 1.73E‐05	

St.	Marks	NWR	

and	Bradwell	

Bay	Wilderness	*	

Nitrogen	 0.01	 2.04E‐03 2.82E‐03 2.67E‐03	

Sulfur	 0.005	 1.49E‐05 2.09E‐05 2.78E‐06	

*	St.	Marks	NWR	and	Bradwell	Bay	Wilderness	were	modeled	together	by	including	all	receptors	from	both	of	these	

Class	I	areas.		Therefore,	the	deposition	values	presented	here	represent	the	worst‐case	deposition	for	both	Class	I	

areas	considered	together.		Individual	worst‐case	deposition	for	the	two	Class	I	areas	are	equal	to	or	lower	than	this	

estimate.	

6.3. VISIBILITY 

As	discussed	in	Section	3.2.2,	visibility	impacts,	in	terms	of	regional	haze,	were	determined	for	

Breton	NWR	and	St.	Marks	NWR	using	“Method	8”.		Table6‐3	shows	the	98th	percentile	24‐hour	

average	visibility	impact	for	years	2001	through	2003	based	on	CALPOST	“Method	8”	for	the	

proposed	project.	
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Table 6‐3.		Method 8	‐	98th Percentile Extinction Change For Drilling Operations

Class I Area Parameter

Year

2001 2002 2003

Breton	NWR	 Method	8	

98th	Percentile	24‐hr	

Average	

Extinction	Change	%	

5.18% 3.55% 4.42%

No.	of	Days	>	5	%	

Extinction	Change	98th	

Percentile	Threshold	

2 0 0

No.	of	Days	>	10	%	

Extinction	Change	98th	

Percentile	Threshold	

0 0 0

St.	Marks	

NWR	 Method	8	

98th	Percentile	24‐hr	

Average	

Extinction	Change	%	

1.23% 0.87% 1.18%

No.	of	Days	>	5	%	

Extinction	Change	98th	

Percentile	Threshold	

0 0 0

No.	of	Days	>	10	%	

Extinction	Change	98th	

Percentile	Threshold	

0 0 0

As	summarized	in	Table	6‐3,	the	98th	percentile	extinction	change	%	using	Method	8	is	less	than	5%	

for	both	2002	and	2003	modeled	years.		However,	the	estimated	impacts	of	the	proposed	project’s	

emissions	on	the	Breton	for	the	2001	modeled	year	shows	visibility	greater	than	the	FLM	

established	threshold	of	5%.		Anadarko	believes	due	to	the	conservative	assumptions	contained	in	

the	emission	estimates	and	modeling	analyses	as	listed	below,	no	significant	project‐related	impacts	

is	expected.		

Two	point	source	modeled	at	the	worst‐case	location	closest	to	the	nearest	receptor;	

Modeled	performed	at	maximum	lb/hr	emission	whereas	the	visibility	is	a	24‐hour	standard;	

and	

Temporary	nature	of	the	source	activity	(drillship)	at	the	worst‐case	modeled	location.	

Therefore,	based	on	 this	methodology,	 the	proposed	project	will	neither	‘cause’	nor	‘contribute’	 to	

visibility	impairment	in	the	Breton	NWR	and	St.	Marks	NWR	Class	I	areas.	
Anadarko Petroleum Corporation 6-4 Trinity Consultants 

6.4. CLASS II AREA PSD SIL RESULTS 

Impacts	were	predicted	at	the	Inner/Outer	OCS	boundary	(Class	II	areas),	and	were	compared	to	the	

Class	II	area	modeling	SILs.		Maximum	hourly	emission	rates	were	conservatively	modeled	for	

comparison	with	the	1‐hour,	24‐hour	and	annual	averaging	period	SILs,	and	no	puff	depletion	due	to	

wet	or	dry	deposition	was	accounted	for.		Additionally,	all	NOX	emissions	were	conservatively	

modeled	to	represent	NO2	emissions.		A	comparison	of	the	pollutant	concentrations	with	the	Class	II	

area	SILs	for	all	averaging	periods	is	presented	in	Table	6‐4.		Predicted	concentrations	of	NOX,	PM10,	

PM2.5	and	CO	do	not	exceed	the	SILs.		Hence	no	further	analysis	is	required.			

Due	to	the	same	reasons	as	described	previously	in	case	of	Class	I	PM2.5	SILs,	Anadarko	proposes	to	

utilize	Class	II	PM2.5	SILs	as	a	valid	mechanism	to	assess	whether	a	full	impact	assessment	is	

necessary.		Given	the	conservative	emission	rates	and	receptor	location	(i.e.,	placement	of	Class	II	

receptors	at	the	Inner/Outer	OCS	Boundary),	and	small	number	of	other	possible	increment	

consuming	PM2.5	emission	sources	in	the	EGOM,	the	use	of	the	PM2.5	SIL	should	not	jeopardize	PSD	

increment	consumption	at	this	area.			

Table 6‐4.		Air Dispersion Modeling Results	‐	Class II Area SILs

Class II Area Parameter

Class II Modeling

Significance Level

(μg/m3)

Years

2001

(μg/m3)

2002

(μg/m3)

2003

(μg/m3)

Receptors	25	

miles	from	

nearest	

shoreline	

NO2	‐	

Annual	 1	 0.08	 0.09	 0.09	

NO2	‐	1	hour	 7.5	 5.01	 5.04	 4.94	

PM2.5	‐	24	

hour	 1.2	 0.12	 0.09	 0.11	

PM2.5	‐	

Annual	 0.3	 0.006	 0.007	 0.009	

PM10	‐	24	

hour	 5	 0.14	 0.10	 0.13	

CO	‐	1	hour	 2,000	 10.56	 13.66	 11.81	

CO	‐	8	hour*	 500	 ‐‐	 ‐‐	 ‐‐	

*	The	CO	8‐hour	SIL	level	for	Class	II	is	500	μg/m3.	Based	on	the	result	of	this	analysis,	modeled	impacts	of	CO	1‐hour	

values	are	well	below	the	CO	8‐hour	Class	II	SIL	levels.	Hence	Anadarko	can	expect	to	comply	with	CO	8‐hour	SILs	via	

compliance	with	the	CO	1‐hour	SIL	values	

The	fact	that	the	maximum	impacts	from	project	emissions	are	substantially	less	than	the	SILs	(i.e.,	

Table	6‐4	Class	II	maximum	project	impacts	are	10%	of	the	24‐hour	and	3%	of	the	annual	PM2.5	SIL)	

provides	further	support	for	the	use	of	the	SILs	in	this	application.		Hence,	it	is	reasonable	to	

conclude	that	a	proposed	source	with	a	predicted	PM2.5	impact	below	the	PM2.5	SIL	values	will	not	

cause	or	contribute	to	a	violation	of	the	PM2.5	NAAQS.		Moreover,	as	shown	in	the	Table	6‐4,	all	

predicted	impacts	are	less	than	their	respective	SILs.		Similarly,	since	the	predicted	concentrations	

are	less	than	the	SMCs,	no	preconstruction	monitoring	is	required.	

6.4.1. Ozone Impact Analysis 

Ozone	is	an	air	pollutant	formed	through	complex	chemical	reactions	of	NOX	and	VOC	emissions,	

during	periods	of	conducive	weather	conditions.		Ozone	is	more	readily	formed	when	it	is	sunny	and	

hot	and	the	air	is	stagnant.		Conversely,	ozone	production	is	more	limited	when	it	is	cloudy,	cool,	
Anadarko Petroleum Corporation 6-5 Trinity Consultants 

rainy,	and	windy.		For	these	reasons,	ozone	concentrations	are	generally	the	highest	during	the	

summer.		The	majority	of	tropospheric	ozone	formation	occurs	when	NOX,	CO	and	VOCs	react	in	the	

atmosphere	in	the	presence	of	sunlight.		NOX	and	VOCs	are	ozone	precursors.		The	chemical	

reactions	involved	in	tropospheric	ozone	formation	are	a	series	of	complex	cycles	in	which	CO	and	

VOCs	are	oxidized	to	water	vapor	and	CO2.		Oxidation	begins	with	the	reaction	of	CO	with	the	

hydroxyl	radical.		The	hydrogen	atom	formed	by	this	reacts	rapidly	with	oxygen	to	give	a	peroxy	

radical	HO2.		Peroxy	radicals	then	go	on	to	react	with	NO	to	give	NO2,	which	is	photolysed	to	give	

atomic	oxygen	and	through	reaction	with	oxygen	a	molecule	of	ozone.		This	cycle	involving	HOX	and	

NOX	is	terminated	by	the	reaction	of	OH	with	NO2	to	form	nitric	acid	or	by	the	reaction	of	peroxy	

radicals	with	each	other	to	form	peroxides.		The	chemistry	involving	VOCs	is	much	more	complex	

but	the	same	reaction	of	peroxy	radicals	oxidizing	NO	to	NO2	is	the	critical	step	leading	to	ozone	

formation.	

Ozone	is	a	toxic	air	pollutant	that	have	NOx	and	VOC	as	its	precursors.		Since	the	project’s	estimated	

NOX	emissions	exceed	the	100	tpy,	it	requires	assessment	of	the	project’s	ozone	impacts.		The	

estimated	project	emissions	are	provided	in	Appendix	G.		An	adequate	ozone	formation	model	has	

not	been	developed	for	this	type	of	sole	source	application.		Hence,	a	qualitative	or	relative	

assessment	was	be	performed	as	presented	below.		This	assessment	is	similar	to	the	analysis	

conducted	by	the	EPA	Region	4	in	the	preliminary	statement	of	basis	for	permit	no.	OCS‐EPA‐R4006	

and	OCS‐EPA‐R4012	prepared.	65,	66	.		

According	to	the	information	presented	in	the	Oil	and	Gas	Exploration	section	on	the	NOAA	

Ocean	Explorer	website,	there	are	3,858	oil	rigs	or	platforms	in	the	Western	and	Central	

Planning	Areas	of	the	Gulf	of	Mexico	(GOM).	67			Further	analysis	based	on	the	2008	Emissions	

Inventory	from	the	Bureau	of	Safety	and	Environmental	Enforcement	(BSEE)	showed	that	some	of	

these	rigs	or	platforms	are	either	inactive,	weren’t	included	in	the	emissions	inventory	report,	or	

have	been	decommissioned.		This	inventory	indicates	there	are	3,027	point	sources	that	emit	either	

VOC	or	NOX	located	in	the	Gulf	of	Mexico	west	of	87	degree	30	minute	longitude.	

To	put	the	project’s	NOX	and	VOC	emissions	in	perspective,	Anadarko	compared	the	proposed	

project	emissions	to	Gulf	of	Mexico	NOX	and	VOC	emissions	reported	in	the	2008	Gulfwide	Emission	

Inventory	Study	Report	(latest	inventory	report	of	the	Bureau	of	Energy	Management,	Regulation	

and	Enforcement).	68		Comparing	the	proposed	project	emissions	with	these	estimates	reveal	project	

emissions	are	less	than	0.15%	of	total	NOX	and	0.1%	of	total	VOC	Gulf	of	Mexico	emissions.		

Table 6‐5.		2008 Emissions of NOx and VOCs from Point Sources in the Gulf of Mexico

Pollutant Source Emissions (TPY)

NOx	 1.388	Existing	Emission	Points	 74,286	

VOC	 3026	Existing	Emission	Points	 60,824	

For	further	comparison,	Table	6‐6	presents	the	statewide	total	NOX	emissions	from	the	2008	

National	Emissions	Inventory	(NEI)	for	the	states	around	the	Gulf	of	Mexico	as	summarized	from	

																																																															

65 U.S. EPA Region 4, Preliminary Determination & Statement of Basis Outer Continental Shelf Air Permit OCS-EPAR4006, August 19, 2011.

66 U.S. EPA Region 4, Preliminary Determination & Statement of Basis Outer Continental Shelf Air Permit OCS-EPAR4012, August 9, 2013.

67 http://oceanexplorer.noaa.gov/explorations/06mexico/background/oil/oil.html 

68 http://www.bsee.gov/Environmental-Stewardship/Environmental-Studies/Gulf-of-Mexico-Region/AirQuality/2008-Gulfwide-Emission-Inventory.aspx 
Anadarko Petroleum Corporation 6-6 Trinity Consultants 

information	provided	in	the	Technical	Support	Document	for	the	EPA	Federal	Transportation	Rule	

(EPA‐HQ‐OAR‐2009‐0491).	69		This	document	also	showed	that	on‐road	sources	contributed	the	

most	to	the	total	NOX	emissions	in	the	Gulf	States	which	was	approximately	36%.		Estimated	project	

emissions	are	insignificant	when	compared	with	the	total	NOX	emissions	of	nearly	4.0	million	tons	

from	the	five	Gulf	States.		

Table 6‐6.		State‐	Level Total NOx Emissions for Gulf States in the 2008 NEI

State NOx Emissions (TPY)

Alabama	 421,467	

Florida	 895,436	

Louisiana	 548,439	

Mississippi	 278,745	

Texas	 1,827,200	

Total 3,971,287

Additionally,	the	nearest	coastline	is	more	than	100	km	from	the	worst‐case	drillship	location.		

Emissions	of	NOX	and	VOCs	from	the	project	need	to	travel	more	than	100	km	to	reach	the	coastline	

to	potentially	contribute	to	on‐shore	ozone	concentrations.		In	addition,	the	wind	speeds	direction	in	

the	eastern	Gulf	of	Mexico	changes	frequently,	so	there	is	a	dispersion	over	wide	area	of	project	

emissions.		Based	on	the	aforementioned	information	and	analysis,	Anadarko’s	project	emissions	

are	not	expected	to	significantly	impact	ozone	formation	along	and	near	the	coastal	areas	of	the	Gulf	

of	Mexico.	

6.5. ADDITIONAL IMPACT ANALYSIS 

An	additional	impacts	analysis	was	performed	in	accordance	with	PSD	requirements	in	40	CFR	§	

52.21(o).		The	analysis	evaluates	the	potential	impacts	that	the	emissions	from	the	proposed	

exploration	activities	could	have	on	growth,	soils,	vegetation,	and	visibility	in	the	OCS	impact	area	of	

concern.		

6.5.1. Growth analysis 

The	potential	growth	of	industrial,	commercial,	and	residential	sources	as	a	result	of	the	proposed	

project	activities	is	expected	to	be	minimal.		The	current	infrastructure	that	supports	the	well‐

developed	oil	and	gas	activities	in	the	area	just	west	of	the	proposed	drilling	activities	is	adequate	to	

support	the	proposed	drilling	activities	and	no	additional	growth	is	expected.		Considering	the	

temporary	nature	of	the	proposed	OCS	source	and	Anadarko’s	deep	understanding	of	the	robust	and	

well	developed	oil	and	gas	industry	that	currently	supports	exploration	activities,	Anadarko	

anticipates	that	any	industrial,	commercial	and	residential	growth	will	be	insignificant	

6.5.2. Soils and vegetation analysis 

The	EPA,	through	the	CAA,	has	promulgated	primary	and	secondary	ambient	air	quality	standards.		

The	primary	air	quality	standards	are	set	at	levels	necessary	to	provide	an	adequate	margin	of	safety	

to	protect	human	health.		The	secondary	standards	are	set	at	levels	to	provide	for	protection	of	

public	welfare,	where	welfare	is	defined	to	include	the	following:		soils,	water,	vegetation,	manmade	

																																																															

69 http://www.epa.gov/ttnchie1/net/2008inventory.html 
Anadarko Petroleum Corporation 6-7 Trinity Consultants 

materials,	animals,	wildlife,	weather,	visibility,	climate,	and	damage	to	or	deterioration	of	

property.70			

To	satisfy	this	requirement,	Anadarko	assessed	the	modeling	results	against	the	secondary	NAAQS,	

for	determination	of	impacts	to	soil	and	vegetation.		Since	the	ambient	air	concentrations	are	found	

to	be	less	than	the	secondary	NAAQS,	it	can	be	concluded	that	emissions	from	the	proposed	sources	

will	not	result	in	harmful	effects	to	either	soil	or	vegetation.

71		Alternatively,	due	to	the	location	of	

the	proposed	exploration	activities	being	more	than	100	km	from	the	nearest	shoreline	if	ambient	

air	concentrations	are	found	to	be	less	than	the	SILs,	it	will	be	presumed	that	emissions	from	the	

proposed	sources	will	not	result	in	harmful	effects	to	either	soil	or	vegetation.	

6.5.3. Visibility Analysis 

The	estimate	of	project	impact	on	visibility	in	the	project’s	impact	area	was	assessed	using	the	EPA	

plume	impact	screening	model	VISCREEN.	The	VISCREEN	model	estimates	the	potential	visual	

impact	of	a	plume	caused	by	a	proposed	project’s	emissions.	A	VISCREEN	Level	I	analysis	was	

conducted	to	estimate	if	the	emissions	from	the	proposed	exploration	activities	could	result	in	an	

adverse	impact	on	visibility	at	the	closest	visibility	sensitive	Class	II	area	receptor.		VISCREEN	

conservatively	evaluated	whether	a	plume	will	produce	a	plume	perceptible	to	an	observer	under	

worst‐case	meteorological	conditions	at	a	specific	location.		Several	angles	between	the	observer’s	

line	of	sight	and	the	sun’s	radiation	(θ)	were	considered.		

The	application	of	VISCREEN	is	limited	to	distances	less	than	or	equal	to	50	km.		Therefore	to	

conservatively	estimate	the	potential	visual	impact	in	the	impact	area	that	is	more	than	90	km	from	

the	drilling	location,	the	50	km	distance	was	used	in	the	VISCREEN	analysis.		The	project’s	

particulate	matter	and	NOX	emissions	were	provided	as	inputs	as	shown	below	in	Table	6‐7.		The	

default	values	were	used	for	background	ozone,	stability	class,	and	wind	speed	(default	background	

ozone	concentration	of	0.04	parts	per	million,	and	default	stability	and	wind	speed	are	6	and	1	

meter	per	second,	respectively)	as	shown	below	in	Table	6‐8.		The	closest	Class	II	area	receptor	to	

the	lease	block	in	the	Gulf	of	Mexico	was	located	on	the	edge	of	the	Alabama	Delta,	more	than	50	km	

away.			

Table 6‐7 Level I VISCREEN Analysis Input Emission Rates

Pollutant		 Emissions (lb/hr)

Particulate	Matter	 30	

NOx	(as	NO2)	 624	

Primary	NO2	 0	

Soot	 0	

Primary	SO4	 0	

																																																															

70	Sections	109	and	302	of	the	Clean	Air	Act.				 71	U.S.	EPA,	Office	of	Air	Quality	Planning	and	Standards,	New Source Review Workshop Manual,	Research	

Triangle	Park,	NC,	October	1990.	
Anadarko Petroleum Corporation 6-8 Trinity Consultants 

Table 6‐8 Level I VISCREEN Analysis Input Parameters

Input Parameters

Background	Ozone	(ppm)	 0.04	

Background	Visual	Range	(km)	 25	

Distance:	Source	to	Closest	Class	I	area	(km)	 50	

Distance:	Source	to	Farthest	Class	I	area	(km)	 50	

Source	Observer	Distance	(km)	 50	

Plume‐	Source‐	Observer	Angle	 11.25		

Stability	 6	

Wind	Speed	(m/s)	 1.0	

The	VISCREEN	model	is	designed	to	determine	whether	the	plume	from	an	emission	source	has	the	

potential	to	be	traceable	to	an	untrained	observer	under	reasonable	worst	case	conditions.		Two	

screening	criteria	are	used	to	carry	out	the	analysis	and	if	either	criterion	is	exceeded,	more	

comprehensive	analyses	were	carried	out.			

The	first	criterion,	delta	E,	known	as	the	plume	perceptibility	parameter	is	based	on	the	difference	in	

color	and	brightness	between	the	plume	and	the	background.		It	is	also	known	as	the	color	

difference	parameter	and	depends	on	three	factors,	namely,	brightness	(L),	color	hue	(a)	and	color	

saturation	(b).		The	default	threshold	for	delta	E	is	2.0	

The	second	criterion	is	called	the	green	contrast	value	(Cplume	or	Cp).		Cp	is	defined	as	the	contrast	of	

a	plume	against	a	viewing	background	such	as	the	sky	or	a	terrain	feature.		Change	is	measured	in	

terms	of	green	color	(wavelength=0.55	microns).		The	default	threshold	for	Cp	is	0.05.	

Table 6‐9 Level I VISCREEN Analysis Results

Background Θ	 Distance

(Source‐

Observer)

Delta E Contrast

Critical Plume Critical Plume

Sky		 10		 50		 2.00	 1.870	 0.05	 ‐0.007	

Sky		 140		 50		 2.00	 0.599	 0.05	 ‐0.011	

Terrain		 10		 50		 2.00	 0.175	 0.05	 0.003	

Terrain		 140		 50		 2.00	 0.055	 0.05	 0.002	

Table	6‐9	provides	the	results	of	the	VISCREEN	modeling	for	the	proposed	project.		As	shown	in	this	

table,	the	default	threshold	for	Delta	E	and	contrast	(Cp)	were	not	exceeded	for	sky	or	terrain	

backgrounds	at	50	km	distance.		Therefore,	the	proposed	project	activities	are	not	expected	to	

impair	the	local	visibility	at	the	closest	areas	of	concern,	25	nautical	miles	from	each	state’s	seaward	

boundary	or	areas	further	away	than	that.
Anadarko Petroleum Corporation Trinity Consultants 

APPENDIX A: AREA MAP AND WORST-CASE DRILLSHIP LOCATION 

RELATIVE TO CLASS I AREAS 

	 	
281 km

167 km

285 km

A A

!

!

Mobile

Tallahassee

Closest Receptor: Bradwell Bay Wilderness

Closest Receptor: St. Marks NWR

Closest Receptor: Breton NWR

141 149 De Soto

Canyon

Lloyd

Ridge

A A

542541

585

630629

714

940939938937

894893892891 898 899 900

936935934

758

855854

322321320319

364363 366365

413412411410409408407

451 457456455

853

498

978 980979 985984983

015014013

060 063 064

104 106 107 108

150 151 152

456

149

195194

232 238 239 240

319318 326

363362 367 371370

408407 412411410 414

499

768

847

591590589588587586

330

499

545544543

635634633632631

679678677676

723722721

286

846

769 770 771 772 773

592

636 637 638 639

680 681 682 683 684

815 816 817

724 725 726 727 728 729

287 288 289

243 244 245

331 332 333

547 548

761

849

586

145 146 143

190189188187 191

231230

281

325324

369368367

890

982

012011

055

366

539

806805

943

018 020

057056 059058

102101

146145144

187

231230

323 324

452451450

495

542 545

628627

671 672

718717

274 276275

232 233

318

406

454453452

497496

671670

716715

760759

804

852851 856

895 897

942

190189

234233

278

362

713

801

273

273

757

229

317

361

889

933

977

317

405

493

625

669

361

141 149

GOM Lease Block Map

! Cities

A Worst Case Drillship Locations

Closest Receptor: Bradwell Bay Wilderness

Closest Receptor: Breton NWR

Closest Receptor: St. Marks NWR

Selected Lease Blocks

APC Active Leases

Current Leases

Wedge

Protraction Areas

Date: 10/30/2012

Projection: GCS NAD 83

0 25 50 75 100

Kilometers
Anadarko Petroleum Corporation Trinity Consultants 

APPENDIX B: WORST-CASE DRILLSHIP AND SUPPLY BOAT LOCATIONS 

RELATIVE TO CLASS II AREA 

Anadarko Petroleum Corporation Trinity Consultants 

APPENDIX C: LIST OF ALL LEASE BLOCKS WITHIN THE WEDGE 
AREABLK AREABLK2

DC103 DC0103

DC104 DC0104

DC105 DC0105

DC141 DC0141

DC142 DC0142

DC143 DC0143

DC144 DC0144

DC145 DC0145

DC146 DC0146

DC147 DC0147

DC148 DC0148

DC149 DC0149

DC185 DC0185

DC186 DC0186

DC187 DC0187

DC188 DC0188

DC189 DC0189

DC190 DC0190

DC191 DC0191

DC192 DC0192

DC193 DC0193

DC229 DC0229

DC230 DC0230

DC231 DC0231

DC232 DC0232

DC233 DC0233

DC234 DC0234

DC235 DC0235

DC236 DC0236

DC237 DC0237

DC273 DC0273

DC274 DC0274

DC275 DC0275

DC276 DC0276

DC277 DC0277

DC278 DC0278

DC279 DC0279

DC280 DC0280

DC281 DC0281

DC317 DC0317

DC318 DC0318

DC319 DC0319

DC320 DC0320

DC321 DC0321

DC322 DC0322

DC323 DC0323
AREABLK AREABLK2

DC324 DC0324

DC325 DC0325

DC326 DC0326

DC361 DC0361

DC362 DC0362

DC363 DC0363

DC364 DC0364

DC365 DC0365

DC366 DC0366

DC367 DC0367

DC368 DC0368

DC369 DC0369

DC370 DC0370

DC405 DC0405

DC406 DC0406

DC407 DC0407

DC408 DC0408

DC409 DC0409

DC410 DC0410

DC411 DC0411

DC412 DC0412

DC413 DC0413

DC414 DC0414

DC449 DC0449

DC450 DC0450

DC451 DC0451

DC452 DC0452

DC453 DC0453

DC454 DC0454

DC455 DC0455

DC456 DC0456

DC457 DC0457

DC458 DC0458

DC459 DC0459

DC460 DC0460

DC493 DC0493

DC494 DC0494

DC495 DC0495

DC496 DC0496

DC497 DC0497

DC498 DC0498

DC499 DC0499

DC500 DC0500

DC501 DC0501

DC502 DC0502

DC503 DC0503
AREABLK AREABLK2

DC504 DC0504

DC505 DC0505

DC537 DC0537

DC538 DC0538

DC539 DC0539

DC540 DC0540

DC541 DC0541

DC542 DC0542

DC543 DC0543

DC544 DC0544

DC545 DC0545

DC546 DC0546

DC547 DC0547

DC548 DC0548

DC549 DC0549

DC550 DC0550

DC581 DC0581

DC582 DC0582

DC583 DC0583

DC584 DC0584

DC585 DC0585

DC586 DC0586

DC587 DC0587

DC588 DC0588

DC589 DC0589

DC590 DC0590

DC591 DC0591

DC592 DC0592

DC593 DC0593

DC594 DC0594

DC595 DC0595

DC625 DC0625

DC626 DC0626

DC627 DC0627

DC628 DC0628

DC629 DC0629

DC630 DC0630

DC631 DC0631

DC632 DC0632

DC633 DC0633

DC634 DC0634

DC635 DC0635

DC636 DC0636

DC637 DC0637

DC638 DC0638

DC639 DC0639
AREABLK AREABLK2

DC640 DC0640

DC669 DC0669

DC670 DC0670

DC671 DC0671

DC672 DC0672

DC673 DC0673

DC674 DC0674

DC675 DC0675

DC676 DC0676

DC677 DC0677

DC678 DC0678

DC679 DC0679

DC680 DC0680

DC681 DC0681

DC682 DC0682

DC683 DC0683

DC684 DC0684

DC685 DC0685

DC713 DC0713

DC714 DC0714

DC715 DC0715

DC716 DC0716

DC717 DC0717

DC718 DC0718

DC719 DC0719

DC720 DC0720

DC721 DC0721

DC722 DC0722

DC723 DC0723

DC724 DC0724

DC725 DC0725

DC726 DC0726

DC727 DC0727

DC728 DC0728

DC729 DC0729

DC757 DC0757

DC758 DC0758

DC759 DC0759

DC760 DC0760

DC761 DC0761

DC762 DC0762

DC763 DC0763

DC764 DC0764

DC765 DC0765

DC766 DC0766

DC767 DC0767
AREABLK AREABLK2

DC768 DC0768

DC769 DC0769

DC770 DC0770

DC771 DC0771

DC772 DC0772

DC773 DC0773

DC801 DC0801

DC802 DC0802

DC803 DC0803

DC804 DC0804

DC805 DC0805

DC806 DC0806

DC807 DC0807

DC808 DC0808

DC809 DC0809

DC810 DC0810

DC811 DC0811

DC812 DC0812

DC813 DC0813

DC814 DC0814

DC815 DC0815

DC816 DC0816

DC817 DC0817

DC818 DC0818

DC845 DC0845

DC846 DC0846

DC847 DC0847

DC848 DC0848

DC849 DC0849

DC850 DC0850

DC851 DC0851

DC852 DC0852

DC853 DC0853

DC854 DC0854

DC855 DC0855

DC856 DC0856

DC857 DC0857

DC858 DC0858

DC859 DC0859

DC860 DC0860

DC861 DC0861

DC862 DC0862

DC889 DC0889

DC890 DC0890

DC891 DC0891

DC892 DC0892
AREABLK AREABLK2

DC893 DC0893

DC894 DC0894

DC895 DC0895

DC896 DC0896

DC897 DC0897

DC898 DC0898

DC899 DC0899

DC900 DC0900

DC901 DC0901

DC902 DC0902

DC903 DC0903

DC904 DC0904

DC905 DC0905

DC906 DC0906

DC933 DC0933

DC934 DC0934

DC935 DC0935

DC936 DC0936

DC937 DC0937

DC938 DC0938

DC939 DC0939

DC940 DC0940

DC941 DC0941

DC942 DC0942

DC943 DC0943

DC944 DC0944

DC945 DC0945

DC946 DC0946

DC947 DC0947

DC948 DC0948

DC949 DC0949

DC950 DC0950

DC977 DC0977

DC978 DC0978

DC979 DC0979

DC980 DC0980

DC981 DC0981

DC982 DC0982

DC983 DC0983

DC984 DC0984

DC985 DC0985

DC986 DC0986

DC987 DC0987

DC988 DC0988

DC989 DC0989

DC990 DC0990
AREABLK AREABLK2

DC991 DC0991

DC992 DC0992

DC993 DC0993

DC994 DC0994

FP009 FP0009

FP010 FP0010

FP011 FP0011

FP012 FP0012

FP013 FP0013

FP014 FP0014

FP015 FP0015

FP016 FP0016

FP017 FP0017

FP018 FP0018

FP019 FP0019

FP020 FP0020

FP021 FP0021

FP022 FP0022

FP023 FP0023

FP024 FP0024

FP025 FP0025

FP026 FP0026

FP053 FP0053

FP054 FP0054

FP055 FP0055

FP056 FP0056

FP057 FP0057

FP058 FP0058

FP059 FP0059

FP060 FP0060

FP061 FP0061

FP062 FP0062

FP063 FP0063

FP064 FP0064

FP065 FP0065

FP066 FP0066

FP067 FP0067

FP068 FP0068

FP069 FP0069

FP070 FP0070

FP097 FP0097

FP098 FP0098

FP099 FP0099

FP100 FP0100

FP101 FP0101

FP102 FP0102
AREABLK AREABLK2

FP103 FP0103

FP104 FP0104

FP105 FP0105

FP106 FP0106

FP107 FP0107

FP108 FP0108

FP109 FP0109

FP110 FP0110

FP111 FP0111

FP112 FP0112

FP113 FP0113

FP114 FP0114

FP141 FP0141

FP142 FP0142

FP143 FP0143

FP144 FP0144

FP145 FP0145

FP146 FP0146

FP147 FP0147

FP148 FP0148

FP149 FP0149

FP150 FP0150

FP151 FP0151

FP152 FP0152

FP153 FP0153

FP154 FP0154

FP155 FP0155

FP156 FP0156

FP157 FP0157

FP158 FP0158

FP185 FP0185

FP186 FP0186

FP187 FP0187

FP188 FP0188

FP189 FP0189

FP190 FP0190

FP191 FP0191

FP192 FP0192

FP193 FP0193

FP194 FP0194

FP195 FP0195

FP196 FP0196

FP197 FP0197

FP198 FP0198

FP199 FP0199

FP200 FP0200
AREABLK AREABLK2

FP201 FP0201

FP202 FP0202

FP229 FP0229

FP230 FP0230

FP231 FP0231

FP232 FP0232

FP233 FP0233

FP234 FP0234

FP235 FP0235

FP236 FP0236

FP237 FP0237

FP238 FP0238

FP239 FP0239

FP240 FP0240

FP241 FP0241

FP242 FP0242

FP243 FP0243

FP244 FP0244

FP245 FP0245

FP246 FP0246

FP273 FP0273

FP274 FP0274

FP275 FP0275

FP276 FP0276

FP277 FP0277

FP278 FP0278

FP279 FP0279

FP280 FP0280

FP281 FP0281

FP282 FP0282

FP283 FP0283

FP284 FP0284

FP285 FP0285

FP286 FP0286

FP287 FP0287

FP288 FP0288

FP289 FP0289

FP290 FP0290

FP317 FP0317

FP318 FP0318

FP319 FP0319

FP320 FP0320

FP321 FP0321

FP322 FP0322

FP323 FP0323

FP324 FP0324
AREABLK AREABLK2

FP325 FP0325

FP326 FP0326

FP327 FP0327

FP328 FP0328

FP329 FP0329

FP330 FP0330

FP331 FP0331

FP332 FP0332

FP333 FP0333

FP334 FP0334

FP363 FP0363

FP364 FP0364

FP365 FP0365

FP366 FP0366

FP367 FP0367

FP368 FP0368

FP369 FP0369

FP370 FP0370

FP371 FP0371

FP372 FP0372

FP373 FP0373

FP374 FP0374

FP375 FP0375

FP376 FP0376

FP377 FP0377

FP378 FP0378

FP414 FP0414

FP415 FP0415

FP416 FP0416

FP417 FP0417

FP418 FP0418

FP419 FP0419

FP420 FP0420

FP421 FP0421

FP422 FP0422

FP459 FP0459

FP460 FP0460

FP461 FP0461

FP462 FP0462

FP463 FP0463

FP464 FP0464

FP465 FP0465

FP466 FP0466

FP503 FP0503

FP504 FP0504

FP505 FP0505
AREABLK AREABLK2

FP506 FP0506

FP507 FP0507

FP508 FP0508

FP509 FP0509

FP510 FP0510

FP548 FP0548

FP549 FP0549

FP550 FP0550

FP551 FP0551

FP552 FP0552

FP553 FP0553

FP554 FP0554

FP594 FP0594

FP595 FP0595

FP596 FP0596

FP597 FP0597

FP598 FP0598

FP639 FP0639

FP640 FP0640

FP641 FP0641

FP642 FP0642

FP685 FP0685

FP686 FP0686

HE009 HE0009

HE010 HE0010

HE011 HE0011

HE012 HE0012

HE013 HE0013

HE014 HE0014

HE015 HE0015

HE016 HE0016

HE017 HE0017

HE018 HE0018

HE019 HE0019

HE020 HE0020

HE021 HE0021

HE022 HE0022

HE023 HE0023

HE024 HE0024

HE025 HE0025

HE026 HE0026

HE053 HE0053

HE054 HE0054

HE055 HE0055

HE056 HE0056

HE057 HE0057
AREABLK AREABLK2

HE058 HE0058

HE059 HE0059

HE060 HE0060

HE061 HE0061

HE062 HE0062

HE063 HE0063

HE064 HE0064

HE065 HE0065

HE066 HE0066

HE067 HE0067

HE068 HE0068

HE069 HE0069

HE070 HE0070

HE097 HE0097

HE098 HE0098

HE099 HE0099

HE100 HE0100

HE101 HE0101

HE102 HE0102

HE103 HE0103

HE104 HE0104

HE105 HE0105

HE106 HE0106

HE107 HE0107

HE108 HE0108

HE109 HE0109

HE110 HE0110

HE111 HE0111

HE112 HE0112

HE113 HE0113

HE114 HE0114

HE141 HE0141

HE142 HE0142

HE143 HE0143

HE144 HE0144

HE145 HE0145

HE146 HE0146

HE147 HE0147

HE148 HE0148

HE149 HE0149

HE150 HE0150

HE151 HE0151

HE152 HE0152

HE153 HE0153

HE154 HE0154

HE155 HE0155
AREABLK AREABLK2

HE156 HE0156

HE157 HE0157

HE158 HE0158

HE185 HE0185

HE186 HE0186

HE187 HE0187

HE188 HE0188

HE189 HE0189

HE190 HE0190

HE191 HE0191

HE192 HE0192

HE193 HE0193

HE194 HE0194

HE195 HE0195

HE196 HE0196

HE197 HE0197

HE198 HE0198

HE199 HE0199

HE200 HE0200

HE201 HE0201

HE202 HE0202

HE229 HE0229

HE230 HE0230

HE231 HE0231

HE232 HE0232

HE233 HE0233

HE234 HE0234

HE235 HE0235

HE236 HE0236

HE237 HE0237

HE238 HE0238

HE239 HE0239

HE240 HE0240

HE241 HE0241

HE242 HE0242

HE243 HE0243

HE244 HE0244

HE245 HE0245

HE246 HE0246

HE273 HE0273

HE274 HE0274

HE275 HE0275

HE276 HE0276

HE277 HE0277

HE278 HE0278

HE279 HE0279
AREABLK AREABLK2

HE280 HE0280

HE281 HE0281

HE282 HE0282

HE283 HE0283

HE284 HE0284

HE285 HE0285

HE286 HE0286

HE287 HE0287

HE288 HE0288

HE289 HE0289

HE290 HE0290

HE317 HE0317

HE318 HE0318

HE319 HE0319

HE320 HE0320

HE321 HE0321

HE322 HE0322

HE323 HE0323

HE324 HE0324

HE325 HE0325

HE326 HE0326

HE327 HE0327

HE328 HE0328

HE329 HE0329

HE330 HE0330

HE331 HE0331

HE332 HE0332

HE333 HE0333

HE334 HE0334

HE361 HE0361

HE362 HE0362

HE363 HE0363

HE364 HE0364

HE365 HE0365

HE366 HE0366

HE367 HE0367

HE368 HE0368

HE369 HE0369

HE370 HE0370

HE371 HE0371

HE372 HE0372

HE373 HE0373

HE374 HE0374

HE375 HE0375

HE376 HE0376

HE377 HE0377
AREABLK AREABLK2

HE378 HE0378

HE405 HE0405

HE406 HE0406

HE407 HE0407

HE408 HE0408

HE409 HE0409

HE410 HE0410

HE411 HE0411

HE412 HE0412

HE413 HE0413

HE414 HE0414

HE415 HE0415

HE416 HE0416

HE417 HE0417

HE418 HE0418

HE419 HE0419

HE420 HE0420

HE421 HE0421

HE422 HE0422

HE449 HE0449

HE450 HE0450

HE451 HE0451

HE452 HE0452

HE453 HE0453

HE454 HE0454

HE455 HE0455

HE456 HE0456

HE457 HE0457

HE458 HE0458

HE459 HE0459

HE460 HE0460

HE461 HE0461

HE462 HE0462

HE463 HE0463

HE464 HE0464

HE465 HE0465

HE466 HE0466

HE493 HE0493

HE494 HE0494

HE495 HE0495

HE496 HE0496

HE497 HE0497

HE498 HE0498

HE499 HE0499

HE500 HE0500

HE501 HE0501
AREABLK AREABLK2

HE502 HE0502

HE503 HE0503

HE504 HE0504

HE505 HE0505

HE506 HE0506

HE507 HE0507

HE508 HE0508

HE509 HE0509

HE510 HE0510

HE537 HE0537

HE538 HE0538

HE539 HE0539

HE540 HE0540

HE541 HE0541

HE542 HE0542

HE543 HE0543

HE544 HE0544

HE545 HE0545

HE546 HE0546

HE547 HE0547

HE548 HE0548

HE549 HE0549

HE550 HE0550

HE551 HE0551

HE552 HE0552

HE553 HE0553

HE554 HE0554

HE581 HE0581

HE582 HE0582

HE583 HE0583

HE584 HE0584

HE585 HE0585

HE586 HE0586

HE587 HE0587

HE588 HE0588

HE589 HE0589

HE590 HE0590

HE591 HE0591

HE592 HE0592

HE593 HE0593

HE594 HE0594

HE595 HE0595

HE596 HE0596

HE597 HE0597

HE598 HE0598

HE625 HE0625
AREABLK AREABLK2

HE626 HE0626

HE627 HE0627

HE628 HE0628

HE629 HE0629

HE630 HE0630

HE631 HE0631

HE632 HE0632

HE633 HE0633

HE634 HE0634

HE635 HE0635

HE636 HE0636

HE637 HE0637

HE638 HE0638

HE639 HE0639

HE640 HE0640

HE641 HE0641

HE642 HE0642

HE669 HE0669

HE670 HE0670

HE671 HE0671

HE672 HE0672

HE673 HE0673

HE674 HE0674

HE675 HE0675

HE676 HE0676

HE677 HE0677

HE678 HE0678

HE679 HE0679

HE680 HE0680

HE681 HE0681

HE682 HE0682

HE683 HE0683

HE684 HE0684

HE685 HE0685

HE686 HE0686

HE713 HE0713

HE714 HE0714

HE715 HE0715

HE716 HE0716

HE717 HE0717

HE718 HE0718

HE719 HE0719

HE720 HE0720

HE721 HE0721

HE722 HE0722

HE723 HE0723
AREABLK AREABLK2

HE724 HE0724

HE725 HE0725

HE726 HE0726

HE727 HE0727

HE728 HE0728

HE729 HE0729

HE730 HE0730

HE757 HE0757

HE758 HE0758

HE759 HE0759

HE760 HE0760

HE761 HE0761

HE762 HE0762

HE763 HE0763

HE764 HE0764

HE765 HE0765

HE766 HE0766

HE767 HE0767

HE768 HE0768

HE769 HE0769

HE770 HE0770

HE771 HE0771

HE772 HE0772

HE773 HE0773

HE774 HE0774

HE801 HE0801

HE802 HE0802

HE803 HE0803

HE804 HE0804

HE805 HE0805

HE806 HE0806

HE807 HE0807

HE808 HE0808

HE809 HE0809

HE810 HE0810

HE811 HE0811

HE812 HE0812

HE813 HE0813

HE814 HE0814

HE815 HE0815

HE816 HE0816

HE817 HE0817

HE818 HE0818

HE845 HE0845

HE846 HE0846

HE847 HE0847
AREABLK AREABLK2

HE848 HE0848

HE849 HE0849

HE850 HE0850

HE851 HE0851

HE852 HE0852

HE853 HE0853

HE854 HE0854

HE855 HE0855

HE856 HE0856

HE857 HE0857

HE858 HE0858

HE859 HE0859

HE860 HE0860

HE861 HE0861

HE862 HE0862

HE889 HE0889

HE890 HE0890

HE891 HE0891

HE892 HE0892

HE893 HE0893

HE894 HE0894

HE895 HE0895

HE896 HE0896

HE897 HE0897

HE898 HE0898

HE899 HE0899

HE900 HE0900

HE901 HE0901

HE902 HE0902

HE903 HE0903

HE904 HE0904

HE905 HE0905

HE906 HE0906

HE933 HE0933

HE934 HE0934

HE935 HE0935

HE936 HE0936

HE937 HE0937

HE938 HE0938

HE939 HE0939

HE940 HE0940

HE941 HE0941

HE942 HE0942

HE943 HE0943

HE944 HE0944

HE945 HE0945
AREABLK AREABLK2

HE946 HE0946

HE947 HE0947

HE948 HE0948

HE949 HE0949

HE950 HE0950

HE977 HE0977

HE978 HE0978

HE979 HE0979

HE980 HE0980

HE981 HE0981

HE982 HE0982

HE983 HE0983

HE984 HE0984

HE985 HE0985

HE986 HE0986

HE987 HE0987

HE988 HE0988

HE989 HE0989

HE990 HE0990

HE991 HE0991

HE992 HE0992

HE993 HE0993

HE994 HE0994

LL009 LL0009

LL010 LL0010

LL011 LL0011

LL012 LL0012

LL013 LL0013

LL014 LL0014

LL015 LL0015

LL016 LL0016

LL017 LL0017

LL018 LL0018

LL019 LL0019

LL020 LL0020

LL021 LL0021

LL022 LL0022

LL023 LL0023

LL024 LL0024

LL025 LL0025

LL026 LL0026

LL053 LL0053

LL054 LL0054

LL055 LL0055

LL056 LL0056

LL057 LL0057
AREABLK AREABLK2

LL058 LL0058

LL059 LL0059

LL060 LL0060

LL061 LL0061

LL062 LL0062

LL063 LL0063

LL064 LL0064

LL065 LL0065

LL066 LL0066

LL067 LL0067

LL068 LL0068

LL069 LL0069

LL070 LL0070

LL097 LL0097

LL098 LL0098

LL099 LL0099

LL100 LL0100

LL101 LL0101

LL102 LL0102

LL103 LL0103

LL104 LL0104

LL105 LL0105

LL106 LL0106

LL107 LL0107

LL108 LL0108

LL109 LL0109

LL110 LL0110

LL111 LL0111

LL112 LL0112

LL113 LL0113

LL114 LL0114

LL141 LL0141

LL142 LL0142

LL143 LL0143

LL144 LL0144

LL145 LL0145

LL146 LL0146

LL147 LL0147

LL148 LL0148

LL149 LL0149

LL150 LL0150

LL151 LL0151

LL152 LL0152

LL153 LL0153

LL154 LL0154

LL155 LL0155
AREABLK AREABLK2

LL156 LL0156

LL157 LL0157

LL158 LL0158

LL185 LL0185

LL186 LL0186

LL187 LL0187

LL188 LL0188

LL189 LL0189

LL190 LL0190

LL191 LL0191

LL192 LL0192

LL193 LL0193

LL194 LL0194

LL195 LL0195

LL196 LL0196

LL197 LL0197

LL198 LL0198

LL199 LL0199

LL200 LL0200

LL201 LL0201

LL202 LL0202

LL229 LL0229

LL230 LL0230

LL231 LL0231

LL232 LL0232

LL233 LL0233

LL234 LL0234

LL235 LL0235

LL236 LL0236

LL237 LL0237

LL238 LL0238

LL239 LL0239

LL240 LL0240

LL241 LL0241

LL242 LL0242

LL243 LL0243

LL244 LL0244

LL245 LL0245

LL246 LL0246

LL273 LL0273

LL274 LL0274

LL275 LL0275

LL276 LL0276

LL277 LL0277

LL278 LL0278

LL279 LL0279
AREABLK AREABLK2

LL280 LL0280

LL281 LL0281

LL282 LL0282

LL283 LL0283

LL284 LL0284

LL285 LL0285

LL286 LL0286

LL287 LL0287

LL288 LL0288

LL289 LL0289

LL290 LL0290

LL317 LL0317

LL318 LL0318

LL319 LL0319

LL320 LL0320

LL321 LL0321

LL322 LL0322

LL323 LL0323

LL324 LL0324

LL325 LL0325

LL326 LL0326

LL327 LL0327

LL328 LL0328

LL329 LL0329

LL330 LL0330

LL331 LL0331

LL332 LL0332

LL333 LL0333

LL334 LL0334

LL361 LL0361

LL362 LL0362

LL363 LL0363

LL364 LL0364

LL365 LL0365

LL366 LL0366

LL367 LL0367

LL368 LL0368

LL369 LL0369

LL370 LL0370

LL371 LL0371

LL372 LL0372

LL373 LL0373

LL374 LL0374

LL375 LL0375

LL376 LL0376

LL377 LL0377
AREABLK AREABLK2

LL378 LL0378

LL405 LL0405

LL406 LL0406

LL407 LL0407

LL408 LL0408

LL409 LL0409

LL410 LL0410

LL411 LL0411

LL412 LL0412

LL413 LL0413

LL414 LL0414

LL415 LL0415

LL416 LL0416

LL417 LL0417

LL418 LL0418

LL419 LL0419

LL420 LL0420

LL421 LL0421

LL422 LL0422

LL449 LL0449

LL450 LL0450

LL451 LL0451

LL452 LL0452

LL453 LL0453

LL454 LL0454

LL455 LL0455

LL456 LL0456

LL457 LL0457

LL458 LL0458

LL459 LL0459

LL460 LL0460

LL461 LL0461

LL462 LL0462

LL463 LL0463

LL464 LL0464

LL465 LL0465

LL466 LL0466

LL493 LL0493

LL494 LL0494

LL495 LL0495

LL496 LL0496

LL497 LL0497

LL498 LL0498

LL499 LL0499

LL500 LL0500

LL501 LL0501
AREABLK AREABLK2

LL502 LL0502

LL503 LL0503

LL504 LL0504

LL505 LL0505

LL506 LL0506

LL507 LL0507

LL508 LL0508

LL509 LL0509

LL510 LL0510

LL537 LL0537

LL538 LL0538

LL539 LL0539

LL540 LL0540

LL541 LL0541

LL542 LL0542

LL543 LL0543

LL544 LL0544

LL545 LL0545

LL546 LL0546

LL547 LL0547

LL548 LL0548

LL549 LL0549

LL550 LL0550

LL551 LL0551

LL552 LL0552

LL553 LL0553

LL554 LL0554

LL581 LL0581

LL582 LL0582

LL583 LL0583

LL584 LL0584

LL585 LL0585

LL586 LL0586

LL587 LL0587

LL588 LL0588

LL589 LL0589

LL590 LL0590

LL591 LL0591

LL592 LL0592

LL593 LL0593

LL594 LL0594

LL595 LL0595

LL596 LL0596

LL597 LL0597

LL598 LL0598

LL625 LL0625
AREABLK AREABLK2

LL626 LL0626

LL627 LL0627

LL628 LL0628

LL629 LL0629

LL630 LL0630

LL631 LL0631

LL632 LL0632

LL633 LL0633

LL634 LL0634

LL635 LL0635

LL636 LL0636

LL637 LL0637

LL638 LL0638

LL639 LL0639

LL640 LL0640

LL641 LL0641

LL642 LL0642

LL669 LL0669

LL670 LL0670

LL671 LL0671

LL672 LL0672

LL673 LL0673

LL674 LL0674

LL675 LL0675

LL676 LL0676

LL677 LL0677

LL678 LL0678

LL679 LL0679

LL680 LL0680

LL681 LL0681

LL682 LL0682

LL683 LL0683

LL684 LL0684

LL685 LL0685

LL686 LL0686

LL713 LL0713

LL714 LL0714

LL715 LL0715

LL716 LL0716

LL717 LL0717

LL718 LL0718

LL719 LL0719

LL720 LL0720

LL721 LL0721

LL722 LL0722

LL723 LL0723
AREABLK AREABLK2

LL724 LL0724

LL725 LL0725

LL726 LL0726

LL727 LL0727

LL728 LL0728

LL729 LL0729

LL730 LL0730

LL757 LL0757

LL758 LL0758

LL759 LL0759

LL760 LL0760

LL761 LL0761

LL762 LL0762

LL763 LL0763

LL764 LL0764

LL765 LL0765

LL766 LL0766

LL767 LL0767

LL768 LL0768

LL769 LL0769

LL770 LL0770

LL771 LL0771

LL772 LL0772

LL773 LL0773

LL774 LL0774

LL801 LL0801

LL802 LL0802

LL803 LL0803

LL804 LL0804

LL805 LL0805

LL806 LL0806

LL807 LL0807

LL808 LL0808

LL809 LL0809

LL810 LL0810

LL811 LL0811

LL812 LL0812

LL813 LL0813

LL814 LL0814

LL815 LL0815

LL816 LL0816

LL817 LL0817

LL818 LL0818

LL845 LL0845

LL846 LL0846

LL847 LL0847
AREABLK AREABLK2

LL848 LL0848

LL849 LL0849

LL850 LL0850

LL851 LL0851

LL852 LL0852

LL853 LL0853

LL854 LL0854

LL855 LL0855

LL856 LL0856

LL857 LL0857

LL858 LL0858

LL859 LL0859

LL860 LL0860

LL861 LL0861

LL862 LL0862

LL889 LL0889

LL890 LL0890

LL891 LL0891

LL892 LL0892

LL893 LL0893

LL894 LL0894

LL895 LL0895

LL896 LL0896

LL897 LL0897

LL898 LL0898

LL899 LL0899

LL900 LL0900

LL901 LL0901

LL902 LL0902

LL903 LL0903

LL904 LL0904

LL905 LL0905

LL906 LL0906

LL933 LL0933

LL934 LL0934

LL935 LL0935

LL936 LL0936

LL937 LL0937

LL938 LL0938

LL939 LL0939

LL940 LL0940

LL941 LL0941

LL942 LL0942

LL943 LL0943

LL944 LL0944

LL945 LL0945
AREABLK AREABLK2

LL946 LL0946

LL947 LL0947

LL948 LL0948

LL949 LL0949

LL950 LL0950

LL977 LL0977

LL978 LL0978

LL979 LL0979

LL980 LL0980

LL981 LL0981

LL982 LL0982

LL983 LL0983

LL984 LL0984

LL985 LL0985

LL986 LL0986

LL987 LL0987

LL988 LL0988

LL989 LL0989

LL990 LL0990

LL991 LL0991

LL992 LL0992

LL993 LL0993

LL994 LL0994
AREABLK AREABLK2

DC148 DC0148

DC186 DC0186

DC187 DC0187

DC188 DC0188

DC189 DC0189

DC190 DC0190

DC191 DC0191

DC192 DC0192

DC230 DC0230

DC231 DC0231

DC232 DC0232

DC233 DC0233

DC234 DC0234

DC235 DC0235

DC236 DC0236

DC274 DC0274

DC275 DC0275

DC276 DC0276

DC277 DC0277

DC278 DC0278

DC279 DC0279

DC280 DC0280

DC318 DC0318

DC319 DC0319

DC320 DC0320

DC321 DC0321

DC322 DC0322

DC323 DC0323

DC324 DC0324

DC362 DC0362

DC363 DC0363

DC364 DC0364

DC365 DC0365

DC366 DC0366

DC367 DC0367

DC368 DC0368

DC369 DC0369

DC406 DC0406

DC407 DC0407

DC408 DC0408

DC409 DC0409

DC410 DC0410

DC411 DC0411

DC412 DC0412

DC413 DC0413

DC450 DC0450
AREABLK AREABLK2

DC451 DC0451

DC452 DC0452

DC453 DC0453

DC454 DC0454

DC455 DC0455

DC456 DC0456

DC457 DC0457

DC494 DC0494

DC495 DC0495

DC496 DC0496

DC497 DC0497

DC498 DC0498

DC499 DC0499

DC500 DC0500

DC501 DC0501

DC502 DC0502

DC503 DC0503

DC538 DC0538

DC539 DC0539

DC540 DC0540

DC541 DC0541

DC542 DC0542

DC543 DC0543

DC544 DC0544

DC545 DC0545

DC546 DC0546

DC547 DC0547

DC548 DC0548

DC582 DC0582

DC583 DC0583

DC584 DC0584

DC585 DC0585

DC586 DC0586

DC587 DC0587

DC588 DC0588

DC589 DC0589

DC590 DC0590

DC591 DC0591

DC592 DC0592

DC593 DC0593

DC626 DC0626

DC627 DC0627

DC628 DC0628

DC629 DC0629

DC630 DC0630

DC631 DC0631
AREABLK AREABLK2

DC632 DC0632

DC633 DC0633

DC634 DC0634

DC635 DC0635

DC636 DC0636

DC637 DC0637

DC638 DC0638

DC670 DC0670

DC671 DC0671

DC672 DC0672

DC673 DC0673

DC674 DC0674

DC675 DC0675

DC676 DC0676

DC677 DC0677

DC678 DC0678

DC679 DC0679

DC680 DC0680

DC681 DC0681

DC682 DC0682

DC683 DC0683

DC714 DC0714

DC715 DC0715

DC716 DC0716

DC717 DC0717

DC718 DC0718

DC719 DC0719

DC720 DC0720

DC721 DC0721

DC722 DC0722

DC723 DC0723

DC724 DC0724

DC725 DC0725

DC726 DC0726

DC727 DC0727

DC728 DC0728

DC758 DC0758

DC759 DC0759

DC760 DC0760

DC761 DC0761

DC762 DC0762

DC763 DC0763

DC764 DC0764

DC765 DC0765

DC766 DC0766

DC767 DC0767
AREABLK AREABLK2

DC768 DC0768

DC769 DC0769

DC770 DC0770

DC771 DC0771

DC772 DC0772

DC802 DC0802

DC803 DC0803

DC804 DC0804

DC805 DC0805

DC806 DC0806

DC807 DC0807

DC808 DC0808

DC809 DC0809

DC810 DC0810

DC811 DC0811

DC812 DC0812

DC813 DC0813

DC814 DC0814

DC815 DC0815

DC816 DC0816

DC846 DC0846

DC847 DC0847

DC848 DC0848

DC849 DC0849

DC850 DC0850

DC851 DC0851

DC852 DC0852

DC853 DC0853

DC854 DC0854

DC855 DC0855

DC856 DC0856

DC857 DC0857

DC858 DC0858

DC859 DC0859

DC860 DC0860

DC861 DC0861

DC890 DC0890

DC891 DC0891

DC892 DC0892

DC893 DC0893

DC894 DC0894

DC895 DC0895

DC896 DC0896

DC897 DC0897

DC898 DC0898

DC899 DC0899
AREABLK AREABLK2

DC900 DC0900

DC901 DC0901

DC902 DC0902

DC903 DC0903

DC904 DC0904

DC905 DC0905

DC934 DC0934

DC935 DC0935

DC936 DC0936

DC937 DC0937

DC938 DC0938

DC939 DC0939

DC940 DC0940

DC941 DC0941

DC942 DC0942

DC943 DC0943

DC944 DC0944

DC945 DC0945

DC946 DC0946

DC947 DC0947

DC948 DC0948

DC949 DC0949

DC978 DC0978

DC979 DC0979

DC980 DC0980

DC981 DC0981

DC982 DC0982

DC983 DC0983

DC984 DC0984

DC985 DC0985

DC986 DC0986

DC987 DC0987

DC988 DC0988

DC989 DC0989

DC990 DC0990

DC991 DC0991

DC992 DC0992

DC993 DC0993

FP010 FP0010

FP011 FP0011

FP012 FP0012

FP013 FP0013

FP014 FP0014

FP015 FP0015

FP016 FP0016

FP017 FP0017
AREABLK AREABLK2

FP018 FP0018

FP019 FP0019

FP020 FP0020

FP021 FP0021

FP022 FP0022

FP023 FP0023

FP024 FP0024

FP025 FP0025

FP054 FP0054

FP055 FP0055

FP056 FP0056

FP057 FP0057

FP058 FP0058

FP059 FP0059

FP060 FP0060

FP061 FP0061

FP062 FP0062

FP063 FP0063

FP064 FP0064

FP065 FP0065

FP066 FP0066

FP067 FP0067

FP068 FP0068

FP069 FP0069

FP098 FP0098

FP099 FP0099

FP100 FP0100

FP101 FP0101

FP102 FP0102

FP103 FP0103

FP104 FP0104

FP105 FP0105

FP106 FP0106

FP107 FP0107

FP108 FP0108

FP109 FP0109

FP110 FP0110

FP111 FP0111

FP112 FP0112

FP113 FP0113

FP142 FP0142

FP143 FP0143

FP144 FP0144

FP145 FP0145

FP146 FP0146

FP147 FP0147
AREABLK AREABLK2

FP148 FP0148

FP149 FP0149

FP150 FP0150

FP151 FP0151

FP152 FP0152

FP153 FP0153

FP154 FP0154

FP155 FP0155

FP156 FP0156

FP157 FP0157

FP186 FP0186

FP187 FP0187

FP188 FP0188

FP189 FP0189

FP190 FP0190

FP191 FP0191

FP192 FP0192

FP193 FP0193

FP194 FP0194

FP195 FP0195

FP196 FP0196

FP197 FP0197

FP198 FP0198

FP199 FP0199

FP200 FP0200

FP201 FP0201

FP230 FP0230

FP231 FP0231

FP232 FP0232

FP233 FP0233

FP234 FP0234

FP235 FP0235

FP236 FP0236

FP237 FP0237

FP238 FP0238

FP239 FP0239

FP240 FP0240

FP241 FP0241

FP242 FP0242

FP243 FP0243

FP244 FP0244

FP245 FP0245

FP274 FP0274

FP275 FP0275

FP276 FP0276

FP277 FP0277
AREABLK AREABLK2

FP278 FP0278

FP279 FP0279

FP280 FP0280

FP281 FP0281

FP282 FP0282

FP283 FP0283

FP284 FP0284

FP285 FP0285

FP286 FP0286

FP287 FP0287

FP288 FP0288

FP289 FP0289

FP318 FP0318

FP319 FP0319

FP320 FP0320

FP321 FP0321

FP322 FP0322

FP323 FP0323

FP324 FP0324

FP325 FP0325

FP326 FP0326

FP327 FP0327

FP328 FP0328

FP329 FP0329

FP330 FP0330

FP331 FP0331

FP332 FP0332

FP333 FP0333

FP363 FP0363

FP364 FP0364

FP365 FP0365

FP366 FP0366

FP367 FP0367

FP368 FP0368

FP369 FP0369

FP370 FP0370

FP371 FP0371

FP372 FP0372

FP373 FP0373

FP374 FP0374

FP375 FP0375

FP376 FP0376

FP377 FP0377

FP416 FP0416

FP417 FP0417

FP418 FP0418
AREABLK AREABLK2

FP419 FP0419

FP420 FP0420

FP421 FP0421

FP459 FP0459

FP460 FP0460

FP461 FP0461

FP462 FP0462

FP463 FP0463

FP464 FP0464

FP465 FP0465

FP503 FP0503

FP504 FP0504

FP505 FP0505

FP506 FP0506

FP507 FP0507

FP508 FP0508

FP509 FP0509

FP548 FP0548

FP549 FP0549

FP550 FP0550

FP551 FP0551

FP552 FP0552

FP553 FP0553

FP594 FP0594

FP595 FP0595

FP596 FP0596

FP597 FP0597

FP639 FP0639

FP640 FP0640

FP641 FP0641

FP685 FP0685

HE010 HE0010

HE011 HE0011

HE012 HE0012

HE013 HE0013

HE014 HE0014

HE015 HE0015

HE016 HE0016

HE017 HE0017

HE018 HE0018

HE019 HE0019

HE020 HE0020

HE021 HE0021

HE022 HE0022

HE023 HE0023

HE024 HE0024
AREABLK AREABLK2

HE025 HE0025

HE054 HE0054

HE055 HE0055

HE056 HE0056

HE057 HE0057

HE058 HE0058

HE059 HE0059

HE060 HE0060

HE061 HE0061

HE062 HE0062

HE063 HE0063

HE064 HE0064

HE065 HE0065

HE066 HE0066

HE067 HE0067

HE068 HE0068

HE069 HE0069

HE098 HE0098

HE099 HE0099

HE100 HE0100

HE101 HE0101

HE102 HE0102

HE103 HE0103

HE104 HE0104

HE105 HE0105

HE106 HE0106

HE107 HE0107

HE108 HE0108

HE109 HE0109

HE110 HE0110

HE111 HE0111

HE112 HE0112

HE113 HE0113

HE142 HE0142

HE143 HE0143

HE144 HE0144

HE145 HE0145

HE146 HE0146

HE147 HE0147

HE148 HE0148

HE149 HE0149

HE150 HE0150

HE151 HE0151

HE152 HE0152

HE153 HE0153

HE154 HE0154
AREABLK AREABLK2

HE155 HE0155

HE156 HE0156

HE157 HE0157

HE186 HE0186

HE187 HE0187

HE188 HE0188

HE189 HE0189

HE190 HE0190

HE191 HE0191

HE192 HE0192

HE193 HE0193

HE194 HE0194

HE195 HE0195

HE196 HE0196

HE197 HE0197

HE198 HE0198

HE199 HE0199

HE200 HE0200

HE201 HE0201

HE230 HE0230

HE231 HE0231

HE232 HE0232

HE233 HE0233

HE234 HE0234

HE235 HE0235

HE236 HE0236

HE237 HE0237

HE238 HE0238

HE239 HE0239

HE240 HE0240

HE241 HE0241

HE242 HE0242

HE243 HE0243

HE244 HE0244

HE245 HE0245

HE274 HE0274

HE275 HE0275

HE276 HE0276

HE277 HE0277

HE278 HE0278

HE279 HE0279

HE280 HE0280

HE281 HE0281

HE282 HE0282

HE283 HE0283

HE284 HE0284
AREABLK AREABLK2

HE285 HE0285

HE286 HE0286

HE287 HE0287

HE288 HE0288

HE289 HE0289

HE318 HE0318

HE319 HE0319

HE320 HE0320

HE321 HE0321

HE322 HE0322

HE323 HE0323

HE324 HE0324

HE325 HE0325

HE326 HE0326

HE327 HE0327

HE328 HE0328

HE329 HE0329

HE330 HE0330

HE331 HE0331

HE332 HE0332

HE333 HE0333

HE362 HE0362

HE363 HE0363

HE364 HE0364

HE365 HE0365

HE366 HE0366

HE367 HE0367

HE368 HE0368

HE369 HE0369

HE370 HE0370

HE371 HE0371

HE372 HE0372

HE373 HE0373

HE374 HE0374

HE375 HE0375

HE376 HE0376

HE377 HE0377

HE406 HE0406

HE407 HE0407

HE408 HE0408

HE409 HE0409

HE410 HE0410

HE411 HE0411

HE412 HE0412

HE413 HE0413

HE414 HE0414
AREABLK AREABLK2

HE415 HE0415

HE416 HE0416

HE417 HE0417

HE418 HE0418

HE419 HE0419

HE420 HE0420

HE421 HE0421

HE450 HE0450

HE451 HE0451

HE452 HE0452

HE453 HE0453

HE454 HE0454

HE455 HE0455

HE456 HE0456

HE457 HE0457

HE458 HE0458

HE459 HE0459

HE460 HE0460

HE461 HE0461

HE462 HE0462

HE463 HE0463

HE464 HE0464

HE465 HE0465

HE494 HE0494

HE495 HE0495

HE496 HE0496

HE497 HE0497

HE498 HE0498

HE499 HE0499

HE500 HE0500

HE501 HE0501

HE502 HE0502

HE503 HE0503

HE504 HE0504

HE505 HE0505

HE506 HE0506

HE507 HE0507

HE508 HE0508

HE509 HE0509

HE538 HE0538

HE539 HE0539

HE540 HE0540

HE541 HE0541

HE542 HE0542

HE543 HE0543

HE544 HE0544
AREABLK AREABLK2

HE545 HE0545

HE546 HE0546

HE547 HE0547

HE548 HE0548

HE549 HE0549

HE550 HE0550

HE551 HE0551

HE552 HE0552

HE553 HE0553

HE582 HE0582

HE583 HE0583

HE584 HE0584

HE585 HE0585

HE586 HE0586

HE587 HE0587

HE588 HE0588

HE589 HE0589

HE590 HE0590

HE591 HE0591

HE592 HE0592

HE593 HE0593

HE594 HE0594

HE595 HE0595

HE596 HE0596

HE597 HE0597

HE626 HE0626

HE627 HE0627

HE628 HE0628

HE629 HE0629

HE630 HE0630

HE631 HE0631

HE632 HE0632

HE633 HE0633

HE634 HE0634

HE635 HE0635

HE636 HE0636

HE637 HE0637

HE638 HE0638

HE639 HE0639

HE640 HE0640

HE641 HE0641

HE670 HE0670

HE671 HE0671

HE672 HE0672

HE673 HE0673

HE674 HE0674
AREABLK AREABLK2

HE675 HE0675

HE676 HE0676

HE677 HE0677

HE678 HE0678

HE679 HE0679

HE680 HE0680

HE681 HE0681

HE682 HE0682

HE683 HE0683

HE684 HE0684

HE685 HE0685

HE714 HE0714

HE715 HE0715

HE716 HE0716

HE717 HE0717

HE718 HE0718

HE719 HE0719

HE720 HE0720

HE721 HE0721

HE722 HE0722

HE723 HE0723

HE724 HE0724

HE725 HE0725

HE726 HE0726

HE727 HE0727

HE728 HE0728

HE729 HE0729

HE758 HE0758

HE759 HE0759

HE760 HE0760

HE761 HE0761

HE762 HE0762

HE763 HE0763

HE764 HE0764

HE765 HE0765

HE766 HE0766

HE767 HE0767

HE768 HE0768

HE769 HE0769

HE770 HE0770

HE771 HE0771

HE772 HE0772

HE773 HE0773

HE802 HE0802

HE803 HE0803

HE804 HE0804
AREABLK AREABLK2

HE805 HE0805

HE806 HE0806

HE807 HE0807

HE808 HE0808

HE809 HE0809

HE810 HE0810

HE811 HE0811

HE812 HE0812

HE813 HE0813

HE814 HE0814

HE815 HE0815

HE816 HE0816

HE817 HE0817

HE846 HE0846

HE847 HE0847

HE848 HE0848

HE849 HE0849

HE850 HE0850

HE851 HE0851

HE852 HE0852

HE853 HE0853

HE854 HE0854

HE855 HE0855

HE856 HE0856

HE857 HE0857

HE858 HE0858

HE859 HE0859

HE860 HE0860

HE861 HE0861

HE890 HE0890

HE891 HE0891

HE892 HE0892

HE893 HE0893

HE894 HE0894

HE895 HE0895

HE896 HE0896

HE897 HE0897

HE898 HE0898

HE899 HE0899

HE900 HE0900

HE901 HE0901

HE902 HE0902

HE903 HE0903

HE904 HE0904

HE905 HE0905

HE934 HE0934
AREABLK AREABLK2

HE935 HE0935

HE936 HE0936

HE937 HE0937

HE938 HE0938

HE939 HE0939

HE940 HE0940

HE941 HE0941

HE942 HE0942

HE943 HE0943

HE944 HE0944

HE945 HE0945

HE946 HE0946

HE947 HE0947

HE948 HE0948

HE949 HE0949

HE978 HE0978

HE979 HE0979

HE980 HE0980

HE981 HE0981

HE982 HE0982

HE983 HE0983

HE984 HE0984

HE985 HE0985

HE986 HE0986

HE987 HE0987

HE988 HE0988

HE989 HE0989

HE990 HE0990

HE991 HE0991

HE992 HE0992

HE993 HE0993

LL010 LL0010

LL011 LL0011

LL012 LL0012

LL013 LL0013

LL014 LL0014

LL015 LL0015

LL016 LL0016

LL017 LL0017

LL018 LL0018

LL019 LL0019

LL020 LL0020

LL021 LL0021

LL022 LL0022

LL023 LL0023

LL024 LL0024
AREABLK AREABLK2

LL025 LL0025

LL054 LL0054

LL055 LL0055

LL056 LL0056

LL057 LL0057

LL058 LL0058

LL059 LL0059

LL060 LL0060

LL061 LL0061

LL062 LL0062

LL063 LL0063

LL064 LL0064

LL065 LL0065

LL066 LL0066

LL067 LL0067

LL068 LL0068

LL069 LL0069

LL098 LL0098

LL099 LL0099

LL100 LL0100

LL101 LL0101

LL102 LL0102

LL103 LL0103

LL104 LL0104

LL105 LL0105

LL106 LL0106

LL107 LL0107

LL108 LL0108

LL109 LL0109

LL110 LL0110

LL111 LL0111

LL112 LL0112

LL113 LL0113

LL142 LL0142

LL143 LL0143

LL144 LL0144

LL145 LL0145

LL146 LL0146

LL147 LL0147

LL148 LL0148

LL149 LL0149

LL150 LL0150

LL151 LL0151

LL152 LL0152

LL153 LL0153

LL154 LL0154
AREABLK AREABLK2

LL155 LL0155

LL156 LL0156

LL157 LL0157

LL186 LL0186

LL187 LL0187

LL188 LL0188

LL189 LL0189

LL190 LL0190

LL191 LL0191

LL192 LL0192

LL193 LL0193

LL194 LL0194

LL195 LL0195

LL196 LL0196

LL197 LL0197

LL198 LL0198

LL199 LL0199

LL200 LL0200

LL201 LL0201

LL230 LL0230

LL231 LL0231

LL232 LL0232

LL233 LL0233

LL234 LL0234

LL235 LL0235

LL236 LL0236

LL237 LL0237

LL238 LL0238

LL239 LL0239

LL240 LL0240

LL241 LL0241

LL242 LL0242

LL243 LL0243

LL244 LL0244

LL245 LL0245

LL274 LL0274

LL275 LL0275

LL276 LL0276

LL277 LL0277

LL278 LL0278

LL279 LL0279

LL280 LL0280

LL281 LL0281

LL282 LL0282

LL283 LL0283

LL284 LL0284
AREABLK AREABLK2

LL285 LL0285

LL286 LL0286

LL287 LL0287

LL288 LL0288

LL289 LL0289

LL318 LL0318

LL319 LL0319

LL320 LL0320

LL321 LL0321

LL322 LL0322

LL323 LL0323

LL324 LL0324

LL325 LL0325

LL326 LL0326

LL327 LL0327

LL328 LL0328

LL329 LL0329

LL330 LL0330

LL331 LL0331

LL332 LL0332

LL333 LL0333

LL362 LL0362

LL363 LL0363

LL364 LL0364

LL365 LL0365

LL366 LL0366

LL367 LL0367

LL368 LL0368

LL369 LL0369

LL370 LL0370

LL371 LL0371

LL372 LL0372

LL373 LL0373

LL374 LL0374

LL375 LL0375

LL376 LL0376

LL377 LL0377

LL406 LL0406

LL407 LL0407

LL408 LL0408

LL409 LL0409

LL410 LL0410

LL411 LL0411

LL412 LL0412

LL413 LL0413

LL414 LL0414
AREABLK AREABLK2

LL415 LL0415

LL416 LL0416

LL417 LL0417

LL418 LL0418

LL419 LL0419

LL420 LL0420

LL421 LL0421

LL450 LL0450

LL451 LL0451

LL452 LL0452

LL453 LL0453

LL454 LL0454

LL455 LL0455

LL456 LL0456

LL457 LL0457

LL458 LL0458

LL459 LL0459

LL460 LL0460

LL461 LL0461

LL462 LL0462

LL463 LL0463

LL464 LL0464

LL465 LL0465

LL494 LL0494

LL495 LL0495

LL496 LL0496

LL497 LL0497

LL498 LL0498

LL499 LL0499

LL500 LL0500

LL501 LL0501

LL502 LL0502

LL503 LL0503

LL504 LL0504

LL505 LL0505

LL506 LL0506

LL507 LL0507

LL508 LL0508

LL509 LL0509

LL538 LL0538

LL539 LL0539

LL540 LL0540

LL541 LL0541

LL542 LL0542

LL543 LL0543

LL544 LL0544
AREABLK AREABLK2

LL545 LL0545

LL546 LL0546

LL547 LL0547

LL548 LL0548

LL549 LL0549

LL550 LL0550

LL551 LL0551

LL552 LL0552

LL553 LL0553

LL582 LL0582

LL583 LL0583

LL584 LL0584

LL585 LL0585

LL586 LL0586

LL587 LL0587

LL588 LL0588

LL589 LL0589

LL590 LL0590

LL591 LL0591

LL592 LL0592

LL593 LL0593

LL594 LL0594

LL595 LL0595

LL596 LL0596

LL597 LL0597

LL626 LL0626

LL627 LL0627

LL628 LL0628

LL629 LL0629

LL630 LL0630

LL631 LL0631

LL632 LL0632

LL633 LL0633

LL634 LL0634

LL635 LL0635

LL636 LL0636

LL637 LL0637

LL638 LL0638

LL639 LL0639

LL640 LL0640

LL641 LL0641

LL670 LL0670

LL671 LL0671

LL672 LL0672

LL673 LL0673

LL674 LL0674
AREABLK AREABLK2

LL675 LL0675

LL676 LL0676

LL677 LL0677

LL678 LL0678

LL679 LL0679

LL680 LL0680

LL681 LL0681

LL682 LL0682

LL683 LL0683

LL684 LL0684

LL685 LL0685

LL714 LL0714

LL715 LL0715

LL716 LL0716

LL717 LL0717

LL718 LL0718

LL719 LL0719

LL720 LL0720

LL721 LL0721

LL722 LL0722

LL723 LL0723

LL724 LL0724

LL725 LL0725

LL726 LL0726

LL727 LL0727

LL728 LL0728

LL729 LL0729

LL758 LL0758

LL759 LL0759

LL760 LL0760

LL761 LL0761

LL762 LL0762

LL763 LL0763

LL764 LL0764

LL765 LL0765

LL766 LL0766

LL767 LL0767

LL768 LL0768

LL769 LL0769

LL770 LL0770

LL771 LL0771

LL772 LL0772

LL773 LL0773

LL802 LL0802

LL803 LL0803

LL804 LL0804
AREABLK AREABLK2

LL805 LL0805

LL806 LL0806

LL807 LL0807

LL808 LL0808

LL809 LL0809

LL810 LL0810

LL811 LL0811

LL812 LL0812

LL813 LL0813

LL814 LL0814

LL815 LL0815

LL816 LL0816

LL817 LL0817

LL846 LL0846

LL847 LL0847

LL848 LL0848

LL849 LL0849

LL850 LL0850

LL851 LL0851

LL852 LL0852

LL853 LL0853

LL854 LL0854

LL855 LL0855

LL856 LL0856

LL857 LL0857

LL858 LL0858

LL859 LL0859

LL860 LL0860

LL861 LL0861

LL890 LL0890

LL891 LL0891

LL892 LL0892

LL893 LL0893

LL894 LL0894

LL895 LL0895

LL896 LL0896

LL897 LL0897

LL898 LL0898

LL899 LL0899

LL900 LL0900

LL901 LL0901

LL902 LL0902

LL903 LL0903

LL904 LL0904

LL905 LL0905

LL934 LL0934
AREABLK AREABLK2

LL935 LL0935

LL936 LL0936

LL937 LL0937

LL938 LL0938

LL939 LL0939

LL940 LL0940

LL941 LL0941

LL942 LL0942

LL943 LL0943

LL944 LL0944

LL945 LL0945

LL946 LL0946

LL947 LL0947

LL948 LL0948

LL949 LL0949

LL978 LL0978

LL979 LL0979

LL980 LL0980

LL981 LL0981

LL982 LL0982

LL983 LL0983

LL984 LL0984

LL985 LL0985

LL986 LL0986

LL987 LL0987

LL988 LL0988

LL989 LL0989

LL990 LL0990

LL991 LL0991

LL992 LL0992

LL993 LL0993
LEASENUM BLOCKNUM AREABLK

G33771 143 DC143

G33772 145 DC145

G33773 146 DC146

G33774 187 DC187

G33775 188 DC188

G33776 189 DC189

G33777 190 DC190

G33778 191 DC191

G31537 229 DC229

G33779 230 DC230

G33780 231 DC231

G34471 232 DC232

G34472 233 DC233

G31539 273 DC273

G34474 274 DC274

G34475 275 DC275

G34476 276 DC276

G33781 281 DC281

G34478 317 DC317

G34479 318 DC318

G31540 319 DC319

G31541 320 DC320

G31542 321 DC321

G31543 322 DC322

G33782 324 DC324

G33783 325 DC325

G34480 361 DC361

G34481 362 DC362

G31545 363 DC363

G31546 364 DC364

G31547 365 DC365

G31548 366 DC366

G33784 367 DC367

G33785 368 DC368

G33786 369 DC369

G34482 405 DC405

G34483 406 DC406

G31549 407 DC407

G31550 408 DC408

G31551 409 DC409

G31552 410 DC410

G31553 411 DC411

G31554 412 DC412

G31555 413 DC413

G31556 451 DC451

G34485 452 DC452
LEASENUM BLOCKNUM AREABLK

G34486 453 DC453

G34487 454 DC454

G31557 455 DC455

G31558 456 DC456

G31559 457 DC457

G34489 493 DC493

G34490 496 DC496

G34491 497 DC497

G31560 498 DC498

G32369 499 DC499

G31561 541 DC541

G31562 542 DC542

G32370 543 DC543

G32371 544 DC544

G32372 545 DC545

G31563 585 DC585

G32373 586 DC586

G32374 587 DC587

G32375 588 DC588

G32376 589 DC589

G32377 590 DC590

G32378 591 DC591

G32000 592 DC592

G34495 625 DC625

G31564 629 DC629

G31565 630 DC630

G32379 631 DC631

G32380 632 DC632

G32381 633 DC633

G32382 634 DC634

G32383 635 DC635

G32001 636 DC636

G32002 637 DC637

G32003 638 DC638

G32004 639 DC639

G32005 640 DC640

G34498 669 DC669

G34499 670 DC670

G34500 671 DC671

G32384 676 DC676

G32385 677 DC677

G32386 678 DC678

G32387 679 DC679

G32006 680 DC680

G32007 681 DC681

G32008 682 DC682
LEASENUM BLOCKNUM AREABLK

G32009 683 DC683

G32010 684 DC684

G32011 685 DC685

G31567 713 DC713

G31568 714 DC714

G34504 715 DC715

G34505 716 DC716

G32388 721 DC721

G32389 722 DC722

G32390 723 DC723

G32012 724 DC724

G32013 725 DC725

G32014 726 DC726

G32015 727 DC727

G32016 728 DC728

G32017 729 DC729

G31570 757 DC757

G31571 758 DC758

G34506 759 DC759

G34507 760 DC760

G33184 761 DC761

G32393 768 DC768

G32018 769 DC769

G32019 770 DC770

G32020 771 DC771

G32021 772 DC772

G32022 773 DC773

G31573 801 DC801

G34508 804 DC804

G33185 805 DC805

G33186 806 DC806

G32023 815 DC815

G32024 816 DC816

G32025 817 DC817

G32026 818 DC818

G32394 846 DC846

G32395 847 DC847

G33188 849 DC849

G34509 851 DC851

G34510 852 DC852

G31575 853 DC853

G31576 854 DC854

G31577 855 DC855

G34511 856 DC856

G33190 889 DC889

G33787 890 DC890
LEASENUM BLOCKNUM AREABLK

G31579 891 DC891

G31580 892 DC892

G31581 893 DC893

G31582 894 DC894

G34512 895 DC895

G34513 897 DC897

G31583 898 DC898

G31584 899 DC899

G31585 900 DC900

G33191 933 DC933

G31586 934 DC934

G31587 935 DC935

G31588 936 DC936

G31589 937 DC937

G31590 938 DC938

G31591 939 DC939

G31592 940 DC940

G34514 942 DC942

G33192 943 DC943

G33193 977 DC977

G31593 978 DC978

G31594 979 DC979

G31595 980 DC980

G33788 982 DC982

G31596 983 DC983

G31597 984 DC984

G31598 985 DC985

G33880 011 LL011

G33881 012 LL012

G31808 013 LL013

G31809 014 LL014

G31810 015 LL015

G33297 018 LL018

G33298 020 LL020

G33882 055 LL055

G33299 056 LL056

G33300 057 LL057

G33301 058 LL058

G33302 059 LL059

G31811 060 LL060

G31812 063 LL063

G31813 064 LL064

G33303 101 LL101

G33304 102 LL102

G31814 104 LL104

G31815 106 LL106
LEASENUM BLOCKNUM AREABLK

G31816 107 LL107

G31817 108 LL108

G33306 144 LL144

G33307 145 LL145

G33308 146 LL146

G31818 149 LL149

G31819 150 LL150

G31820 151 LL151

G31821 152 LL152

G33309 187 LL187

G34592 189 LL189

G34593 190 LL190

G31823 194 LL194

G31824 195 LL195

G33310 230 LL230

G33311 231 LL231

G31825 232 LL232

G34594 233 LL233

G34595 234 LL234

G31826 238 LL238

G31827 239 LL239

G31828 240 LL240

G32027 243 LL243

G32028 244 LL244

G32029 245 LL245

G31829 273 LL273

G34596 278 LL278

G32589 286 LL286

G32030 287 LL287

G32031 288 LL288

G32032 289 LL289

G31834 317 LL317

G31835 318 LL318

G31836 319 LL319

G33312 323 LL323

G33313 324 LL324

G31837 326 LL326

G32590 330 LL330

G32033 331 LL331

G32034 332 LL332

G32035 333 LL333

G31838 361 LL361

G31839 362 LL362

G31840 363 LL363

G33884 366 LL366

G31841 367 LL367
LEASENUM BLOCKNUM AREABLK

G31842 370 LL370

G31843 371 LL371

G31844 407 LL407

G31845 408 LL408

G31846 410 LL410

G31847 411 LL411

G31848 412 LL412

G31849 414 LL414

G33314 450 LL450

G33315 451 LL451

G33316 452 LL452

G31850 456 LL456

G33317 495 LL495

G31851 499 LL499

G33886 539 LL539

G33318 542 LL542

G33319 545 LL545

G33320 547 LL547

G33321 548 LL548

G33322 586 LL586

G33324 627 LL627

G33325 628 LL628

G33327 671 LL671

G33328 672 LL672

G33329 717 LL717

G33330 718 LL718
AREANAME BLOCKNUMBE LEASENUM

DE SOTO CANYON 497 G34491

DE SOTO CANYON 852 G34510

DE SOTO CANYON 853 G31575

DE SOTO CANYON 854 G31576

DE SOTO CANYON 855 G31577

DE SOTO CANYON 897 G34513

DE SOTO CANYON 898 G31583

DE SOTO CANYON 899 G31584

DE SOTO CANYON 900 G31585

DE SOTO CANYON 942 G34514

LLOYD RIDGE 13 G31808

LLOYD RIDGE 243 G32027

LLOYD RIDGE 244 G32028

LLOYD RIDGE 245 G32029

LLOYD RIDGE 286 G32589

LLOYD RIDGE 287 G32030

LLOYD RIDGE 289 G32032

LLOYD RIDGE 317 G31834

LLOYD RIDGE 318 G31835

LLOYD RIDGE 330 G32590

LLOYD RIDGE 331 G32033

LLOYD RIDGE 332 G32034

LLOYD RIDGE 361 G31838

LLOYD RIDGE 362 G31839

LLOYD RIDGE 410 G31846

LLOYD RIDGE 539 G33886
Anadarko Petroleum Corporation Trinity Consultants 

APPENDIX D: MODEL INPUT PARAMETERS 

	 	
28.60 1.100 20.30 593

1

Stack parameters were based on the proposed stack parameters of the main engines, which are the highest emitting emission 

source on the proposed drillship. Stack parameters were obtained from the RFI sent to Anadarko dated 09/06/2012. The stack 

velocity was estimated at 50% operating load based on email from Ms. Sara Carlson (Anadarko) to Mr. Rahul Pendse (Trinity) 

on 09/10/2012.

Anadarko Petroleum Corporation

Drillship Stack Parameters1

Stack Height 

(m)

Stack Inside Diameter 

(m)

Stack Gas Exit Velocity

(m/sec)

Stack Gas Temperature 

(K)

Anadarko Petroleum Corporation

Air quality Modeling Analysis 1 of 16

Class I_Model Input Parameters v1.2 - DS Stack Input Parameters

8/24/2013
5.00 0.706 0.64 293

Anadarko Petroleum Corporation

SuppO\%RDW Stack Parameters 1

Stack Height 

(m)

Stack Inside Diameter 

(m)

Stack Gas Exit Velocity

(m/sec)

Stack Gas Temperature 

(K)

1Based on the stack parameters of Kirk Chouest.

Anadarko Petroleum Corporation

Air quality Modeling Analysis 2 of 16

Class I_Model Input Parameters v1.2 - SV Stack Input Parameters

8/24/2013
Anadarko Petroleum Corporation Trinity Consultants 

APPENDIX D1: CLASS I MODEL INPUT PARAMETERS 
Reference latitude: 40 deg

Reference longitude: 97 deg (based on + Western Hemisphere)

Standard parallel #1: 33 deg

Standard parallel #2: 45 deg

Latitude (deg)

(North)

Longitude (deg)

(West)

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

For Breton NWR 28.85 87.52 930.28 -1189.81

For St. Marks NWR and 

Bradwell Bay Wilderness 28.85 87.08 973.83 -1185.04

Class I Area Distance (km) 2

For Breton NWR 167

For St. Marks NWR 285

For Bradwell Bay Wilderness 281

2

 Represents the distance to the closest receptor on each Class I area. Coordinates for receptors on the Class I areas were obtained from the National Park 

Service (NPS) Air Resources Division (ARD) website at - http://www2.nature.nps.gov/air/maps/Receptors/index.htm

Anadarko Petroleum Corporation

LCC Reference Parameters ¥

¥ Based on the model design used by Visibility Improvement State and Tribal Association of the Southeast (VISTAS) for Regional Haze Rule modeling - 

Protocol for the Application of the CALPUFF Model for Analyses of Best Available Retrofit Technology (BART), December 22, 2005, revised August 31, 

2006.

Worksheet for Converting Latitude and Longitude to Lambert Conformal Projection Coordinates

Class I Area

Worst-case Drillship Location 1

1

 Represents the worst-case location within the lease block drilling area with respect to each Class I area. 

Anadarko Petroleum Corporation

Air quality Modeling Analysis Page 3 of 16

Class I_Model Input Parameters v1.2-Coordinate Conversion (LCC) DS

8/24/2013
Reference latitude: 40 deg

Reference longitude: 97 deg (based on + Western Hemisphere)

Standard parallel #1: 33 deg

Standard parallel #2: 45 deg

Latitude (deg) Longitude (deg) LCC Coordin

X (km) 

25 miles from nearest state seaward boundary 29.24 87.54 925.58 

St.Marks and Bradwell Bay Wilderness 29.22 86.95 983.64 

Receptor Distance (km) 2

25 miles from nearest shoreline 48.60

St.Marks and Bradwell Bay Wilderness 55.07

1 Represents the worst-case supply boat location with respect to closest receptor. 2 Represents the distance to the closest receptor. Coordinates for receptors on the Class II areas were obtained from EPA Reg

Anadarko Petroleum Corporation

Worksheet for Converting Latitude and Longitude to Lambert Conformal Projection C

LCC Reference Parameters ¥

¥ Based on the model design used by Visibility Improvement State and Tribal Association of the Southeast (VISTAS) for Reg

Protocol for the Application of the CALPUFF Model for Analyses of Best Available Retrofit Technology (BART), December 2006.

Receptor

Worst-case Supply Boat Location 1

 Anadarko Petroleum Corporation Air quality Modeling Analysis 1 of 1

 Class I_Modeling Inputs Parameters v1.
Source Location LCC X LCC Y

Drillship Location 930.28 -1189.81

Computational Domain Setup - STEP 1 LCC X LCC Y

Northernmost Point -1068.61

Southernmost Point -1189.81

Westernmost Point 777.71

Easternmost Point 930.28

Computational Domain Setup - STEP 2 (based on +/- 50 km) LCC X LCC Y

SW 727.71 -1239.81

NW 727.71 -1018.61

NE 980.28 -1018.61

SE 980.28 -1239.81

Computational Domain Setup - STEP 3 (rounded w/ 4 km spacing) LCC X LCC Y

SW 725.995 -1242.0

NW 725.995 -1018.0

NE 981.995 -1018.0

SE 981.995 -1242.0

Distance Span 256 224

Grid Spacing 4 4

Number of Cells 64 56

VISTAS Domain 2 (Meteorological Domain) SW corner LCC X LCC Y (Fixed)

Meteorological Grid Origin Coordinates 721.995 -1598.0

Computational Grid Settings Cells X Cells Y (Enter these grid settings into CALPUFF).

SW 1 89

NE 65 145

Grid Spacing 4 4

Number of Cells (Check) 64 56

(Extends domain to 50 km further beyond the source and receptors 

for conservatism).

Anadarko Petroleum Corporation

Breton NWR - Computational Domain Grid Setup

(Used Max/ Min of Class I area receptor coordinates and source 

coordinates to ensure the domain included the source as well as all 

receptors).

(Domain endpoint coordinates moved further out to coincide with the 

grid point locations of the meteorological domain (at grid spacing of 

4 Km)

Anadarko Petroleum Corporation

Air quality Modeling Analysis Page 5 of 16

Class I_Model Input Parameters v1.2-Breton - Computational Domain

8/24/2013
Source Location LCC X LCC Y

Drillship Location 973.83 -1185.04

Computational Domain Setup - STEP 1 LCC X LCC Y

Northernmost Point -1001.70

Southernmost Point -1185.04

Westernmost Point 973.83

Easternmost Point 1256.44

Computational Domain Setup - STEP 2 (based on +/- 50 km) LCC X LCC Y

SW 923.83 -1235.04

NW 923.83 -951.70

NE 1306.44 -951.70

SE 1306.44 -1235.04

Computational Domain Setup - STEP 3 (rounded w/ 4 km spacing) LCC X LCC Y

SW 921.995 -1238.0

NW 921.995 -950.0

NE 1309.995 -950.0

SE 1309.995 -1238.0

Distance Span 388 288

Grid Spacing 4 4

Number of Cells 97 72

VISTAS Domain 2 (Meteorological Domain) SW corner LCC X LCC Y (Fixed)

Meteorological Grid Origin Coordinates 721.995 -1598.0

Computational Grid Settings Cells X Cells Y (Enter these grid settings into CALPUFF).

SW 50 90

NE 147 162

Grid Spacing 4 4

Number of Cells (Check) 97 72

(Domain endpoint coordinates moved further out to coincide with the 

grid point locations of the meteorological domain (at grid spacing of 

4 Km)

Anadarko Petroleum Corporation

St. Marks NWR and Bradwell Bay Wilderness - Computational Domain Grid Setup

(Extends domain to 50 km further beyond the source and receptors 

for conservatism).

(Used Max/ Min of Class I area receptor coordinates and source 

coordinates to ensure the domain included the source as well as all 

receptors).

Anadarko Petroleum Corporation

Air quality Modeling Analysis Page 6 of 16

Class I_Model Input Parameters v1.2-St Mark & BrBay - Comput Domain

8/24/2013
Receptor Id. Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Bret1 29.621 89.004 777.710 -1118.013 0.0 0.0 168.62

Bret2 29.637 88.979 779.971 -1115.939 0.0 0.0 167.48

Bret3 29.646 88.971 780.697 -1114.937 0.0 0.0 167.28

Bret4 29.654 88.963 781.423 -1113.936 0.0 0.0 167.08

Bret5 29.721 88.913 785.607 -1106.067 0.0 0.0 167.16

Bret6 29.762 88.871 789.227 -1101.058 0.0 0.0 166.65

Bret7 29.787 88.863 789.783 -1098.197 0.0 0.0 167.73

Bret8 29.804 88.846 791.229 -1096.193 1.0 0.0 167.63

Bret9 29.812 88.846 791.146 -1095.264 1.0 0.0 168.22

Bret10 29.829 88.838 791.785 -1093.333 1.0 0.0 168.79

Bret11 29.837 88.838 791.701 -1092.404 1.0 0.0 169.39

Bret12 29.854 88.829 792.340 -1090.472 1.0 0.0 169.99

Bret13 29.862 88.829 792.256 -1089.543 1.0 0.0 170.60

Bret14 29.871 88.829 792.172 -1088.614 1.0 0.0 171.22

Bret15 29.879 88.829 792.088 -1087.685 1.0 0.0 171.83

Bret16 29.887 88.829 792.005 -1086.756 0.0 0.0 172.45

Bret17 29.896 88.829 791.921 -1085.827 0.0 0.0 173.08

Bret18 29.912 88.829 791.753 -1083.968 0.0 0.0 174.33

Bret19 29.912 88.821 792.559 -1083.896 1.0 0.0 173.74

Bret20 29.921 88.821 792.475 -1082.967 1.0 0.0 174.37

Bret21 29.929 88.829 791.586 -1082.110 0.0 0.0 175.60

Bret22 29.929 88.821 792.391 -1082.038 1.0 0.0 175.01

Bret23 29.937 88.829 791.502 -1081.181 0.0 0.0 176.24

Bret24 29.937 88.821 792.307 -1081.109 1.0 0.0 175.65

Bret25 29.946 88.829 791.418 -1080.252 1.0 0.0 176.88

Bret26 29.954 88.829 791.335 -1079.323 1.0 0.0 177.52

Bret27 29.962 88.838 790.446 -1078.467 0.0 0.0 178.75

Bret28 29.962 88.829 791.251 -1078.394 1.0 0.0 178.17

Bret29 29.971 88.838 790.362 -1077.538 0.0 0.0 179.39

Bret30 29.971 88.829 791.167 -1077.465 1.0 0.0 178.81

Bret31 29.979 88.838 790.279 -1076.609 0.0 0.0 180.04

Bret32 29.987 88.838 790.195 -1075.680 0.0 0.0 180.69

Bret33 29.996 88.838 790.111 -1074.751 1.0 0.0 181.35

Bret34 30.004 88.846 789.223 -1073.894 0.0 0.0 182.58

Bret35 30.012 88.846 789.140 -1072.966 0.0 0.0 183.23

Bret36 30.021 88.854 788.252 -1072.109 0.0 0.0 184.46

Bret37 30.029 88.854 788.168 -1071.180 1.0 0.0 185.12

Bret38 30.037 88.863 787.281 -1070.324 0.0 0.0 186.35

Bret39 30.046 88.871 786.393 -1069.467 0.0 0.0 187.58

Bret40 30.054 88.879 785.506 -1068.610 0.0 0.0 188.81

Breton National Wildlife Refuge - Receptor Information

1

 Lat/ Long coordinates and elevation for receptors on the Class I area were obtained from the National Park Service (NPS) Air Resources Division (ARD) website 

at - http://www2.nature.nps.gov/air/maps/Receptors/index.htm

Anadarko Petroleum Corporation

Anadarko Petroleum Corporation

Air quality Modeling Analysis Page 7 of 16

Class I_Model Input Parameters v1.2-Breton Receptors

8/24/2013
Receptor Id.

Latitude (deg),

(North) 1

Longitude (deg),

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Stm1 29.979 84.454 1212.440 -1028.300 1.0 0.0 285.49

Stm2 29.979 84.438 1214.040 -1028.077 1.0 0.0 286.95

Stm3 29.987 84.454 1212.312 -1027.376 1.0 0.0 285.89

Stm4 29.987 84.446 1213.112 -1027.265 1.0 0.0 286.62

Stm5 29.996 84.454 1212.183 -1026.452 1.0 0.0 286.29

Stm6 29.996 84.446 1212.983 -1026.341 1.0 0.0 287.02

Stm7 30.004 84.471 1210.455 -1025.751 1.0 0.0 285.24

Stm8 30.004 84.463 1211.255 -1025.640 1.0 0.0 285.97

Stm9 30.004 84.454 1212.055 -1025.529 1.0 0.0 286.70

Stm10 30.004 84.446 1212.855 -1025.417 1.0 0.0 287.42

Stm11 30.012 84.463 1211.127 -1024.716 1.0 0.0 286.38

Stm12 30.079 84.179 1237.268 -1013.511 1.0 0.0 314.36

Stm13 30.079 84.171 1238.067 -1013.398 1.0 0.0 315.09

Stm14 30.079 84.163 1238.866 -1013.284 1.0 0.0 315.82

Stm15 30.079 84.154 1239.665 -1013.171 0.0 0.0 316.56

Stm16 30.079 83.979 1256.438 -1010.767 1.0 0.0 332.02

Stm17 30.087 84.179 1237.137 -1012.588 0.0 0.0 314.75

Stm18 30.087 84.171 1237.936 -1012.475 1.0 0.0 315.49

Stm19 30.087 84.154 1239.533 -1012.248 1.0 0.0 316.95

Stm20 30.087 84.146 1240.332 -1012.134 1.0 0.0 317.68

Stm21 30.087 83.979 1256.305 -1009.845 1.0 0.0 332.39

Stm22 30.096 84.171 1237.805 -1011.552 1.0 0.0 315.88

Stm23 30.096 84.146 1240.201 -1011.211 1.0 0.0 318.07

Stm24 30.096 84.138 1240.999 -1011.097 1.0 0.0 318.80

Stm25 30.096 84.129 1241.798 -1010.983 1.0 0.0 319.54

Stm26 30.096 84.113 1243.395 -1010.755 1.0 0.0 321.00

Stm27 30.096 84.104 1244.194 -1010.641 1.0 0.0 321.73

Stm28 30.096 84.088 1245.791 -1010.413 0.0 0.0 323.20

Stm29 30.096 84.079 1246.589 -1010.299 0.0 0.0 323.93

Stm30 30.096 83.996 1254.575 -1009.152 1.0 0.0 331.29

Stm31 30.096 83.979 1256.171 -1008.922 1.0 0.0 332.77

Stm32 30.104 84.196 1235.278 -1010.969 0.0 0.0 314.10

Stm33 30.104 84.188 1236.076 -1010.855 1.0 0.0 314.82

Stm34 30.104 84.179 1236.875 -1010.742 1.0 0.0 315.55

Stm35 30.104 84.171 1237.673 -1010.629 1.0 0.0 316.28

Stm36 30.104 84.163 1238.472 -1010.515 1.0 0.0 317.01

Stm37 30.104 84.146 1240.069 -1010.288 1.0 0.0 318.47

Stm38 30.104 84.138 1240.868 -1010.174 1.0 0.0 319.20

Stm39 30.104 84.129 1241.666 -1010.060 1.0 0.0 319.93

Stm40 30.104 84.121 1242.465 -1009.946 1.0 0.0 320.66

Stm41 30.104 84.113 1243.263 -1009.832 1.0 0.0 321.39

Stm42 30.104 84.096 1244.860 -1009.604 1.0 0.0 322.86

Stm43 30.104 84.088 1245.659 -1009.490 1.0 0.0 323.59

Stm44 30.104 84.079 1246.457 -1009.376 1.0 0.0 324.32

Stm45 30.104 84.071 1247.256 -1009.261 1.0 0.0 325.05

Anadarko Petroleum Corporation

St. Marks National Wildlife Refuge - Receptor Information

Anadarko Petroleum Corporation

Air quality Modeling Analysis Page 8 of 16

Class I_Model Input Parameters v1.2-St. Marks Receptors

8/24/2013
Receptor Id.

Latitude (deg),

(North) 1

Longitude (deg),

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Anadarko Petroleum Corporation

St. Marks National Wildlife Refuge - Receptor Information

Stm46 30.104 84.063 1248.054 -1009.147 1.0 0.0 325.79

Stm47 30.104 84.054 1248.853 -1009.032 0.0 0.0 326.52

Stm48 30.104 84.046 1249.651 -1008.918 0.0 0.0 327.26

Stm49 30.104 84.038 1250.450 -1008.803 0.0 0.0 327.99

Stm50 30.104 84.029 1251.248 -1008.689 0.0 0.0 328.73

Stm51 30.104 84.021 1252.046 -1008.574 0.0 0.0 329.46

Stm52 30.104 84.013 1252.845 -1008.459 1.0 0.0 330.20

Stm53 30.104 84.004 1253.643 -1008.344 1.0 0.0 330.93

Stm54 30.104 83.996 1254.442 -1008.229 1.0 0.0 331.67

Stm55 30.104 83.988 1255.240 -1008.114 1.0 0.0 332.41

Stm56 30.112 84.196 1235.147 -1010.046 1.0 0.0 314.50

Stm57 30.112 84.188 1235.945 -1009.932 1.0 0.0 315.23

Stm58 30.112 84.179 1236.744 -1009.819 1.0 0.0 315.95

Stm59 30.112 84.171 1237.542 -1009.705 1.0 0.0 316.68

Stm60 30.112 84.163 1238.341 -1009.592 1.0 0.0 317.41

Stm61 30.112 84.138 1240.736 -1009.251 1.0 0.0 319.59

Stm62 30.112 84.129 1241.535 -1009.137 2.0 0.0 320.33

Stm63 30.112 84.063 1247.922 -1008.224 2.0 0.0 326.18

Stm64 30.112 84.054 1248.720 -1008.110 1.0 0.0 326.91

Stm65 30.112 84.046 1249.519 -1007.995 1.0 0.0 327.64

Stm66 30.112 84.038 1250.317 -1007.880 1.0 0.0 328.38

Stm67 30.112 84.029 1251.115 -1007.766 1.0 0.0 329.11

Stm68 30.112 84.021 1251.914 -1007.651 1.0 0.0 329.85

Stm69 30.112 84.013 1252.712 -1007.536 1.0 0.0 330.58

Stm70 30.112 84.004 1253.510 -1007.421 1.0 0.0 331.32

Stm71 30.112 83.996 1254.309 -1007.306 1.0 0.0 332.05

Stm72 30.112 83.988 1255.107 -1007.191 1.0 0.0 332.79

Stm73 30.121 84.196 1235.016 -1009.122 1.0 0.0 314.91

Stm74 30.121 84.188 1235.814 -1009.009 2.0 0.0 315.63

Stm75 30.121 84.179 1236.613 -1008.896 3.0 0.0 316.36

Stm76 30.121 84.171 1237.411 -1008.782 2.0 0.0 317.08

Stm77 30.121 84.163 1238.209 -1008.669 1.0 0.0 317.81

Stm78 30.121 84.154 1239.008 -1008.555 1.0 0.0 318.54

Stm79 30.121 84.021 1251.781 -1006.728 2.0 0.0 330.23

Stm80 30.121 84.013 1252.579 -1006.613 3.0 0.0 330.96

Stm81 30.121 84.004 1253.377 -1006.498 3.0 0.0 331.70

Stm82 30.121 83.996 1254.176 -1006.383 2.0 0.0 332.43

Stm83 30.121 83.988 1254.974 -1006.268 2.0 0.0 333.17

Stm84 30.121 83.979 1255.772 -1006.153 3.0 0.0 333.90

Stm85 30.129 84.204 1234.086 -1008.313 1.0 0.0 314.59

Stm86 30.129 84.196 1234.885 -1008.199 1.0 0.0 315.31

Stm87 30.129 84.188 1235.683 -1008.086 2.0 0.0 316.04

Stm88 30.129 84.179 1236.481 -1007.973 2.0 0.0 316.76

Stm89 30.129 84.013 1252.446 -1005.690 3.0 0.0 331.35

Stm90 30.129 84.004 1253.245 -1005.576 2.0 0.0 332.09

Anadarko Petroleum Corporation

Air quality Modeling Analysis Page 9 of 16

Class I_Model Input Parameters v1.2-St. Marks Receptors

8/24/2013
Receptor Id.

Latitude (deg),

(North) 1

Longitude (deg),

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Anadarko Petroleum Corporation

St. Marks National Wildlife Refuge - Receptor Information

Stm91 30.129 83.996 1254.043 -1005.461 3.0 0.0 332.82

Stm92 30.129 83.988 1254.841 -1005.346 3.0 0.0 333.55

Stm93 30.129 83.979 1255.639 -1005.230 3.0 0.0 334.29

Stm94 30.137 84.204 1233.955 -1007.389 1.0 0.0 315.00

Stm95 30.137 84.196 1234.754 -1007.276 1.0 0.0 315.72

Stm96 30.137 83.996 1253.910 -1004.538 3.0 0.0 333.21

Stm97 30.137 83.988 1254.708 -1004.423 3.0 0.0 333.94

Stm98 30.137 83.979 1255.506 -1004.308 3.0 0.0 334.67

Stm99 30.146 84.204 1233.825 -1006.466 1.0 0.0 315.41

Stm100 30.146 84.196 1234.623 -1006.353 1.0 0.0 316.14

Stm101 30.154 84.196 1234.492 -1005.430 1.0 0.0 316.55

1

 Lat/ Long coordinates and elevation for receptors on the Class I area were obtained from the National Park Service (NPS) Air Resources Division (ARD) website at - 

http://www2.nature.nps.gov/air/maps/Receptors/index.htm

Anadarko Petroleum Corporation

Air quality Modeling Analysis Page 10 of 16

Class I_Model Input Parameters v1.2-St. Marks Receptors

8/24/2013
Receptor Id.

Latitude (deg),

(North) 1

Longitude (deg),

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Bbay1 30.113 84.571 1199.202 -1015.068 14.0 0.0 282.28

Bbay2 30.121 84.579 1198.276 -1014.254 14.0 0.0 282.04

Bbay3 30.121 84.571 1199.075 -1014.145 15.0 0.0 282.74

Bbay4 30.121 84.563 1199.873 -1014.035 14.0 0.0 283.44

Bbay5 30.121 84.546 1201.471 -1013.814 15.0 0.0 284.85

Bbay6 30.129 84.596 1196.551 -1013.550 16.0 0.0 281.09

Bbay7 30.129 84.588 1197.350 -1013.441 15.0 0.0 281.79

Bbay8 30.129 84.579 1198.149 -1013.331 15.0 0.0 282.49

Bbay9 30.129 84.571 1198.947 -1013.221 15.0 0.0 283.20

Bbay10 30.129 84.563 1199.746 -1013.111 15.0 0.0 283.90

Bbay11 30.129 84.554 1200.545 -1013.001 17.0 0.0 284.60

Bbay12 30.129 84.546 1201.344 -1012.891 16.0 0.0 285.30

Bbay13 30.138 84.604 1195.625 -1012.736 18.0 0.0 280.86

Bbay14 30.138 84.596 1196.424 -1012.627 17.0 0.0 281.56

Bbay15 30.138 84.588 1197.223 -1012.517 17.0 0.0 282.26

Bbay16 30.138 84.579 1198.022 -1012.407 17.0 0.0 282.96

Bbay17 30.138 84.571 1198.820 -1012.297 17.0 0.0 283.66

Bbay18 30.138 84.563 1199.619 -1012.187 17.0 0.0 284.36

Bbay19 30.138 84.554 1200.418 -1012.077 18.0 0.0 285.06

Bbay20 30.138 84.546 1201.217 -1011.967 17.0 0.0 285.76

Bbay21 30.146 84.604 1195.498 -1011.813 17.0 0.0 281.33

Bbay22 30.146 84.596 1196.297 -1011.703 17.0 0.0 282.02

Bbay23 30.146 84.588 1197.096 -1011.593 18.0 0.0 282.72

Bbay24 30.146 84.579 1197.895 -1011.484 18.0 0.0 283.42

Bbay25 30.146 84.571 1198.693 -1011.374 17.0 0.0 284.12

Bbay26 30.146 84.563 1199.492 -1011.264 17.0 0.0 284.82

Bbay27 30.146 84.554 1200.291 -1011.154 15.0 0.0 285.52

Bbay28 30.154 84.613 1194.573 -1010.999 18.0 0.0 281.10

Bbay29 30.154 84.604 1195.372 -1010.889 17.0 0.0 281.80

Bbay30 30.154 84.596 1196.170 -1010.780 17.0 0.0 282.49

Bbay31 30.154 84.588 1196.969 -1010.670 17.0 0.0 283.19

Bbay32 30.154 84.579 1197.768 -1010.560 17.0 0.0 283.89

Bbay33 30.154 84.571 1198.566 -1010.450 18.0 0.0 284.58

Bbay34 30.154 84.563 1199.365 -1010.340 16.0 0.0 285.28

Bbay35 30.154 84.554 1200.163 -1010.230 15.0 0.0 285.98

Bbay36 30.154 84.546 1200.962 -1010.120 15.0 0.0 286.68

Bbay37 30.154 84.538 1201.760 -1010.010 15.0 0.0 287.38

Bbay38 30.154 84.529 1202.559 -1009.900 14.0 0.0 288.08

Bbay39 30.163 84.604 1195.245 -1009.966 17.0 0.0 282.27

Bbay40 30.163 84.596 1196.043 -1009.856 17.0 0.0 282.96

Bbay41 30.163 84.588 1196.842 -1009.746 18.0 0.0 283.66

Bbay42 30.163 84.579 1197.641 -1009.636 17.0 0.0 284.36

Bbay43 30.163 84.571 1198.439 -1009.527 17.0 0.0 285.05

Bbay44 30.163 84.563 1199.238 -1009.417 17.0 0.0 285.75

Bbay45 30.163 84.554 1200.036 -1009.307 17.0 0.0 286.45

Bbay46 30.163 84.546 1200.834 -1009.197 16.0 0.0 287.14

Bbay47 30.163 84.538 1201.633 -1009.086 15.0 0.0 287.84

Bbay48 30.163 84.529 1202.431 -1008.976 15.0 0.0 288.54

Bbay49 30.163 84.521 1203.230 -1008.866 12.0 0.0 289.24

Bbay50 30.171 84.613 1194.320 -1009.152 17.0 0.0 282.05

Bbay51 30.171 84.604 1195.118 -1009.042 18.0 0.0 282.74

Bbay52 30.171 84.596 1195.917 -1008.932 17.0 0.0 283.44

Anadarko Petroleum Corporation

Bradwell Bay Wilderness - Receptor Information

Anadarko Petroleum Corporation

Air quality Modeling Analysis Page 11 of 16

Class I_Model Input Parameters v1.2-Bradwell Bay Receptors

8/24/2013
Receptor Id.

Latitude (deg),

(North) 1

Longitude (deg),

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Anadarko Petroleum Corporation

Bradwell Bay Wilderness - Receptor Information

Bbay53 30.171 84.588 1196.715 -1008.823 18.0 0.0 284.13

Bbay54 30.171 84.579 1197.513 -1008.713 17.0 0.0 284.83

Bbay55 30.171 84.571 1198.312 -1008.603 17.0 0.0 285.52

Bbay56 30.171 84.563 1199.110 -1008.493 17.0 0.0 286.22

Bbay57 30.171 84.554 1199.909 -1008.383 18.0 0.0 286.91

Bbay58 30.171 84.546 1200.707 -1008.273 17.0 0.0 287.61

Bbay59 30.171 84.538 1201.505 -1008.163 17.0 0.0 288.31

Bbay60 30.171 84.529 1202.304 -1008.053 15.0 0.0 289.01

Bbay61 30.171 84.521 1203.102 -1007.942 14.0 0.0 289.71

Bbay62 30.171 84.513 1203.901 -1007.832 14.0 0.0 290.41

Bbay63 30.171 84.504 1204.699 -1007.722 12.0 0.0 291.11

Bbay64 30.179 84.621 1193.395 -1008.337 17.0 0.0 281.84

Bbay65 30.179 84.613 1194.193 -1008.228 17.0 0.0 282.53

Bbay66 30.179 84.604 1194.991 -1008.118 17.0 0.0 283.22

Bbay67 30.179 84.596 1195.790 -1008.009 18.0 0.0 283.91

Bbay68 30.179 84.588 1196.588 -1007.899 17.0 0.0 284.61

Bbay69 30.179 84.579 1197.386 -1007.789 17.0 0.0 285.30

Bbay70 30.179 84.571 1198.185 -1007.680 18.0 0.0 285.99

Bbay71 30.179 84.563 1198.983 -1007.570 17.0 0.0 286.69

Bbay72 30.179 84.554 1199.781 -1007.460 17.0 0.0 287.38

Bbay73 30.179 84.546 1200.580 -1007.350 17.0 0.0 288.08

Bbay74 30.179 84.538 1201.378 -1007.239 17.0 0.0 288.78

Bbay75 30.179 84.529 1202.176 -1007.129 17.0 0.0 289.47

Bbay76 30.179 84.521 1202.975 -1007.019 15.0 0.0 290.17

Bbay77 30.179 84.513 1203.773 -1006.909 14.0 0.0 290.87

Bbay78 30.179 84.504 1204.571 -1006.798 12.0 0.0 291.57

Bbay79 30.188 84.621 1193.268 -1007.414 15.0 0.0 282.32

Bbay80 30.188 84.613 1194.066 -1007.304 16.0 0.0 283.01

Bbay81 30.188 84.604 1194.865 -1007.195 18.0 0.0 283.70

Bbay82 30.188 84.596 1195.663 -1007.085 17.0 0.0 284.39

Bbay83 30.188 84.588 1196.461 -1006.976 17.0 0.0 285.08

Bbay84 30.188 84.579 1197.259 -1006.866 18.0 0.0 285.77

Bbay85 30.188 84.571 1198.058 -1006.756 17.0 0.0 286.47

Bbay86 30.188 84.563 1198.856 -1006.646 17.0 0.0 287.16

Bbay87 30.188 84.554 1199.654 -1006.536 17.0 0.0 287.85

Bbay88 30.188 84.546 1200.452 -1006.426 17.0 0.0 288.55

Bbay89 30.188 84.538 1201.251 -1006.316 17.0 0.0 289.24

Bbay90 30.188 84.529 1202.049 -1006.206 17.0 0.0 289.94

Bbay91 30.188 84.521 1202.847 -1006.096 16.0 0.0 290.64

Bbay92 30.188 84.513 1203.645 -1005.985 15.0 0.0 291.33

Bbay93 30.188 84.504 1204.443 -1005.875 14.0 0.0 292.03

Bbay94 30.196 84.621 1193.141 -1006.490 21.0 0.0 282.80

Bbay95 30.196 84.613 1193.940 -1006.381 18.0 0.0 283.49

Bbay96 30.196 84.604 1194.738 -1006.271 16.0 0.0 284.18

Bbay97 30.196 84.596 1195.536 -1006.162 17.0 0.0 284.87

Bbay98 30.196 84.588 1196.334 -1006.052 18.0 0.0 285.56

Bbay99 30.196 84.579 1197.132 -1005.942 17.0 0.0 286.25

Bbay100 30.196 84.571 1197.931 -1005.833 17.0 0.0 286.94

Bbay101 30.196 84.563 1198.729 -1005.723 18.0 0.0 287.64

Bbay102 30.196 84.554 1199.527 -1005.613 17.0 0.0 288.33

Bbay103 30.196 84.546 1200.325 -1005.503 17.0 0.0 289.02

Bbay104 30.196 84.538 1201.123 -1005.393 17.0 0.0 289.72

Anadarko Petroleum Corporation

Air quality Modeling Analysis Page 12 of 16

Class I_Model Input Parameters v1.2-Bradwell Bay Receptors

8/24/2013
Receptor Id.

Latitude (deg),

(North) 1

Longitude (deg),

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Anadarko Petroleum Corporation

Bradwell Bay Wilderness - Receptor Information

Bbay105 30.196 84.529 1201.921 -1005.282 16.0 0.0 290.41

Bbay106 30.196 84.521 1202.719 -1005.172 15.0 0.0 291.11

Bbay107 30.196 84.513 1203.517 -1005.062 14.0 0.0 291.80

Bbay108 30.204 84.613 1193.813 -1005.457 23.0 0.0 283.98

Bbay109 30.204 84.604 1194.611 -1005.348 22.0 0.0 284.66

Bbay110 30.204 84.596 1195.409 -1005.238 19.0 0.0 285.35

Bbay111 30.204 84.588 1196.207 -1005.129 17.0 0.0 286.04

Bbay112 30.204 84.579 1197.005 -1005.019 17.0 0.0 286.73

Bbay113 30.204 84.571 1197.804 -1004.909 17.0 0.0 287.42

Bbay114 30.204 84.563 1198.602 -1004.799 17.0 0.0 288.11

Bbay115 30.204 84.554 1199.400 -1004.689 17.0 0.0 288.80

Bbay116 30.204 84.546 1200.198 -1004.579 17.0 0.0 289.50

Bbay117 30.204 84.538 1200.996 -1004.469 16.0 0.0 290.19

Bbay118 30.204 84.529 1201.794 -1004.359 15.0 0.0 290.88

Bbay119 30.204 84.521 1202.592 -1004.249 15.0 0.0 291.58

Bbay120 30.213 84.588 1196.080 -1004.205 22.0 0.0 286.52

Bbay121 30.213 84.579 1196.878 -1004.096 21.0 0.0 287.21

Bbay122 30.213 84.571 1197.676 -1003.986 19.0 0.0 287.90

Bbay123 30.213 84.563 1198.474 -1003.876 18.0 0.0 288.59

Bbay124 30.213 84.554 1199.272 -1003.766 18.0 0.0 289.28

Bbay125 30.213 84.546 1200.070 -1003.656 17.0 0.0 289.97

Bbay126 30.213 84.538 1200.868 -1003.546 15.0 0.0 290.67

Bbay127 30.213 84.529 1201.666 -1003.436 15.0 0.0 291.36

Bbay128 30.221 84.563 1198.347 -1002.952 22.0 0.0 289.07

Bbay129 30.221 84.554 1199.145 -1002.843 19.0 0.0 289.76

Bbay130 30.221 84.546 1199.943 -1002.733 17.0 0.0 290.45

Bbay131 30.221 84.538 1200.741 -1002.622 15.0 0.0 291.14

Bbay132 30.229 84.538 1200.613 -1001.699 15.0 0.0 291.62

1

 Lat/ Long coordinates and elevation for receptors on the Class I area were obtained from the National Park Service (NPS) Air Resources Division (ARD) website at - 

http://www2.nature.nps.gov/air/maps/Receptors/index.htm

Anadarko Petroleum Corporation

Air quality Modeling Analysis Page 13 of 16

Class I_Model Input Parameters v1.2-Bradwell Bay Receptors

8/24/2013
Emissions Speciation Percentage 

(% of Total PM10) 

 Actual Emissions 

(Max. lb/hr) Reference

Total PM10 (TPM10) 100% 27.00 1

Condensable portion of TPM10 (CPM) 13.4% 3.63 2

Organic portion of CPM (SOA) 13.4% 3.63 3

Inorganic portion of CPM 0.0% 0.00 3

Filterable portion of TPM10 (FPM10) 86.6% 23.37 2

Coarse Filterable (PMC) 3.0% 0.80 4

Fine Filterable (PMF) 83.6% 22.57 2

Elemental Carbon (EC) 0.0% 0.00 5

5. Elemental Carbon has been assumed to be 0% due to lack of representative data or emission factors.

4. The percentage of Coarse filterable (PMC) in TPM10 was calculated as the difference between the percentages of 

FPM10 and Fine Filterable (PMF).

Anadarko Petroleum Corporation

Drilling Operation - Particulate Emissions Speciation

1. Total PM10 (TPM10) emissions from the MODU was calculated as the sum total of TPM10 emissions from all 

emission sources, which primarily comprise of diesel-fired engines. TPM10 emissions for the individual emission 

sources were calculated as the sum of filterable PM10 (FPM10) emissions and condensable particulate emissions 

(CPM).

2. AP-42, Table 3.4-2 Particulate and Particle-sizing Emission Factors for Large Uncontrolled Stationary Diesel 

Engines was used to speciate TPM10 into FPM10 and CPM. Filterable particulate < 3 um was used as a surrogate for 

PMF/ Filterable PM2.5. 

3. No representative data or emission factors were available for determining inorganic (SO4 and NO3) condensable 

emissions. Per AP-42, Table 3.4-1 Gaseous Emission Factors for Large Stationary Diesel and All Stationary DualFuel Engines, footnote d, all sulfur in the fuel is assumed to be converted to SO2

. Therefore, inorganic condensable 

emissions from the MODU were assumed to be zero. Based on guidance provided in Procedure for Speciation of 

Emissions for VISTAS BART Modeling, July 18, 2006, 100% of non-H2SO4 condensable mass was assumed to be 

organic condensables (SOA).

Anadarko Petroleum Corporation

Air quality Modeling Analysis Page 14 of 16

Class I_Model Input Parameters v1.2-Drilling - PM Speciation

8/24/2013
Emissions Speciation Percentage 

(% of Total PM10) 

 Actual Emissions 

(Max. lb/hr) Reference

Total PM10 (TPM10) 100% 3.00 1

Condensable portion of TPM10 (CPM) 13.4% 0.40 2

Organic portion of CPM (SOA) 13.4% 0.40 3

Inorganic portion of CPM 0.0% 0.00 3

Filterable portion of TPM10 (FPM10) 86.6% 2.60 2

Coarse Filterable (PMC) 3.0% 0.09 4

Fine Filterable (PMF) 83.6% 2.51 2

Elemental Carbon (EC) 0.0% 0.00 5

5. Elemental Carbon has been assumed to be 0% due to lack of representative data or emission factors.

4. The percentage of Coarse filterable (PMC) in TPM10 was calculated as the difference between the percentages of 

FPM10 and Fine Filterable (PMF).

Anadarko Petroleum Corporation

SuppO\%RDW - Particulate Emissions Speciation

1. Total PM10 (TPM10) emissions from the MODU was calculated as the sum total of TPM10 emissions from all 

emission sources, which primarily comprise of diesel-fired engines. TPM10 emissions for the individual emission 

sources were calculated as the sum of filterable PM10 (FPM10) emissions and condensable particulate emissions 

(CPM).

2. AP-42, Table 3.4-2 Particulate and Particle-sizing Emission Factors for Large Uncontrolled Stationary Diesel 

Engines was used to speciate TPM10 into FPM10 and CPM. Filterable particulate < 3 um was used as a surrogate for 

PMF/ Filterable PM2.5. 

3. No representative data or emission factors were available for determining inorganic (SO4 and NO3) condensable 

emissions. Per AP-42, Table 3.4-1 Gaseous Emission Factors for Large Stationary Diesel and All Stationary DualFuel Engines, footnote d, all sulfur in the fuel is assumed to be converted to SO2

. Therefore, inorganic condensable 

emissions from the MODU were assumed to be zero. Based on guidance provided in Procedure for Speciation of 

Emissions for VISTAS BART Modeling, July 18, 2006, 100% of non-H2SO4 condensable mass was assumed to be 

organic condensables (SOA).

Anadarko Petroleum Corporation

Air quality Modeling Analysis Page 15 of 16

Class I_Model Input Parameters v1.2-SV - PM Speciation

8/24/2013
Species

Dry Deposition Phase 

(Gas/ Particle)1

Wet Deposition 

Modeled? (Yes/ No)2

Geometric Mass 

Mean Diameter 3 

(microns)

Geometric Standard 

Deviation 3 

(microns)

SO2 Gas Yes N/A N/A

SO4 Particle Yes 0.48 2.0

NOx Gas No N/A N/A

HNO3 Gas Yes N/A N/A

NO3 Particle Yes 0.48 2.0

SOA Particle Yes 0.48 2.0

PMC Particle Yes 6.5 0.0

PMF Particle Yes 1.75 0.0

Anadarko Petroleum Corporation

Deposition Analysis - Input Parameters

1 Gas phase deposition has been analyzed for SO2

, NOx, and HNO3, and particle phase deposition for SO4, NO3, and PM 

categories, in accordance with the U.S. Forest Service – Air Quality Program, National Park Service – Air Resources 

Division, U.S. Fish and Wildlife Service – Air Quality Branch, Phase I Report of the Federal Land Managers’ Air Quality 

Related Values Workgroup (FLAG), October 2010. (FLAG Phase I Revised).

2 Both wet and dry fluxes have been estimated for all pollutant species except NOx, in accordance with the FLAG Phase I 

revised report. Both dry and wet deposition were disabled for NOx and PM10 Increment Modeling.

3

 The average particle diameter for each speciated particulate (PM) category has been taken as the geometric mass mean 

diameter for that category. Geometric standard deviation has been assumed to be zero for all PM categories. Default 

CALPUFF values have been used for SOA, SO4, and NO3 particles.

Anadarko Petroleum Corporation

Air quality Modeling Analysis Page 16 of 16

Class I_Model Input Parameters v1.2-Deposition

8/24/2013
Anadarko Petroleum Corporation Trinity Consultants 

APPENDIX D2: CLASS II MODEL INPUT PARAMETERS 
Reference latitude: 40 deg

Reference longitude: 97 deg (based on + Western Hemisphere)

Standard parallel #1: 33 deg

Standard parallel #2: 45 deg

Latitude (deg) Longitude (deg) LCC Coordinates

X (km)

LCC Coordinates

Y (km)

25 miles from nearest state seaward boundary 28.85 87.52 930.28 -1189.81

Class II Area Distance (km) 2

25 miles from nearest shoreline 94.9

2

 Represents the distance to the closest receptor on Class II area. Coordinates for receptors on the Class II areas were obtained from EPA Region IV.

Anadarko Petroleum Corporation

LCC Reference Parameters ¥

¥ Based on the model design used by Visibility Improvement State and Tribal Association of the Southeast (VISTAS) for Regional Haze Rule modeling - 

Protocol for the Application of the CALPUFF Model for Analyses of Best Available Retrofit Technology (BART), December 22, 2005, revised August 31, 

2006.

Worksheet for Converting Latitude and Longitude to Lambert Conformal Projection Coordinates

Class II Area

Worst-case Drillship Location 1

1

 Represents the worst-case location within the lease block drilling area with respect to each Class I area. 

Anadarko Petroleum Corporation

Air quality Modeling Analysis 4 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Coordinate Conversion LCC(DS)

8/24/2013
Reference latitude: 40 deg

Reference longitude: 97 deg (based on + Western Hemisphere)

Standard parallel #1: 33 deg

Standard parallel #2: 45 deg

Latitude (deg) Longitude (deg) LCC Coordinates

X (km)

LCC Coordinates

Y (km)

25 miles from nearest state seaward boundary 29.24 87.54 925.58 -1143.75

Class II Area Distance (km) 2

25 miles from nearest shoreline 48.6

1

 Represents the worst-case supply boat location with respect to closest receptor. 

2

 Represents the distance to the closest receptor. Coordinates for receptors on the Class II areas were obtained from EPA Region IV.

Anadarko Petroleum Corporation

Worksheet for Converting Latitude and Longitude to Lambert Conformal Projection Coordinates

LCC Reference Parameters ¥

¥ Based on the model design used by Visibility Improvement State and Tribal Association of the Southeast (VISTAS) for Regional Haze Rule modeling - 

Protocol for the Application of the CALPUFF Model for Analyses of Best Available Retrofit Technology (BART), December 22, 2005, revised August 31, 

2006.

Class II Area

Worst-case SuppO\%RDWLocation 1

Anadarko Petroleum Corporation

Air quality Modeling Analysis 3 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Coordinate Conversion LCC (SB)

8/24/2013
Source Location LCC X LCC Y

Worse-Case Drillship Location 930.28 -1189.81

Computational Domain Setup - STEP 1 LCC X LCC Y

Northernmost Point -1071.15

Southernmost Point -1375.25

Westernmost Point 724.56

Easternmost Point 1422.68

Computational Domain Setup - STEP 2 (based on +/- 50 km) LCC X LCC Y

SW 674.56 -1425.25

NW 674.56 -1021.15

NE 1472.68 -1021.15

SE 1472.68 -1425.25

Computational Domain Setup - STEP 3 (rounded w/ 4 km spacing) LCC X LCC Y

SW 673.995 -1426.0

NW 673.995 -1018.0

NE 1473.995 -1018.0

SE 1473.995 -1426.0

Distance Span 800 408

Grid Spacing 4 4

Number of Cells 200 102

VISTAS Domain 2 (Meteorological Domain) SW corner LCC X LCC Y (Fixed)

Meteorological Grid Origin Coordinates 721.995 -1598.0

Computational Grid Settings Cells X Cells Y

SW -12 43

NE 188 145

Grid Spacing 4 4

Number of Cells (Check) 200 102

(Used Max/ Min of Class I area receptor 

coordinates and source coordinates to 

ensure the domain included the source as 

well as all receptors).

(Enter these grid settings into 

CALPUFF).

Anadarko Petroleum Corporation

Class II - Computational Domain Grid Setup

(Domain endpoint coordinates moved 

further out to coincide with the grid point 

locations of the meteorological domain 

(at grid spacing of 4 Km)

(Extends domain to 50 km further 

beyond the source and receptors for 

conservatism).

Anadarko Petroleum Corporation

Air quality Modeling Analysis 5 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II - Computational Domain

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Receptor 1 28.495 89.657 724.559 -1249.311 0.0 0.0 214.15

Receptor 2 28.490 89.648 725.465 -1249.757 0.0 0.0 213.41

Receptor 3 28.486 89.639 726.381 -1250.182 0.0 0.0 212.65

Receptor 4 28.482 89.630 727.305 -1250.588 0.0 0.0 211.88

Receptor 5 28.477 89.621 728.239 -1250.971 0.0 0.0 211.09

Receptor 6 28.474 89.612 729.181 -1251.334 0.0 0.0 210.30

Receptor 7 28.470 89.603 730.131 -1251.674 0.0 0.0 209.49

Receptor 8 28.466 89.593 731.089 -1251.992 0.0 0.0 208.67

Receptor 9 28.463 89.584 732.053 -1252.289 0.0 0.0 207.84

Receptor 10 28.460 89.574 733.025 -1252.562 0.0 0.0 206.99

Receptor 11 28.457 89.565 734.001 -1252.813 0.0 0.0 206.14

Receptor 12 28.454 89.555 734.985 -1253.040 0.0 0.0 205.27

Receptor 13 28.452 89.545 735.973 -1253.244 0.0 0.0 204.40

Receptor 14 28.449 89.535 736.965 -1253.425 0.0 0.0 203.51

Receptor 15 28.447 89.525 737.962 -1253.582 0.0 0.0 202.61

Receptor 16 28.445 89.515 738.962 -1253.715 0.0 0.0 201.71

Receptor 17 28.444 89.505 739.964 -1253.824 0.0 0.0 200.79

Receptor 18 28.442 89.495 740.969 -1253.909 0.0 0.0 199.87

Receptor 19 28.441 89.485 741.976 -1253.971 0.0 0.0 198.93

Receptor 20 28.440 89.475 742.984 -1254.007 0.0 0.0 197.99

Receptor 21 28.439 89.465 743.993 -1254.019 0.0 0.0 197.04

Receptor 22 28.438 89.455 745.001 -1254.008 0.0 0.0 196.08

Receptor 23 28.438 89.444 746.008 -1253.970 0.0 0.0 195.12

Receptor 24 28.438 89.434 747.015 -1253.911 0.0 0.0 194.15

Receptor 25 28.438 89.424 748.020 -1253.825 0.0 0.0 193.17

Receptor 26 28.438 89.414 749.023 -1253.715 0.0 0.0 192.19

Receptor 27 28.438 89.404 750.023 -1253.583 0.0 0.0 191.20

Receptor 28 28.439 89.394 751.019 -1253.424 0.0 0.0 190.21

Receptor 29 28.440 89.383 752.011 -1253.242 0.0 0.0 189.22

Receptor 30 28.441 89.373 752.998 -1253.037 0.0 0.0 188.22

Receptor 31 28.442 89.363 753.981 -1252.807 0.0 0.0 187.21

Receptor 32 28.444 89.353 754.957 -1252.555 0.0 0.0 186.21

Receptor 33 28.446 89.343 755.927 -1252.277 0.0 0.0 185.20

Receptor 34 28.447 89.333 756.890 -1251.978 0.0 0.0 184.20

Receptor 35 28.450 89.323 757.847 -1251.656 0.0 0.0 183.19

Receptor 36 28.452 89.313 758.794 -1251.310 0.0 0.0 182.18

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Anadarko Petroleum Corporation

Air quality Modeling Analysis 6 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 37 28.454 89.304 759.734 -1250.943 0.0 0.0 181.17

Receptor 38 28.457 89.294 760.665 -1250.554 0.0 0.0 180.16

Receptor 39 28.460 89.284 761.586 -1250.141 0.0 0.0 179.16

Receptor 40 28.463 89.275 762.498 -1249.709 0.0 0.0 178.15

Receptor 41 28.467 89.265 763.400 -1249.255 0.0 0.0 177.15

Receptor 42 28.470 89.256 764.290 -1248.779 0.0 0.0 176.15

Receptor 43 28.474 89.246 765.170 -1248.285 0.0 0.0 175.16

Receptor 44 28.478 89.237 766.039 -1247.771 0.0 0.0 174.17

Receptor 45 28.482 89.228 766.897 -1247.241 0.0 0.0 173.18

Receptor 46 28.486 89.219 767.744 -1246.689 0.0 0.0 172.20

Receptor 47 28.491 89.210 768.577 -1246.119 0.0 0.0 171.22

Receptor 48 28.495 89.201 769.398 -1245.531 0.0 0.0 170.26

Receptor 49 28.500 89.193 770.207 -1244.926 0.0 0.0 169.29

Receptor 50 28.501 89.183 771.146 -1244.724 0.0 0.0 168.34

Receptor 51 28.500 89.173 772.155 -1244.707 0.0 0.0 167.38

Receptor 52 28.500 89.163 773.162 -1244.665 0.0 0.0 166.42

Receptor 53 28.500 89.152 774.169 -1244.601 0.0 0.0 165.45

Receptor 54 28.500 89.142 775.173 -1244.510 0.0 0.0 164.47

Receptor 55 28.500 89.132 776.175 -1244.395 0.0 0.0 163.48

Receptor 56 28.500 89.122 777.174 -1244.258 0.0 0.0 162.50

Receptor 57 28.501 89.112 778.169 -1244.094 0.0 0.0 161.51

Receptor 58 28.502 89.102 779.161 -1243.908 0.0 0.0 160.51

Receptor 59 28.503 89.091 780.147 -1243.697 0.0 0.0 159.51

Receptor 60 28.504 89.081 781.128 -1243.463 0.0 0.0 158.51

Receptor 61 28.506 89.071 782.103 -1243.206 0.0 0.0 157.50

Receptor 62 28.508 89.061 783.072 -1242.924 0.0 0.0 156.49

Receptor 63 28.510 89.051 784.034 -1242.620 0.0 0.0 155.49

Receptor 64 28.512 89.041 784.988 -1242.293 0.0 0.0 154.48

Receptor 65 28.514 89.031 785.934 -1241.943 0.0 0.0 153.47

Receptor 66 28.517 89.022 786.872 -1241.571 0.0 0.0 152.46

Receptor 67 28.520 89.012 787.801 -1241.177 0.0 0.0 151.45

Receptor 68 28.522 89.002 788.720 -1240.761 0.0 0.0 150.45

Receptor 69 28.526 88.993 789.630 -1240.324 0.0 0.0 149.44

Receptor 70 28.529 88.983 790.529 -1239.866 0.0 0.0 148.44

Receptor 71 28.533 88.974 791.418 -1239.387 0.0 0.0 147.44

Receptor 72 28.536 88.965 792.295 -1238.889 0.0 0.0 146.45

Anadarko Petroleum Corporation

Air quality Modeling Analysis 7 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 73 28.540 88.955 793.161 -1238.370 0.0 0.0 145.46

Receptor 74 28.544 88.946 794.015 -1237.830 0.0 0.0 144.48

Receptor 75 28.549 88.937 794.856 -1237.272 0.0 0.0 143.50

Receptor 76 28.553 88.928 795.685 -1236.695 0.0 0.0 142.53

Receptor 77 28.558 88.920 796.500 -1236.099 0.0 0.0 141.56

Receptor 78 28.563 88.911 797.302 -1235.485 0.0 0.0 140.60

Receptor 79 28.567 88.903 798.090 -1234.853 0.0 0.0 139.65

Receptor 80 28.573 88.894 798.865 -1234.205 0.0 0.0 138.71

Receptor 81 28.578 88.886 799.624 -1233.539 0.0 0.0 137.78

Receptor 82 28.583 88.878 800.369 -1232.857 0.0 0.0 136.86

Receptor 83 28.589 88.870 801.100 -1232.159 0.0 0.0 135.94

Receptor 84 28.595 88.862 801.816 -1231.445 0.0 0.0 135.04

Receptor 85 28.601 88.854 802.516 -1230.717 0.0 0.0 134.15

Receptor 86 28.607 88.846 803.205 -1229.978 0.0 0.0 133.27

Receptor 87 28.613 88.839 803.881 -1229.226 0.0 0.0 132.40

Receptor 88 28.619 88.832 804.539 -1228.459 0.0 0.0 131.54

Receptor 89 28.625 88.824 805.183 -1227.679 0.0 0.0 130.70

Receptor 90 28.632 88.817 805.817 -1226.892 0.0 0.0 129.87

Receptor 91 28.638 88.810 806.435 -1226.092 0.0 0.0 129.05

Receptor 92 28.645 88.803 807.038 -1225.280 0.0 0.0 128.24

Receptor 93 28.652 88.797 807.623 -1224.455 0.0 0.0 127.45

Receptor 94 28.659 88.790 808.192 -1223.620 0.0 0.0 126.68

Receptor 95 28.666 88.784 808.746 -1222.773 0.0 0.0 125.92

Receptor 96 28.673 88.778 809.281 -1221.915 0.0 0.0 125.18

Receptor 97 28.681 88.772 809.800 -1221.047 0.0 0.0 124.46

Receptor 98 28.688 88.766 810.302 -1220.168 0.0 0.0 123.76

Receptor 99 28.695 88.759 810.887 -1219.352 0.0 0.0 122.99

Receptor 100 28.701 88.752 811.555 -1218.594 0.0 0.0 122.16

Receptor 101 28.707 88.744 812.209 -1217.823 0.0 0.0 121.35

Receptor 102 28.714 88.737 812.844 -1217.037 0.0 0.0 120.55

Receptor 103 28.720 88.730 813.465 -1216.239 0.0 0.0 119.77

Receptor 104 28.727 88.723 814.069 -1215.428 0.0 0.0 119.00

Receptor 105 28.734 88.717 814.654 -1214.604 0.0 0.0 118.25

Receptor 106 28.741 88.710 815.225 -1213.769 0.0 0.0 117.52

Receptor 107 28.748 88.704 815.779 -1212.923 0.0 0.0 116.81

Receptor 108 28.755 88.698 816.315 -1212.066 0.0 0.0 116.12

Anadarko Petroleum Corporation

Air quality Modeling Analysis 8 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 109 28.762 88.691 816.835 -1211.199 0.0 0.0 115.44

Receptor 110 28.770 88.686 817.338 -1210.321 0.0 0.0 114.79

Receptor 111 28.777 88.680 817.823 -1209.433 0.0 0.0 114.15

Receptor 112 28.785 88.674 818.292 -1208.537 0.0 0.0 113.54

Receptor 113 28.791 88.667 818.901 -1207.740 0.0 0.0 112.81

Receptor 114 28.797 88.660 819.564 -1206.978 0.0 0.0 112.04

Receptor 115 28.804 88.653 820.210 -1206.202 0.0 0.0 111.28

Receptor 116 28.810 88.646 820.840 -1205.411 0.0 0.0 110.54

Receptor 117 28.817 88.639 821.454 -1204.608 0.0 0.0 109.83

Receptor 118 28.824 88.632 822.051 -1203.793 0.0 0.0 109.13

Receptor 119 28.830 88.625 822.631 -1202.965 0.0 0.0 108.45

Receptor 120 28.837 88.619 823.196 -1202.127 0.0 0.0 107.79

Receptor 121 28.844 88.612 823.744 -1201.277 0.0 0.0 107.15

Receptor 122 28.852 88.606 824.273 -1200.416 0.0 0.0 106.53

Receptor 123 28.859 88.600 824.786 -1199.544 0.0 0.0 105.94

Receptor 124 29.420 88.540 824.847 -1136.358 0.0 0.0 118.21

Receptor 125 29.412 88.539 825.021 -1137.224 0.0 0.0 117.66

Receptor 126 28.866 88.594 825.283 -1198.663 0.0 0.0 105.37

Receptor 127 29.427 88.533 825.424 -1135.529 0.0 0.0 118.07

Receptor 128 29.404 88.535 825.494 -1138.117 0.0 0.0 116.84

Receptor 129 28.874 88.589 825.760 -1197.772 0.0 0.0 104.82

Receptor 130 29.395 88.531 825.951 -1139.018 0.0 0.0 116.04

Receptor 131 29.433 88.526 826.025 -1134.719 0.0 0.0 117.92

Receptor 132 28.882 88.583 826.221 -1196.872 0.0 0.0 104.30

Receptor 133 29.387 88.527 826.393 -1139.927 0.0 0.0 115.24

Receptor 134 29.440 88.519 826.617 -1133.902 0.0 0.0 117.78

Receptor 135 28.889 88.578 826.666 -1195.964 0.0 0.0 103.80

Receptor 136 29.378 88.524 826.818 -1140.844 0.0 0.0 114.46

Receptor 137 28.897 88.573 827.093 -1195.047 0.0 0.0 103.32

Receptor 138 29.447 88.513 827.192 -1133.073 0.0 0.0 117.67

Receptor 139 29.370 88.521 827.227 -1141.769 0.0 0.0 113.70

Receptor 140 28.905 88.568 827.502 -1194.122 0.0 0.0 102.87

Receptor 141 29.361 88.518 827.620 -1142.700 0.0 0.0 112.95

Receptor 142 29.454 88.506 827.752 -1132.234 0.0 0.0 117.59

Receptor 143 28.913 88.563 827.894 -1193.190 0.0 0.0 102.44

Receptor 144 29.352 88.515 827.995 -1143.639 0.0 0.0 112.22

Anadarko Petroleum Corporation

Air quality Modeling Analysis 9 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 145 28.921 88.558 828.269 -1192.250 0.0 0.0 102.04

Receptor 146 29.461 88.500 828.293 -1131.382 0.0 0.0 117.54

Receptor 147 29.344 88.512 828.355 -1144.584 0.0 0.0 111.51

Receptor 148 28.929 88.553 828.626 -1191.303 0.0 0.0 101.66

Receptor 149 29.335 88.509 828.698 -1145.535 0.0 0.0 110.81

Receptor 150 29.468 88.494 828.817 -1130.520 0.0 0.0 117.52

Receptor 151 28.937 88.549 828.965 -1190.350 0.0 0.0 101.32

Receptor 152 29.326 88.507 829.026 -1146.491 0.0 0.0 110.13

Receptor 153 28.945 88.545 829.286 -1189.391 0.0 0.0 100.99

Receptor 154 29.476 88.488 829.325 -1129.647 0.0 0.0 117.52

Receptor 155 29.317 88.505 829.334 -1147.454 0.0 0.0 109.47

Receptor 156 28.954 88.541 829.589 -1188.425 0.0 0.0 100.70

Receptor 157 29.309 88.503 829.627 -1148.422 0.0 0.0 108.83

Receptor 158 29.483 88.482 829.817 -1128.766 0.0 0.0 117.56

Receptor 159 28.962 88.537 829.876 -1187.455 0.0 0.0 100.43

Receptor 160 29.300 88.501 829.905 -1149.395 0.0 0.0 108.21

Receptor 161 28.970 88.534 830.145 -1186.479 0.0 0.0 100.19

Receptor 162 29.291 88.499 830.163 -1150.373 0.0 0.0 107.60

Receptor 163 29.491 88.476 830.290 -1127.874 0.0 0.0 117.62

Receptor 164 28.979 88.530 830.395 -1185.499 0.0 0.0 99.98

Receptor 165 29.282 88.497 830.406 -1151.355 0.0 0.0 107.02

Receptor 166 28.987 88.527 830.629 -1184.514 0.0 0.0 99.79

Receptor 167 29.273 88.496 830.632 -1152.341 0.0 0.0 106.46

Receptor 168 29.498 88.471 830.746 -1126.974 0.0 0.0 117.71

Receptor 169 29.264 88.495 830.840 -1153.331 0.0 0.0 105.92

Receptor 170 28.996 88.524 830.844 -1183.525 0.0 0.0 99.63

Receptor 171 29.255 88.494 831.032 -1154.324 0.0 0.0 105.40

Receptor 172 29.005 88.521 831.042 -1182.533 0.0 0.0 99.50

Receptor 173 29.506 88.465 831.186 -1126.065 0.0 0.0 117.83

Receptor 174 29.246 88.493 831.206 -1155.320 0.0 0.0 104.91

Receptor 175 29.013 88.518 831.223 -1181.537 0.0 0.0 99.40

Receptor 176 29.237 88.492 831.365 -1156.319 0.0 0.0 104.43

Receptor 177 29.022 88.515 831.385 -1180.538 0.0 0.0 99.33

Receptor 178 29.228 88.492 831.504 -1157.322 0.0 0.0 103.98

Receptor 179 29.031 88.513 831.532 -1179.537 0.0 0.0 99.28

Receptor 180 29.514 88.460 831.608 -1125.148 0.0 0.0 117.97

Anadarko Petroleum Corporation

Air quality Modeling Analysis 10 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 181 29.219 88.492 831.628 -1158.326 0.0 0.0 103.55

Receptor 182 29.040 88.511 831.659 -1178.532 0.0 0.0 99.26

Receptor 183 29.210 88.492 831.736 -1159.332 0.0 0.0 103.15

Receptor 184 29.049 88.509 831.770 -1177.527 0.0 0.0 99.27

Receptor 185 29.201 88.492 831.824 -1160.340 0.0 0.0 102.77

Receptor 186 29.057 88.507 831.865 -1176.519 0.0 0.0 99.31

Receptor 187 29.192 88.492 831.897 -1161.349 0.0 0.0 102.42

Receptor 188 29.066 88.505 831.940 -1175.509 0.0 0.0 99.37

Receptor 189 29.183 88.492 831.953 -1162.359 0.0 0.0 102.09

Receptor 190 29.174 88.493 831.990 -1163.371 0.0 0.0 101.78

Receptor 191 29.138 88.497 831.995 -1167.417 0.0 0.0 100.80

Receptor 192 29.075 88.503 831.998 -1174.499 0.0 0.0 99.47

Receptor 193 29.147 88.496 832.001 -1166.406 0.0 0.0 101.03

Receptor 194 29.165 88.494 832.011 -1164.382 0.0 0.0 101.51

Receptor 195 29.522 88.455 832.012 -1124.223 0.0 0.0 118.15

Receptor 196 29.156 88.494 832.015 -1165.394 0.0 0.0 101.25

Receptor 197 29.084 88.502 832.039 -1173.488 0.0 0.0 99.59

Receptor 198 29.129 88.497 832.043 -1168.428 0.0 0.0 100.54

Receptor 199 29.093 88.501 832.065 -1172.476 0.0 0.0 99.73

Receptor 200 29.120 88.498 832.073 -1169.440 0.0 0.0 100.30

Receptor 201 29.102 88.500 832.082 -1171.464 0.0 0.0 99.90

Receptor 202 29.111 88.499 832.087 -1170.452 0.0 0.0 100.08

Receptor 203 29.530 88.450 832.399 -1123.290 0.0 0.0 118.35

Receptor 204 29.538 88.446 832.768 -1122.350 0.0 0.0 118.57

Receptor 205 29.546 88.441 833.134 -1121.409 0.0 0.0 118.81

Receptor 206 29.554 88.436 833.493 -1120.465 0.0 0.0 119.07

Receptor 207 29.562 88.432 833.836 -1119.515 0.0 0.0 119.34

Receptor 208 29.570 88.428 834.161 -1118.559 0.0 0.0 119.65

Receptor 209 29.578 88.423 834.480 -1117.600 0.0 0.0 119.97

Receptor 210 29.587 88.419 834.784 -1116.637 0.0 0.0 120.31

Receptor 211 29.595 88.416 835.071 -1115.669 0.0 0.0 120.67

Receptor 212 29.603 88.412 835.340 -1114.695 0.0 0.0 121.06

Receptor 213 29.612 88.408 835.596 -1113.718 0.0 0.0 121.47

Receptor 214 29.620 88.405 835.852 -1112.741 0.0 0.0 121.89

Receptor 215 29.629 88.401 836.103 -1111.763 0.0 0.0 122.31

Receptor 216 29.637 88.398 836.354 -1110.785 0.0 0.0 122.75

Anadarko Petroleum Corporation

Air quality Modeling Analysis 11 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 217 29.646 88.394 836.593 -1109.803 0.0 0.0 123.20

Receptor 218 29.654 88.391 836.817 -1108.818 0.0 0.0 123.67

Receptor 219 29.663 88.388 837.028 -1107.830 0.0 0.0 124.17

Receptor 220 29.672 88.385 837.235 -1106.842 0.0 0.0 124.67

Receptor 221 29.680 88.382 837.436 -1105.852 0.0 0.0 125.18

Receptor 222 29.689 88.379 837.621 -1104.859 0.0 0.0 125.71

Receptor 223 29.698 88.376 837.788 -1103.863 0.0 0.0 126.26

Receptor 224 29.706 88.374 837.943 -1102.864 0.0 0.0 126.83

Receptor 225 29.715 88.371 838.092 -1101.866 0.0 0.0 127.41

Receptor 226 29.724 88.369 838.242 -1100.867 0.0 0.0 127.99

Receptor 227 29.733 88.366 838.377 -1099.866 0.0 0.0 128.59

Receptor 228 29.737 88.359 839.066 -1099.354 0.0 0.0 128.46

Receptor 229 29.738 88.349 840.029 -1099.066 0.0 0.0 127.98

Receptor 230 29.740 88.339 840.986 -1098.756 0.0 0.0 127.53

Receptor 231 29.742 88.329 841.935 -1098.424 0.0 0.0 127.11

Receptor 232 29.745 88.319 842.877 -1098.072 0.0 0.0 126.71

Receptor 233 29.747 88.309 843.819 -1097.720 0.0 0.0 126.32

Receptor 234 29.750 88.299 844.756 -1097.357 0.0 0.0 125.95

Receptor 235 29.752 88.289 845.690 -1096.983 0.0 0.0 125.59

Receptor 236 29.755 88.279 846.614 -1096.585 0.0 0.0 125.26

Receptor 237 29.758 88.269 847.527 -1096.164 0.0 0.0 124.97

Receptor 238 29.761 88.259 848.432 -1095.725 0.0 0.0 124.71

Receptor 239 29.764 88.250 849.328 -1095.268 0.0 0.0 124.47

Receptor 240 29.766 88.240 850.291 -1095.005 0.0 0.0 124.04

Receptor 241 29.766 88.231 851.137 -1094.936 0.0 0.0 123.55

Receptor 242 29.763 88.221 852.110 -1095.189 0.0 0.0 122.74

Receptor 243 29.760 88.211 853.090 -1095.417 0.0 0.0 121.94

Receptor 244 29.757 88.202 854.074 -1095.624 0.0 0.0 121.16

Receptor 245 29.755 88.192 855.063 -1095.805 0.0 0.0 120.39

Receptor 246 29.752 88.182 856.056 -1095.963 0.0 0.0 119.65

Receptor 247 29.750 88.171 857.053 -1096.097 0.0 0.0 118.93

Receptor 248 29.748 88.161 858.053 -1096.206 0.0 0.0 118.23

Receptor 249 29.747 88.151 859.055 -1096.291 0.0 0.0 117.56

Receptor 250 29.745 88.141 860.058 -1096.351 0.0 0.0 116.90

Receptor 251 29.744 88.131 861.063 -1096.386 0.0 0.0 116.27

Receptor 252 29.743 88.120 862.068 -1096.398 0.0 0.0 115.67

Anadarko Petroleum Corporation

Air quality Modeling Analysis 12 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 253 29.742 88.110 863.073 -1096.383 0.0 0.0 115.09

Receptor 254 29.742 88.100 864.078 -1096.344 0.0 0.0 114.54

Receptor 255 29.742 88.089 865.081 -1096.280 0.0 0.0 114.01

Receptor 256 29.741 88.079 866.082 -1096.192 0.0 0.0 113.52

Receptor 257 29.742 88.069 867.081 -1096.078 0.0 0.0 113.05

Receptor 258 29.742 88.058 868.077 -1095.939 0.0 0.0 112.61

Receptor 259 29.743 88.048 869.070 -1095.778 0.0 0.0 112.20

Receptor 260 29.743 88.038 870.057 -1095.590 0.0 0.0 111.82

Receptor 261 29.744 88.028 871.040 -1095.378 0.0 0.0 111.48

Receptor 262 29.746 88.017 872.017 -1095.143 0.0 0.0 111.16

Receptor 263 29.747 88.007 872.989 -1094.882 0.0 0.0 110.88

Receptor 264 29.749 87.997 873.954 -1094.600 0.0 0.0 110.63

Receptor 265 29.751 87.987 874.911 -1094.293 0.0 0.0 110.41

Receptor 266 29.753 87.977 875.861 -1093.962 0.0 0.0 110.22

Receptor 267 29.755 87.967 876.803 -1093.610 0.0 0.0 110.07

Receptor 268 29.757 87.957 877.735 -1093.234 0.0 0.0 109.95

Receptor 269 29.760 87.947 878.658 -1092.835 0.0 0.0 109.86

Receptor 270 29.762 87.937 879.621 -1092.546 0.0 0.0 109.67

Receptor 271 29.763 87.927 880.603 -1092.375 0.0 0.0 109.37

Receptor 272 29.762 87.916 881.607 -1092.328 0.0 0.0 108.96

Receptor 273 29.762 87.906 882.611 -1092.263 0.0 0.0 108.57

Receptor 274 29.761 87.896 883.614 -1092.206 0.0 0.0 108.19

Receptor 275 29.761 87.885 884.618 -1092.150 0.0 0.0 107.81

Receptor 276 29.761 87.875 885.621 -1092.087 0.0 0.0 107.45

Receptor 277 29.760 87.865 886.626 -1092.042 0.0 0.0 107.07

Receptor 278 29.760 87.854 887.629 -1091.990 0.0 0.0 106.72

Receptor 279 29.759 87.844 888.632 -1091.917 0.0 0.0 106.39

Receptor 280 29.759 87.834 889.633 -1091.822 0.0 0.0 106.09

Receptor 281 29.760 87.823 890.631 -1091.704 0.0 0.0 105.82

Receptor 282 29.760 87.813 891.627 -1091.563 0.0 0.0 105.58

Receptor 283 29.760 87.803 892.620 -1091.406 0.0 0.0 105.37

Receptor 284 29.761 87.792 893.609 -1091.225 0.0 0.0 105.19

Receptor 285 29.762 87.782 894.593 -1091.023 0.0 0.0 105.04

Receptor 286 29.763 87.772 895.579 -1090.823 0.0 0.0 104.90

Receptor 287 29.764 87.762 896.558 -1090.597 0.0 0.0 104.79

Receptor 288 29.765 87.751 897.537 -1090.366 0.0 0.0 104.70

Anadarko Petroleum Corporation

Air quality Modeling Analysis 13 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 289 29.766 87.741 898.514 -1090.129 0.0 0.0 104.62

Receptor 290 29.768 87.731 899.486 -1089.869 0.0 0.0 104.58

Receptor 291 29.769 87.721 900.452 -1089.591 0.0 0.0 104.57

Receptor 292 29.771 87.710 901.420 -1089.318 0.0 0.0 104.56

Receptor 293 29.773 87.700 902.383 -1089.030 0.0 0.0 104.57

Receptor 294 29.775 87.690 903.341 -1088.725 0.0 0.0 104.62

Receptor 295 29.776 87.680 904.300 -1088.424 0.0 0.0 104.66

Receptor 296 29.778 87.670 905.272 -1088.167 0.0 0.0 104.68

Receptor 297 29.779 87.660 906.252 -1087.941 0.0 0.0 104.67

Receptor 298 29.780 87.649 907.229 -1087.706 0.0 0.0 104.68

Receptor 299 29.781 87.639 908.202 -1087.453 0.0 0.0 104.71

Receptor 300 29.783 87.629 909.172 -1087.188 0.0 0.0 104.77

Receptor 301 29.784 87.619 910.144 -1086.935 0.0 0.0 104.83

Receptor 302 29.785 87.608 911.127 -1086.722 0.0 0.0 104.85

Receptor 303 29.786 87.598 912.105 -1086.487 0.0 0.0 104.91

Receptor 304 29.788 87.588 913.076 -1086.227 0.0 0.0 105.00

Receptor 305 29.789 87.578 914.041 -1085.943 0.0 0.0 105.13

Receptor 306 29.791 87.568 914.998 -1085.637 0.0 0.0 105.29

Receptor 307 29.793 87.558 915.947 -1085.306 0.0 0.0 105.49

Receptor 308 29.796 87.547 916.890 -1084.956 0.0 0.0 105.71

Receptor 309 29.798 87.538 917.826 -1084.587 0.0 0.0 105.96

Receptor 310 29.801 87.528 918.754 -1084.200 0.0 0.0 106.24

Receptor 311 29.803 87.518 919.692 -1083.836 0.0 0.0 106.50

Receptor 312 29.699 87.520 920.655 -1095.406 0.0 0.0 94.90

Receptor 313 29.702 87.510 921.589 -1095.031 0.0 0.0 95.18

Receptor 314 29.704 87.500 922.520 -1094.651 0.0 0.0 95.48

Receptor 315 29.706 87.490 923.462 -1094.303 0.0 0.0 95.75

Receptor 316 29.708 87.480 924.438 -1094.058 0.0 0.0 95.93

Receptor 317 29.709 87.470 925.408 -1093.793 0.0 0.0 96.14

Receptor 318 29.711 87.460 926.373 -1093.508 0.0 0.0 96.38

Receptor 319 29.713 87.450 927.331 -1093.205 0.0 0.0 96.65

Receptor 320 29.714 87.439 928.285 -1092.883 0.0 0.0 96.95

Receptor 321 29.717 87.429 929.231 -1092.542 0.0 0.0 97.28

Receptor 322 29.719 87.419 930.169 -1092.181 0.0 0.0 97.63

Receptor 323 29.721 87.409 931.101 -1091.801 0.0 0.0 98.02

Receptor 324 29.724 87.400 932.024 -1091.402 0.0 0.0 98.43

Anadarko Petroleum Corporation

Air quality Modeling Analysis 14 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 325 29.727 87.390 932.940 -1090.987 0.0 0.0 98.86

Receptor 326 29.729 87.380 933.894 -1090.667 0.0 0.0 99.21

Receptor 327 29.731 87.370 934.842 -1090.335 0.0 0.0 99.58

Receptor 328 29.733 87.360 935.797 -1090.017 0.0 0.0 99.95

Receptor 329 29.734 87.349 936.765 -1089.747 0.0 0.0 100.28

Receptor 330 29.736 87.339 937.734 -1089.478 0.0 0.0 100.61

Receptor 331 29.737 87.329 938.698 -1089.192 0.0 0.0 100.97

Receptor 332 29.739 87.319 939.656 -1088.887 0.0 0.0 101.36

Receptor 333 29.741 87.309 940.611 -1088.570 0.0 0.0 101.77

Receptor 334 29.743 87.299 941.563 -1088.248 0.0 0.0 102.19

Receptor 335 29.745 87.289 942.515 -1087.922 0.0 0.0 102.62

Receptor 336 29.747 87.279 943.460 -1087.578 0.0 0.0 103.08

Receptor 337 29.749 87.268 944.419 -1087.300 0.0 0.0 103.48

Receptor 338 29.749 87.258 945.418 -1087.183 0.0 0.0 103.74

Receptor 339 29.749 87.248 946.414 -1087.050 0.0 0.0 104.02

Receptor 340 29.750 87.237 947.408 -1086.899 0.0 0.0 104.33

Receptor 341 29.750 87.227 948.399 -1086.730 0.0 0.0 104.66

Receptor 342 29.751 87.217 949.389 -1086.553 0.0 0.0 105.01

Receptor 343 29.751 87.206 950.377 -1086.368 0.0 0.0 105.38

Receptor 344 29.752 87.196 951.363 -1086.171 0.0 0.0 105.76

Receptor 345 29.753 87.186 952.348 -1085.970 0.0 0.0 106.16

Receptor 346 29.754 87.176 953.329 -1085.750 0.0 0.0 106.59

Receptor 347 29.755 87.165 954.307 -1085.517 0.0 0.0 107.03

Receptor 348 29.756 87.155 955.287 -1085.289 0.0 0.0 107.47

Receptor 349 29.757 87.145 956.261 -1085.042 0.0 0.0 107.94

Receptor 350 29.759 87.135 957.235 -1084.794 0.0 0.0 108.42

Receptor 351 29.760 87.124 958.208 -1084.538 0.0 0.0 108.92

Receptor 352 29.761 87.114 959.177 -1084.273 0.0 0.0 109.42

Receptor 353 29.763 87.104 960.150 -1084.014 0.0 0.0 109.94

Receptor 354 29.764 87.094 961.122 -1083.759 0.0 0.0 110.45

Receptor 355 29.765 87.083 962.097 -1083.512 0.0 0.0 110.96

Receptor 356 29.767 87.073 963.066 -1083.247 0.0 0.0 111.50

Receptor 357 29.768 87.063 964.032 -1082.964 0.0 0.0 112.05

Receptor 358 29.770 87.053 964.992 -1082.669 0.0 0.0 112.63

Receptor 359 29.772 87.043 965.950 -1082.361 0.0 0.0 113.22

Receptor 360 29.774 87.033 966.901 -1082.034 0.0 0.0 113.83

Anadarko Petroleum Corporation

Air quality Modeling Analysis 15 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 361 29.776 87.023 967.853 -1081.713 0.0 0.0 114.44

Receptor 362 29.778 87.012 968.812 -1081.410 0.0 0.0 115.05

Receptor 363 29.779 87.002 969.767 -1081.094 0.0 0.0 115.67

Receptor 364 29.781 86.992 970.717 -1080.766 0.0 0.0 116.30

Receptor 365 29.783 86.982 971.670 -1080.444 0.0 0.0 116.94

Receptor 366 29.785 86.972 972.623 -1080.122 0.0 0.0 117.58

Receptor 367 29.787 86.962 973.572 -1079.788 0.0 0.0 118.24

Receptor 368 29.789 86.952 974.526 -1079.471 0.0 0.0 118.88

Receptor 369 29.791 86.942 975.484 -1079.167 0.0 0.0 119.52

Receptor 370 29.793 86.932 976.438 -1078.850 0.0 0.0 120.18

Receptor 371 29.794 86.921 977.396 -1078.545 0.0 0.0 120.83

Receptor 372 29.796 86.911 978.350 -1078.227 0.0 0.0 121.50

Receptor 373 29.798 86.901 979.306 -1077.916 0.0 0.0 122.17

Receptor 374 29.800 86.891 980.267 -1077.623 0.0 0.0 122.82

Receptor 375 29.802 86.881 981.227 -1077.323 0.0 0.0 123.49

Receptor 376 29.803 86.871 982.183 -1077.011 0.0 0.0 124.17

Receptor 377 29.805 86.861 983.135 -1076.689 0.0 0.0 124.86

Receptor 378 29.807 86.850 984.093 -1076.384 0.0 0.0 125.55

Receptor 379 29.809 86.840 985.053 -1076.083 0.0 0.0 126.23

Receptor 380 29.811 86.830 986.007 -1075.765 0.0 0.0 126.94

Receptor 381 29.813 86.820 986.959 -1075.442 0.0 0.0 127.65

Receptor 382 29.814 86.810 987.923 -1075.159 0.0 0.0 128.33

Receptor 383 29.816 86.800 988.886 -1074.871 0.0 0.0 129.02

Receptor 384 29.817 86.789 989.853 -1074.595 0.0 0.0 129.71

Receptor 385 29.818 86.779 990.825 -1074.339 0.0 0.0 130.38

Receptor 386 29.820 86.769 991.796 -1074.079 0.0 0.0 131.07

Receptor 387 29.821 86.759 992.775 -1073.846 0.0 0.0 131.73

Receptor 388 29.822 86.748 993.752 -1073.610 0.0 0.0 132.41

Receptor 389 29.823 86.738 994.729 -1073.374 0.0 0.0 133.09

Receptor 390 29.824 86.728 995.705 -1073.135 0.0 0.0 133.77

Receptor 391 29.825 86.718 996.685 -1072.911 0.0 0.0 134.45

Receptor 392 29.826 86.707 997.662 -1072.672 0.0 0.0 135.14

Receptor 393 29.827 86.697 998.644 -1072.460 0.0 0.0 135.81

Receptor 394 29.828 86.687 999.630 -1072.266 0.0 0.0 136.48

Receptor 395 29.828 86.676 1000.623 -1072.105 0.0 0.0 137.13

Receptor 396 29.829 86.666 1001.616 -1071.955 0.0 0.0 137.77

Anadarko Petroleum Corporation

Air quality Modeling Analysis 16 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 397 29.829 86.656 1002.610 -1071.802 0.0 0.0 138.41

Receptor 398 29.829 86.645 1003.608 -1071.710 0.0 0.0 139.02

Receptor 399 29.828 86.635 1004.611 -1071.716 0.0 0.0 139.54

Receptor 400 29.826 86.625 1005.609 -1071.840 0.0 0.0 139.97

Receptor 401 29.824 86.615 1006.609 -1071.941 0.0 0.0 140.43

Receptor 402 29.822 86.605 1007.612 -1072.024 0.0 0.0 140.91

Receptor 403 29.820 86.595 1008.615 -1072.086 0.0 0.0 141.41

Receptor 404 29.819 86.584 1009.619 -1072.127 0.0 0.0 141.93

Receptor 405 29.818 86.574 1010.624 -1072.147 0.0 0.0 142.48

Receptor 406 29.817 86.564 1011.630 -1072.147 0.0 0.0 143.05

Receptor 407 29.816 86.554 1012.635 -1072.127 0.0 0.0 143.64

Receptor 408 29.815 86.543 1013.639 -1072.087 0.0 0.0 144.25

Receptor 409 29.815 86.533 1014.642 -1072.026 0.0 0.0 144.88

Receptor 410 29.815 86.523 1015.644 -1071.943 0.0 0.0 145.54

Receptor 411 29.814 86.512 1016.644 -1071.840 0.0 0.0 146.21

Receptor 412 29.814 86.502 1017.642 -1071.716 0.0 0.0 146.90

Receptor 413 29.815 86.492 1018.638 -1071.582 0.0 0.0 147.60

Receptor 414 29.815 86.481 1019.631 -1071.428 0.0 0.0 148.32

Receptor 415 29.815 86.471 1020.622 -1071.255 0.0 0.0 149.06

Receptor 416 29.815 86.461 1021.616 -1071.150 0.0 0.0 149.74

Receptor 417 29.814 86.450 1022.620 -1071.199 0.0 0.0 150.32

Receptor 418 29.812 86.440 1023.624 -1071.248 0.0 0.0 150.90

Receptor 419 29.811 86.430 1024.627 -1071.322 0.0 0.0 151.47

Receptor 420 29.809 86.420 1025.629 -1071.407 0.0 0.0 152.03

Receptor 421 29.807 86.410 1026.623 -1071.559 0.0 0.0 152.53

Receptor 422 29.804 86.400 1027.609 -1071.751 0.0 0.0 153.01

Receptor 423 29.801 86.390 1028.590 -1071.970 0.0 0.0 153.47

Receptor 424 29.798 86.380 1029.572 -1072.192 0.0 0.0 153.93

Receptor 425 29.795 86.371 1030.556 -1072.397 0.0 0.0 154.41

Receptor 426 29.792 86.361 1031.545 -1072.584 0.0 0.0 154.91

Receptor 427 29.790 86.351 1032.534 -1072.766 0.0 0.0 155.42

Receptor 428 29.787 86.341 1033.515 -1072.988 0.0 0.0 155.90

Receptor 429 29.784 86.331 1034.494 -1073.215 0.0 0.0 156.38

Receptor 430 29.781 86.322 1035.476 -1073.434 0.0 0.0 156.88

Receptor 431 29.778 86.312 1036.460 -1073.640 0.0 0.0 157.39

Receptor 432 29.775 86.302 1037.442 -1073.861 0.0 0.0 157.89

Anadarko Petroleum Corporation

Air quality Modeling Analysis 17 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 433 29.772 86.292 1038.422 -1074.085 0.0 0.0 158.39

Receptor 434 29.769 86.283 1039.405 -1074.301 0.0 0.0 158.91

Receptor 435 29.766 86.273 1040.387 -1074.514 0.0 0.0 159.43

Receptor 436 29.762 86.263 1041.352 -1074.800 0.0 0.0 159.89

Receptor 437 29.759 86.254 1042.321 -1075.068 0.0 0.0 160.37

Receptor 438 29.756 86.244 1043.291 -1075.336 0.0 0.0 160.86

Receptor 439 29.752 86.235 1044.261 -1075.605 0.0 0.0 161.35

Receptor 440 29.748 86.225 1045.214 -1075.925 0.0 0.0 161.80

Receptor 441 29.745 86.216 1046.171 -1076.238 0.0 0.0 162.27

Receptor 442 29.741 86.206 1047.128 -1076.548 0.0 0.0 162.73

Receptor 443 29.737 86.197 1048.089 -1076.845 0.0 0.0 163.22

Receptor 444 29.734 86.187 1049.051 -1077.139 0.0 0.0 163.71

Receptor 445 29.730 86.178 1050.000 -1077.474 0.0 0.0 164.17

Receptor 446 29.725 86.169 1050.941 -1077.831 0.0 0.0 164.62

Receptor 447 29.721 86.160 1051.875 -1078.207 0.0 0.0 165.05

Receptor 448 29.717 86.151 1052.795 -1078.615 0.0 0.0 165.45

Receptor 449 29.712 86.142 1053.711 -1079.032 0.0 0.0 165.86

Receptor 450 29.707 86.133 1054.620 -1079.467 0.0 0.0 166.24

Receptor 451 29.702 86.125 1055.517 -1079.922 0.0 0.0 166.62

Receptor 452 29.697 86.117 1056.394 -1080.410 0.0 0.0 166.96

Receptor 453 29.690 86.109 1057.190 -1081.028 0.0 0.0 167.15

Receptor 454 29.684 86.102 1057.996 -1081.634 0.0 0.0 167.37

Receptor 455 29.678 86.094 1058.812 -1082.225 0.0 0.0 167.62

Receptor 456 29.672 86.086 1059.638 -1082.802 0.0 0.0 167.88

Receptor 457 29.666 86.079 1060.474 -1083.364 0.0 0.0 168.17

Receptor 458 29.660 86.071 1061.321 -1083.911 0.0 0.0 168.49

Receptor 459 29.655 86.063 1062.176 -1084.444 0.0 0.0 168.82

Receptor 460 29.649 86.054 1063.037 -1084.966 0.0 0.0 169.17

Receptor 461 29.644 86.046 1063.907 -1085.474 0.0 0.0 169.54

Receptor 462 29.639 86.038 1064.786 -1085.967 0.0 0.0 169.93

Receptor 463 29.633 86.029 1065.674 -1086.443 0.0 0.0 170.34

Receptor 464 29.628 86.021 1066.555 -1086.932 0.0 0.0 170.75

Receptor 465 29.623 86.013 1067.433 -1087.424 0.0 0.0 171.16

Receptor 466 29.618 86.004 1068.320 -1087.900 0.0 0.0 171.59

Receptor 467 29.613 85.996 1069.217 -1088.361 0.0 0.0 172.04

Receptor 468 29.608 85.987 1070.121 -1088.805 0.0 0.0 172.51

Anadarko Petroleum Corporation

Air quality Modeling Analysis 18 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 469 29.603 85.978 1071.031 -1089.237 0.0 0.0 172.99

Receptor 470 29.598 85.969 1071.943 -1089.662 0.0 0.0 173.49

Receptor 471 29.593 85.961 1072.864 -1090.070 0.0 0.0 174.01

Receptor 472 29.589 85.952 1073.789 -1090.469 0.0 0.0 174.54

Receptor 473 29.580 85.949 1074.192 -1091.391 0.0 0.0 174.35

Receptor 474 29.572 85.946 1074.583 -1092.323 0.0 0.0 174.15

Receptor 475 29.563 85.943 1074.979 -1093.252 0.0 0.0 173.96

Receptor 476 29.554 85.940 1075.390 -1094.176 0.0 0.0 173.79

Receptor 477 29.546 85.937 1075.813 -1095.093 0.0 0.0 173.64

Receptor 478 29.537 85.933 1076.248 -1096.005 0.0 0.0 173.51

Receptor 479 29.529 85.930 1076.690 -1096.914 0.0 0.0 173.40

Receptor 480 29.520 85.927 1077.141 -1097.818 0.0 0.0 173.30

Receptor 481 29.512 85.923 1077.595 -1098.721 0.0 0.0 173.20

Receptor 482 29.503 85.920 1078.038 -1099.629 0.0 0.0 173.11

Receptor 483 29.495 85.916 1078.496 -1100.529 0.0 0.0 173.03

Receptor 484 29.486 85.913 1078.967 -1101.424 0.0 0.0 172.98

Receptor 485 29.478 85.909 1079.441 -1102.316 0.0 0.0 172.93

Receptor 486 29.469 85.905 1079.926 -1103.203 0.0 0.0 172.90

Receptor 487 29.461 85.901 1080.412 -1104.089 0.0 0.0 172.88

Receptor 488 29.453 85.897 1080.910 -1104.968 0.0 0.0 172.88

Receptor 489 29.445 85.893 1081.422 -1105.839 0.0 0.0 172.90

Receptor 490 29.436 85.889 1081.946 -1106.703 0.0 0.0 172.95

Receptor 491 29.428 85.884 1082.483 -1107.559 0.0 0.0 173.01

Receptor 492 29.420 85.880 1083.033 -1108.406 0.0 0.0 173.09

Receptor 493 29.412 85.875 1083.596 -1109.245 0.0 0.0 173.20

Receptor 494 29.404 85.871 1084.164 -1110.080 0.0 0.0 173.31

Receptor 495 29.396 85.866 1084.740 -1110.911 0.0 0.0 173.45

Receptor 496 29.388 85.861 1085.325 -1111.734 0.0 0.0 173.60

Receptor 497 29.380 85.856 1085.920 -1112.550 0.0 0.0 173.76

Receptor 498 29.372 85.851 1086.528 -1113.357 0.0 0.0 173.95

Receptor 499 29.365 85.845 1087.148 -1114.154 0.0 0.0 174.16

Receptor 500 29.357 85.840 1087.778 -1114.944 0.0 0.0 174.39

Receptor 501 29.349 85.834 1088.418 -1115.726 0.0 0.0 174.63

Receptor 502 29.342 85.829 1089.065 -1116.501 0.0 0.0 174.89

Receptor 503 29.334 85.823 1089.711 -1117.277 0.0 0.0 175.16

Receptor 504 29.327 85.818 1090.363 -1118.049 0.0 0.0 175.43

Anadarko Petroleum Corporation

Air quality Modeling Analysis 19 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 505 29.319 85.812 1091.027 -1118.810 0.0 0.0 175.73

Receptor 506 29.312 85.806 1091.703 -1119.560 0.0 0.0 176.05

Receptor 507 29.305 85.800 1092.392 -1120.299 0.0 0.0 176.39

Receptor 508 29.297 85.794 1093.092 -1121.027 0.0 0.0 176.75

Receptor 509 29.290 85.787 1093.804 -1121.742 0.0 0.0 177.13

Receptor 510 29.283 85.781 1094.523 -1122.452 0.0 0.0 177.52

Receptor 511 29.276 85.774 1095.249 -1123.153 0.0 0.0 177.93

Receptor 512 29.269 85.768 1095.984 -1123.845 0.0 0.0 178.35

Receptor 513 29.262 85.761 1096.728 -1124.528 0.0 0.0 178.79

Receptor 514 29.256 85.754 1097.485 -1125.196 0.0 0.0 179.26

Receptor 515 29.249 85.747 1098.253 -1125.851 0.0 0.0 179.74

Receptor 516 29.242 85.740 1099.029 -1126.496 0.0 0.0 180.24

Receptor 517 29.236 85.733 1099.816 -1127.129 0.0 0.0 180.75

Receptor 518 29.230 85.726 1100.612 -1127.748 0.0 0.0 181.29

Receptor 519 29.223 85.718 1101.419 -1128.354 0.0 0.0 181.84

Receptor 520 29.217 85.711 1102.238 -1128.944 0.0 0.0 182.41

Receptor 521 29.211 85.703 1103.064 -1129.524 0.0 0.0 183.00

Receptor 522 29.205 85.695 1103.899 -1130.089 0.0 0.0 183.61

Receptor 523 29.199 85.688 1104.745 -1130.640 0.0 0.0 184.23

Receptor 524 29.194 85.680 1105.600 -1131.175 0.0 0.0 184.87

Receptor 525 29.188 85.671 1106.465 -1131.694 0.0 0.0 185.52

Receptor 526 29.183 85.663 1107.338 -1132.199 0.0 0.0 186.20

Receptor 527 29.177 85.655 1108.221 -1132.687 0.0 0.0 186.89

Receptor 528 29.172 85.646 1109.112 -1133.159 0.0 0.0 187.59

Receptor 529 29.167 85.638 1110.011 -1133.616 0.0 0.0 188.31

Receptor 530 29.162 85.629 1110.918 -1134.056 0.0 0.0 189.05

Receptor 531 29.158 85.621 1111.833 -1134.479 0.0 0.0 189.80

Receptor 532 29.153 85.612 1112.757 -1134.885 0.0 0.0 190.57

Receptor 533 29.148 85.603 1113.687 -1135.275 0.0 0.0 191.34

Receptor 534 29.144 85.594 1114.623 -1135.647 0.0 0.0 192.14

Receptor 535 29.140 85.585 1115.567 -1136.001 0.0 0.0 192.94

Receptor 536 29.136 85.576 1116.517 -1136.338 0.0 0.0 193.76

Receptor 537 29.132 85.566 1117.473 -1136.656 0.0 0.0 194.60

Receptor 538 29.128 85.557 1118.436 -1136.956 0.0 0.0 195.44

Receptor 539 29.125 85.547 1119.403 -1137.237 0.0 0.0 196.30

Receptor 540 29.121 85.538 1120.376 -1137.500 0.0 0.0 197.16

Anadarko Petroleum Corporation

Air quality Modeling Analysis 20 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 541 29.118 85.528 1121.354 -1137.745 0.0 0.0 198.04

Receptor 542 29.115 85.519 1122.336 -1137.970 0.0 0.0 198.93

Receptor 543 29.112 85.509 1123.322 -1138.175 0.0 0.0 199.83

Receptor 544 29.109 85.499 1124.312 -1138.360 0.0 0.0 200.74

Receptor 545 29.107 85.489 1125.306 -1138.525 0.0 0.0 201.66

Receptor 546 29.104 85.479 1126.302 -1138.671 0.0 0.0 202.58

Receptor 547 29.102 85.470 1127.302 -1138.798 0.0 0.0 203.52

Receptor 548 29.100 85.460 1128.303 -1138.906 0.0 0.0 204.46

Receptor 549 29.098 85.449 1129.307 -1138.992 0.0 0.0 205.41

Receptor 550 29.096 85.439 1130.312 -1139.059 0.0 0.0 206.37

Receptor 551 29.095 85.429 1131.318 -1139.105 0.0 0.0 207.34

Receptor 552 29.093 85.419 1132.325 -1139.131 0.0 0.0 208.31

Receptor 553 29.092 85.409 1133.332 -1139.136 0.0 0.0 209.28

Receptor 554 29.091 85.399 1134.339 -1139.122 0.0 0.0 210.26

Receptor 555 29.090 85.389 1135.345 -1139.088 0.0 0.0 211.25

Receptor 556 29.090 85.378 1136.351 -1139.033 0.0 0.0 212.24

Receptor 557 29.089 85.368 1137.354 -1138.958 0.0 0.0 213.23

Receptor 558 29.089 85.358 1138.357 -1138.862 0.0 0.0 214.23

Receptor 559 29.089 85.347 1139.358 -1138.746 0.0 0.0 215.23

Receptor 560 29.089 85.337 1140.355 -1138.608 0.0 0.0 216.23

Receptor 561 29.088 85.327 1141.327 -1138.641 0.0 0.0 217.16

Receptor 562 29.083 85.319 1142.252 -1139.039 0.0 0.0 217.97

Receptor 563 29.079 85.310 1143.187 -1139.420 0.0 0.0 218.79

Receptor 564 29.074 85.301 1144.127 -1139.783 0.0 0.0 219.62

Receptor 565 29.070 85.291 1145.074 -1140.128 0.0 0.0 220.47

Receptor 566 29.066 85.282 1146.027 -1140.456 0.0 0.0 221.32

Receptor 567 29.062 85.273 1146.987 -1140.765 0.0 0.0 222.19

Receptor 568 29.059 85.264 1147.951 -1141.056 0.0 0.0 223.07

Receptor 569 29.055 85.254 1148.922 -1141.328 0.0 0.0 223.95

Receptor 570 29.052 85.245 1149.898 -1141.580 0.0 0.0 224.85

Receptor 571 29.049 85.235 1150.878 -1141.813 0.0 0.0 225.76

Receptor 572 29.046 85.225 1151.862 -1142.028 0.0 0.0 226.68

Receptor 573 29.043 85.216 1152.851 -1142.223 0.0 0.0 227.60

Receptor 574 29.040 85.206 1153.843 -1142.400 0.0 0.0 228.54

Receptor 575 29.037 85.196 1154.838 -1142.555 0.0 0.0 229.48

Receptor 576 29.035 85.186 1155.836 -1142.692 0.0 0.0 230.43

Anadarko Petroleum Corporation

Air quality Modeling Analysis 21 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 577 29.033 85.176 1156.837 -1142.809 0.0 0.0 231.38

Receptor 578 29.031 85.166 1157.840 -1142.905 0.0 0.0 232.35

Receptor 579 29.029 85.156 1158.844 -1142.980 0.0 0.0 233.31

Receptor 580 29.027 85.146 1159.850 -1143.036 0.0 0.0 234.29

Receptor 581 29.026 85.136 1160.856 -1143.075 0.0 0.0 235.27

Receptor 582 29.024 85.126 1161.863 -1143.101 0.0 0.0 236.25

Receptor 583 29.023 85.116 1162.870 -1143.106 0.0 0.0 237.23

Receptor 584 29.022 85.105 1163.877 -1143.091 0.0 0.0 238.22

Receptor 585 29.021 85.095 1164.883 -1143.057 0.0 0.0 239.22

Receptor 586 29.021 85.085 1165.889 -1143.002 0.0 0.0 240.22

Receptor 587 29.020 85.075 1166.893 -1142.927 0.0 0.0 241.21

Receptor 588 29.020 85.064 1167.896 -1142.831 0.0 0.0 242.22

Receptor 589 29.020 85.054 1168.897 -1142.715 0.0 0.0 243.22

Receptor 590 29.020 85.044 1169.895 -1142.582 0.0 0.0 244.23

Receptor 591 29.020 85.034 1170.890 -1142.428 0.0 0.0 245.23

Receptor 592 29.020 85.023 1171.883 -1142.257 0.0 0.0 246.24

Receptor 593 29.021 85.013 1172.871 -1142.066 0.0 0.0 247.25

Receptor 594 29.021 85.003 1173.856 -1141.855 0.0 0.0 248.25

Receptor 595 29.022 84.993 1174.836 -1141.625 0.0 0.0 249.26

Receptor 596 29.023 84.982 1175.812 -1141.376 0.0 0.0 250.27

Receptor 597 29.025 84.972 1176.783 -1141.109 0.0 0.0 251.27

Receptor 598 29.026 84.962 1177.748 -1140.820 0.0 0.0 252.27

Receptor 599 29.028 84.952 1178.707 -1140.512 0.0 0.0 253.27

Receptor 600 29.029 84.942 1179.659 -1140.186 0.0 0.0 254.27

Receptor 601 29.031 84.932 1180.606 -1139.841 0.0 0.0 255.27

Receptor 602 29.033 84.922 1181.545 -1139.477 0.0 0.0 256.26

Receptor 603 29.036 84.912 1182.484 -1139.113 0.0 0.0 257.25

Receptor 604 29.038 84.902 1183.418 -1138.736 0.0 0.0 258.24

Receptor 605 29.040 84.892 1184.345 -1138.341 0.0 0.0 259.23

Receptor 606 29.043 84.882 1185.265 -1137.931 0.0 0.0 260.21

Receptor 607 29.045 84.873 1186.175 -1137.499 0.0 0.0 261.19

Receptor 608 29.048 84.863 1187.087 -1137.072 0.0 0.0 262.17

Receptor 609 29.051 84.853 1188.002 -1136.650 0.0 0.0 263.15

Receptor 610 29.053 84.843 1188.914 -1136.221 0.0 0.0 264.13

Receptor 611 29.056 84.833 1189.821 -1135.784 0.0 0.0 265.11

Receptor 612 29.059 84.824 1190.720 -1135.330 0.0 0.0 266.08

Anadarko Petroleum Corporation

Air quality Modeling Analysis 22 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 613 29.062 84.814 1191.611 -1134.860 0.0 0.0 267.05

Receptor 614 29.065 84.804 1192.504 -1134.395 0.0 0.0 268.02

Receptor 615 29.068 84.795 1193.412 -1133.958 0.0 0.0 269.00

Receptor 616 29.071 84.785 1194.311 -1133.503 0.0 0.0 269.97

Receptor 617 29.074 84.775 1195.201 -1133.031 0.0 0.0 270.94

Receptor 618 29.077 84.766 1196.081 -1132.542 0.0 0.0 271.90

Receptor 619 29.081 84.756 1196.954 -1132.037 0.0 0.0 272.86

Receptor 620 29.084 84.747 1197.816 -1131.516 0.0 0.0 273.81

Receptor 621 29.088 84.737 1198.668 -1130.979 0.0 0.0 274.76

Receptor 622 29.092 84.728 1199.510 -1130.425 0.0 0.0 275.70

Receptor 623 29.096 84.719 1200.340 -1129.855 0.0 0.0 276.64

Receptor 624 29.100 84.710 1201.161 -1129.270 0.0 0.0 277.57

Receptor 625 29.105 84.701 1201.970 -1128.669 0.0 0.0 278.49

Receptor 626 29.109 84.692 1202.768 -1128.053 0.0 0.0 279.40

Receptor 627 29.114 84.683 1203.554 -1127.422 0.0 0.0 280.31

Receptor 628 29.118 84.674 1204.328 -1126.776 0.0 0.0 281.21

Receptor 629 29.123 84.666 1205.098 -1126.125 0.0 0.0 282.10

Receptor 630 29.128 84.657 1205.873 -1125.481 0.0 0.0 283.00

Receptor 631 29.133 84.648 1206.641 -1124.828 0.0 0.0 283.90

Receptor 632 29.136 84.639 1207.502 -1124.314 0.0 0.0 284.86

Receptor 633 29.140 84.629 1208.387 -1123.833 0.0 0.0 285.83

Receptor 634 29.143 84.620 1209.264 -1123.337 0.0 0.0 286.80

Receptor 635 29.146 84.610 1210.141 -1122.843 0.0 0.0 287.76

Receptor 636 29.149 84.601 1211.016 -1122.344 0.0 0.0 288.73

Receptor 637 29.153 84.591 1211.881 -1121.828 0.0 0.0 289.69

Receptor 638 29.157 84.582 1212.735 -1121.294 0.0 0.0 290.65

Receptor 639 29.161 84.573 1213.579 -1120.745 0.0 0.0 291.60

Receptor 640 29.164 84.563 1214.414 -1120.181 0.0 0.0 292.54

Receptor 641 29.169 84.554 1215.239 -1119.603 0.0 0.0 293.48

Receptor 642 29.173 84.545 1216.054 -1119.009 0.0 0.0 294.42

Receptor 643 29.177 84.536 1216.860 -1118.405 0.0 0.0 295.34

Receptor 644 29.182 84.527 1217.657 -1117.789 0.0 0.0 296.27

Receptor 645 29.186 84.518 1218.460 -1117.181 0.0 0.0 297.19

Receptor 646 29.191 84.509 1219.256 -1116.563 0.0 0.0 298.12

Receptor 647 29.195 84.500 1220.041 -1115.932 0.0 0.0 299.03

Receptor 648 29.200 84.492 1220.818 -1115.289 0.0 0.0 299.94

Anadarko Petroleum Corporation

Air quality Modeling Analysis 23 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 649 29.205 84.483 1221.583 -1114.634 0.0 0.0 300.85

Receptor 650 29.210 84.474 1222.336 -1113.964 0.0 0.0 301.75

Receptor 651 29.215 84.466 1223.076 -1113.281 0.0 0.0 302.63

Receptor 652 29.220 84.458 1223.805 -1112.584 0.0 0.0 303.52

Receptor 653 29.225 84.449 1224.521 -1111.874 0.0 0.0 304.39

Receptor 654 29.231 84.441 1225.224 -1111.152 0.0 0.0 305.25

Receptor 655 29.237 84.433 1225.918 -1110.420 0.0 0.0 306.11

Receptor 656 29.242 84.425 1226.600 -1109.678 0.0 0.0 306.97

Receptor 657 29.248 84.417 1227.272 -1108.927 0.0 0.0 307.81

Receptor 658 29.254 84.410 1227.932 -1108.164 0.0 0.0 308.65

Receptor 659 29.260 84.402 1228.578 -1107.390 0.0 0.0 309.48

Receptor 660 29.266 84.395 1229.211 -1106.605 0.0 0.0 310.30

Receptor 661 29.272 84.386 1229.921 -1105.906 0.0 0.0 311.17

Receptor 662 29.276 84.377 1230.747 -1105.330 0.0 0.0 312.12

Receptor 663 29.279 84.368 1231.587 -1104.775 0.0 0.0 313.08

Receptor 664 29.283 84.359 1232.436 -1104.234 0.0 0.0 314.04

Receptor 665 29.287 84.349 1233.274 -1103.676 0.0 0.0 315.00

Receptor 666 29.291 84.340 1234.102 -1103.102 0.0 0.0 315.95

Receptor 667 29.295 84.331 1234.919 -1102.513 0.0 0.0 316.90

Receptor 668 29.300 84.322 1235.724 -1101.909 0.0 0.0 317.84

Receptor 669 29.304 84.313 1236.517 -1101.289 0.0 0.0 318.78

Receptor 670 29.309 84.304 1237.300 -1100.654 0.0 0.0 319.70

Receptor 671 29.314 84.295 1238.069 -1100.004 0.0 0.0 320.62

Receptor 672 29.318 84.287 1238.827 -1099.341 0.0 0.0 321.54

Receptor 673 29.324 84.278 1239.573 -1098.663 0.0 0.0 322.45

Receptor 674 29.329 84.270 1240.305 -1097.972 0.0 0.0 323.34

Receptor 675 29.334 84.262 1241.026 -1097.268 0.0 0.0 324.23

Receptor 676 29.337 84.252 1241.924 -1096.858 0.0 0.0 325.21

Receptor 677 29.338 84.242 1242.872 -1096.522 0.0 0.0 326.22

Receptor 678 29.340 84.232 1243.814 -1096.168 0.0 0.0 327.22

Receptor 679 29.342 84.222 1244.748 -1095.794 0.0 0.0 328.22

Receptor 680 29.345 84.212 1245.674 -1095.403 0.0 0.0 329.22

Receptor 681 29.347 84.202 1246.593 -1094.992 0.0 0.0 330.22

Receptor 682 29.350 84.192 1247.503 -1094.563 0.0 0.0 331.22

Receptor 683 29.353 84.182 1248.404 -1094.115 0.0 0.0 332.21

Receptor 684 29.356 84.173 1249.296 -1093.651 0.0 0.0 333.20

Anadarko Petroleum Corporation

Air quality Modeling Analysis 24 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 685 29.359 84.163 1250.180 -1093.170 0.0 0.0 334.18

Receptor 686 29.362 84.153 1251.054 -1092.670 0.0 0.0 335.16

Receptor 687 29.366 84.144 1251.918 -1092.154 0.0 0.0 336.14

Receptor 688 29.369 84.134 1252.772 -1091.622 0.0 0.0 337.11

Receptor 689 29.373 84.125 1253.615 -1091.073 0.0 0.0 338.08

Receptor 690 29.377 84.116 1254.448 -1090.508 0.0 0.0 339.04

Receptor 691 29.381 84.107 1255.270 -1089.926 0.0 0.0 339.99

Receptor 692 29.385 84.098 1256.080 -1089.329 0.0 0.0 340.94

Receptor 693 29.390 84.089 1256.879 -1088.717 0.0 0.0 341.89

Receptor 694 29.394 84.080 1257.667 -1088.090 0.0 0.0 342.83

Receptor 695 29.399 84.071 1258.443 -1087.448 0.0 0.0 343.76

Receptor 696 29.404 84.062 1259.206 -1086.792 0.0 0.0 344.68

Receptor 697 29.409 84.054 1259.958 -1086.123 0.0 0.0 345.60

Receptor 698 29.414 84.045 1260.697 -1085.439 0.0 0.0 346.51

Receptor 699 29.409 84.039 1261.366 -1085.892 0.0 0.0 347.01

Receptor 700 29.401 84.034 1262.025 -1086.656 0.0 0.0 347.41

Receptor 701 29.394 84.028 1262.693 -1087.411 0.0 0.0 347.83

Receptor 702 29.386 84.022 1263.372 -1088.158 0.0 0.0 348.26

Receptor 703 29.379 84.016 1264.062 -1088.894 0.0 0.0 348.71

Receptor 704 29.372 84.010 1264.764 -1089.619 0.0 0.0 349.17

Receptor 705 29.365 84.004 1265.477 -1090.332 0.0 0.0 349.65

Receptor 706 29.357 83.998 1266.203 -1091.032 0.0 0.0 350.15

Receptor 707 29.350 83.991 1266.940 -1091.721 0.0 0.0 350.66

Receptor 708 29.343 83.985 1267.688 -1092.397 0.0 0.0 351.19

Receptor 709 29.337 83.978 1268.446 -1093.063 0.0 0.0 351.73

Receptor 710 29.330 83.971 1269.217 -1093.713 0.0 0.0 352.30

Receptor 711 29.323 83.964 1269.998 -1094.351 0.0 0.0 352.88

Receptor 712 29.317 83.957 1270.789 -1094.976 0.0 0.0 353.47

Receptor 713 29.310 83.950 1271.590 -1095.588 0.0 0.0 354.08

Receptor 714 29.304 83.942 1272.403 -1096.184 0.0 0.0 354.70

Receptor 715 29.297 83.937 1273.076 -1096.898 0.0 0.0 355.17

Receptor 716 29.288 83.933 1273.542 -1097.794 0.0 0.0 355.38

Receptor 717 29.280 83.930 1274.023 -1098.683 0.0 0.0 355.62

Receptor 718 29.272 83.926 1274.516 -1099.564 0.0 0.0 355.87

Receptor 719 29.263 83.922 1275.024 -1100.438 0.0 0.0 356.14

Receptor 720 29.255 83.918 1275.543 -1101.304 0.0 0.0 356.43

Anadarko Petroleum Corporation

Air quality Modeling Analysis 25 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 721 29.247 83.914 1276.077 -1102.161 0.0 0.0 356.73

Receptor 722 29.238 83.910 1276.623 -1103.011 0.0 0.0 357.06

Receptor 723 29.230 83.905 1277.181 -1103.853 0.0 0.0 357.39

Receptor 724 29.222 83.901 1277.751 -1104.687 0.0 0.0 357.75

Receptor 725 29.214 83.896 1278.334 -1105.511 0.0 0.0 358.12

Receptor 726 29.206 83.891 1278.931 -1106.326 0.0 0.0 358.51

Receptor 727 29.198 83.886 1279.540 -1107.131 0.0 0.0 358.91

Receptor 728 29.190 83.881 1280.161 -1107.927 0.0 0.0 359.34

Receptor 729 29.183 83.876 1280.796 -1108.712 0.0 0.0 359.78

Receptor 730 29.175 83.870 1281.443 -1109.488 0.0 0.0 360.23

Receptor 731 29.167 83.865 1282.100 -1110.254 0.0 0.0 360.70

Receptor 732 29.160 83.859 1282.769 -1111.010 0.0 0.0 361.19

Receptor 733 29.153 83.853 1283.452 -1111.753 0.0 0.0 361.70

Receptor 734 29.145 83.848 1284.146 -1112.486 0.0 0.0 362.22

Receptor 735 29.138 83.841 1284.852 -1113.208 0.0 0.0 362.75

Receptor 736 29.131 83.835 1285.569 -1113.918 0.0 0.0 363.31

Receptor 737 29.124 83.829 1286.298 -1114.616 0.0 0.0 363.87

Receptor 738 29.117 83.822 1287.039 -1115.302 0.0 0.0 364.46

Receptor 739 29.110 83.816 1287.789 -1115.975 0.0 0.0 365.06

Receptor 740 29.103 83.809 1288.551 -1116.637 0.0 0.0 365.67

Receptor 741 29.096 83.802 1289.325 -1117.285 0.0 0.0 366.30

Receptor 742 29.090 83.795 1290.109 -1117.920 0.0 0.0 366.94

Receptor 743 29.083 83.788 1290.903 -1118.542 0.0 0.0 367.60

Receptor 744 29.077 83.781 1291.706 -1119.153 0.0 0.0 368.27

Receptor 745 29.070 83.774 1292.467 -1119.813 0.0 0.0 368.89

Receptor 746 29.063 83.768 1293.212 -1120.493 0.0 0.0 369.49

Receptor 747 29.056 83.761 1293.968 -1121.161 0.0 0.0 370.11

Receptor 748 29.049 83.754 1294.737 -1121.816 0.0 0.0 370.75

Receptor 749 29.043 83.747 1295.515 -1122.458 0.0 0.0 371.39

Receptor 750 29.036 83.740 1296.304 -1123.087 0.0 0.0 372.06

Receptor 751 29.030 83.733 1297.103 -1123.702 0.0 0.0 372.73

Receptor 752 29.023 83.726 1297.914 -1124.303 0.0 0.0 373.43

Receptor 753 29.017 83.719 1298.734 -1124.891 0.0 0.0 374.13

Receptor 754 29.011 83.711 1299.564 -1125.463 0.0 0.0 374.85

Receptor 755 29.005 83.703 1300.405 -1126.021 0.0 0.0 375.58

Receptor 756 28.999 83.696 1301.254 -1126.565 0.0 0.0 376.33

Anadarko Petroleum Corporation

Air quality Modeling Analysis 26 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 757 28.993 83.688 1302.071 -1127.137 0.0 0.0 377.04

Receptor 758 28.985 83.684 1302.643 -1127.970 0.0 0.0 377.46

Receptor 759 28.977 83.679 1303.230 -1128.793 0.0 0.0 377.91

Receptor 760 28.969 83.674 1303.829 -1129.607 0.0 0.0 378.37

Receptor 761 28.961 83.669 1304.440 -1130.411 0.0 0.0 378.85

Receptor 762 28.953 83.664 1305.064 -1131.206 0.0 0.0 379.34

Receptor 763 28.945 83.659 1305.702 -1131.989 0.0 0.0 379.85

Receptor 764 28.938 83.654 1306.349 -1132.765 0.0 0.0 380.37

Receptor 765 28.930 83.649 1306.925 -1133.585 0.0 0.0 380.82

Receptor 766 28.921 83.646 1307.352 -1134.501 0.0 0.0 381.11

Receptor 767 28.912 83.643 1307.792 -1135.411 0.0 0.0 381.41

Receptor 768 28.904 83.640 1308.245 -1136.316 0.0 0.0 381.73

Receptor 769 28.895 83.636 1308.711 -1137.213 0.0 0.0 382.07

Receptor 770 28.887 83.633 1309.191 -1138.103 0.0 0.0 382.42

Receptor 771 28.878 83.629 1309.685 -1138.985 0.0 0.0 382.80

Receptor 772 28.870 83.626 1310.191 -1139.860 0.0 0.0 383.18

Receptor 773 28.862 83.622 1310.710 -1140.728 0.0 0.0 383.58

Receptor 774 28.853 83.618 1311.242 -1141.588 0.0 0.0 384.00

Receptor 775 28.845 83.613 1311.786 -1142.440 0.0 0.0 384.44

Receptor 776 28.837 83.609 1312.343 -1143.283 0.0 0.0 384.89

Receptor 777 28.829 83.604 1312.915 -1144.117 0.0 0.0 385.35

Receptor 778 28.821 83.600 1313.498 -1144.943 0.0 0.0 385.84

Receptor 779 28.813 83.595 1314.095 -1145.759 0.0 0.0 386.34

Receptor 780 28.805 83.590 1314.703 -1146.566 0.0 0.0 386.85

Receptor 781 28.797 83.585 1315.324 -1147.364 0.0 0.0 387.38

Receptor 782 28.789 83.580 1315.957 -1148.151 0.0 0.0 387.92

Receptor 783 28.782 83.575 1316.603 -1148.929 0.0 0.0 388.48

Receptor 784 28.774 83.569 1317.260 -1149.697 0.0 0.0 389.05

Receptor 785 28.767 83.564 1317.928 -1150.454 0.0 0.0 389.64

Receptor 786 28.759 83.558 1318.610 -1151.200 0.0 0.0 390.25

Receptor 787 28.752 83.552 1319.303 -1151.935 0.0 0.0 390.86

Receptor 788 28.744 83.546 1320.007 -1152.660 0.0 0.0 391.49

Receptor 789 28.737 83.540 1320.722 -1153.374 0.0 0.0 392.14

Receptor 790 28.730 83.534 1321.448 -1154.076 0.0 0.0 392.80

Receptor 791 28.723 83.527 1322.186 -1154.766 0.0 0.0 393.47

Receptor 792 28.716 83.521 1322.921 -1155.458 0.0 0.0 394.14

Anadarko Petroleum Corporation

Air quality Modeling Analysis 27 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 793 28.709 83.515 1323.643 -1156.165 0.0 0.0 394.80

Receptor 794 28.702 83.508 1324.377 -1156.859 0.0 0.0 395.47

Receptor 795 28.695 83.502 1325.122 -1157.542 0.0 0.0 396.16

Receptor 796 28.688 83.495 1325.878 -1158.211 0.0 0.0 396.86

Receptor 797 28.681 83.489 1326.646 -1158.868 0.0 0.0 397.57

Receptor 798 28.674 83.482 1327.425 -1159.511 0.0 0.0 398.30

Receptor 799 28.668 83.475 1328.214 -1160.141 0.0 0.0 399.04

Receptor 800 28.661 83.468 1329.013 -1160.759 0.0 0.0 399.79

Receptor 801 28.655 83.461 1329.822 -1161.363 0.0 0.0 400.55

Receptor 802 28.649 83.453 1330.642 -1161.951 0.0 0.0 401.33

Receptor 803 28.642 83.446 1331.472 -1162.527 0.0 0.0 402.12

Receptor 804 28.636 83.438 1332.311 -1163.087 0.0 0.0 402.92

Receptor 805 28.631 83.430 1333.160 -1163.634 0.0 0.0 403.73

Receptor 806 28.625 83.423 1334.018 -1164.164 0.0 0.0 404.55

Receptor 807 28.619 83.415 1334.886 -1164.680 0.0 0.0 405.39

Receptor 808 28.613 83.407 1335.763 -1165.180 0.0 0.0 406.23

Receptor 809 28.608 83.399 1336.648 -1165.665 0.0 0.0 407.09

Receptor 810 28.603 83.390 1337.542 -1166.133 0.0 0.0 407.95

Receptor 811 28.598 83.382 1338.444 -1166.585 0.0 0.0 408.83

Receptor 812 28.592 83.373 1339.354 -1167.021 0.0 0.0 409.71

Receptor 813 28.301 83.418 1339.907 -1200.071 0.0 0.0 409.76

Receptor 814 28.310 83.416 1339.914 -1199.057 0.0 0.0 409.74

Receptor 815 28.292 83.419 1339.917 -1201.084 0.0 0.0 409.79

Receptor 816 28.319 83.415 1339.932 -1198.044 0.0 0.0 409.74

Receptor 817 28.283 83.421 1339.941 -1202.097 0.0 0.0 409.85

Receptor 818 28.328 83.413 1339.966 -1197.032 0.0 0.0 409.75

Receptor 819 28.274 83.422 1339.980 -1203.110 0.0 0.0 409.92

Receptor 820 28.337 83.411 1340.014 -1196.020 0.0 0.0 409.78

Receptor 821 28.265 83.423 1340.032 -1204.122 0.0 0.0 410.00

Receptor 822 28.345 83.409 1340.074 -1195.008 0.0 0.0 409.83

Receptor 823 28.256 83.424 1340.097 -1205.133 0.0 0.0 410.10

Receptor 824 28.354 83.406 1340.148 -1193.998 0.0 0.0 409.89

Receptor 825 28.247 83.424 1340.178 -1206.144 0.0 0.0 410.22

Receptor 826 28.363 83.404 1340.238 -1192.989 0.0 0.0 409.97

Receptor 827 28.588 83.365 1340.271 -1167.440 0.0 0.0 410.60

Receptor 828 28.238 83.425 1340.274 -1207.153 0.0 0.0 410.36

Anadarko Petroleum Corporation

Air quality Modeling Analysis 28 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 829 28.372 83.401 1340.342 -1191.982 0.0 0.0 410.07

Receptor 830 28.229 83.425 1340.384 -1208.160 0.0 0.0 410.52

Receptor 831 28.380 83.399 1340.457 -1190.975 0.0 0.0 410.18

Receptor 832 28.220 83.426 1340.507 -1209.166 0.0 0.0 410.68

Receptor 833 28.389 83.396 1340.584 -1189.970 0.0 0.0 410.31

Receptor 834 28.211 83.426 1340.642 -1210.171 0.0 0.0 410.87

Receptor 835 28.398 83.393 1340.729 -1188.968 0.0 0.0 410.45

Receptor 836 28.202 83.426 1340.791 -1211.174 0.0 0.0 411.07

Receptor 837 28.406 83.390 1340.888 -1187.968 0.0 0.0 410.61

Receptor 838 28.193 83.426 1340.955 -1212.174 0.0 0.0 411.28

Receptor 839 28.415 83.387 1341.061 -1186.971 0.0 0.0 410.79

Receptor 840 28.184 83.425 1341.132 -1213.173 0.0 0.0 411.52

Receptor 841 28.583 83.356 1341.196 -1167.842 0.0 0.0 411.50

Receptor 842 28.423 83.383 1341.242 -1185.974 0.0 0.0 410.98

Receptor 843 28.175 83.425 1341.322 -1214.168 0.0 0.0 411.76

Receptor 844 28.432 83.380 1341.417 -1184.977 0.0 0.0 411.17

Receptor 845 28.166 83.424 1341.524 -1215.162 0.0 0.0 412.03

Receptor 846 28.440 83.377 1341.602 -1183.982 0.0 0.0 411.36

Receptor 847 28.157 83.424 1341.737 -1216.153 0.0 0.0 412.30

Receptor 848 28.449 83.373 1341.803 -1182.990 0.0 0.0 411.58

Receptor 849 28.148 83.423 1341.962 -1217.142 0.0 0.0 412.59

Receptor 850 28.457 83.369 1342.019 -1182.001 0.0 0.0 411.81

Receptor 851 28.578 83.348 1342.128 -1168.227 0.0 0.0 412.41

Receptor 852 28.139 83.422 1342.201 -1218.127 0.0 0.0 412.89

Receptor 853 28.466 83.366 1342.251 -1181.015 0.0 0.0 412.07

Receptor 854 28.130 83.421 1342.453 -1219.109 0.0 0.0 413.21

Receptor 855 28.474 83.362 1342.497 -1180.034 0.0 0.0 412.33

Receptor 856 28.121 83.420 1342.708 -1220.091 0.0 0.0 413.54

Receptor 857 28.482 83.358 1342.755 -1179.055 0.0 0.0 412.62

Receptor 858 28.112 83.419 1342.944 -1221.076 0.0 0.0 413.85

Receptor 859 28.490 83.353 1343.025 -1178.080 0.0 0.0 412.91

Receptor 860 28.103 83.419 1343.056 -1222.083 0.0 0.0 414.04

Receptor 861 28.574 83.339 1343.068 -1168.594 0.0 0.0 413.33

Receptor 862 28.094 83.420 1343.179 -1223.090 0.0 0.0 414.24

Receptor 863 28.498 83.349 1343.308 -1177.109 0.0 0.0 413.22

Receptor 864 28.085 83.420 1343.315 -1224.095 0.0 0.0 414.46

Anadarko Petroleum Corporation

Air quality Modeling Analysis 29 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 865 28.076 83.420 1343.467 -1225.098 0.0 0.0 414.69

Receptor 866 28.507 83.345 1343.608 -1176.142 0.0 0.0 413.56

Receptor 867 28.067 83.420 1343.635 -1226.098 0.0 0.0 414.95

Receptor 868 28.058 83.419 1343.816 -1227.096 0.0 0.0 415.21

Receptor 869 28.515 83.340 1343.920 -1175.180 0.0 0.0 413.90

Receptor 870 28.049 83.419 1344.010 -1228.092 0.0 0.0 415.50

Receptor 871 28.569 83.330 1344.013 -1168.944 0.0 0.0 414.26

Receptor 872 28.040 83.418 1344.219 -1229.084 0.0 0.0 415.80

Receptor 873 28.523 83.335 1344.249 -1174.224 0.0 0.0 414.26

Receptor 874 28.031 83.418 1344.440 -1230.074 0.0 0.0 416.11

Receptor 875 28.531 83.330 1344.592 -1173.272 0.0 0.0 414.64

Receptor 876 28.022 83.417 1344.678 -1231.060 0.0 0.0 416.45

Receptor 877 28.013 83.416 1344.930 -1232.042 0.0 0.0 416.80

Receptor 878 28.538 83.325 1344.948 -1172.326 0.0 0.0 415.04

Receptor 879 28.565 83.321 1344.964 -1169.281 0.0 0.0 415.19

Receptor 880 28.004 83.415 1345.195 -1233.022 0.0 0.0 417.16

Receptor 881 28.546 83.320 1345.319 -1171.385 0.0 0.0 415.45

Receptor 882 27.996 83.414 1345.396 -1234.008 0.0 0.0 417.46

Receptor 883 27.987 83.416 1345.398 -1235.023 0.0 0.0 417.57

Receptor 884 27.978 83.417 1345.408 -1236.037 0.0 0.0 417.69

Receptor 885 27.969 83.418 1345.432 -1237.051 0.0 0.0 417.83

Receptor 886 27.960 83.419 1345.462 -1238.065 0.0 0.0 417.98

Receptor 887 27.951 83.421 1345.508 -1239.079 0.0 0.0 418.14

Receptor 888 27.942 83.421 1345.566 -1240.092 0.0 0.0 418.32

Receptor 889 27.933 83.422 1345.637 -1241.104 0.0 0.0 418.51

Receptor 890 28.554 83.315 1345.705 -1170.450 0.0 0.0 415.88

Receptor 891 27.924 83.423 1345.720 -1242.115 0.0 0.0 418.72

Receptor 892 27.915 83.424 1345.820 -1243.125 0.0 0.0 418.95

Receptor 893 28.561 83.312 1345.919 -1169.604 0.0 0.0 416.13

Receptor 894 27.906 83.424 1345.934 -1244.133 0.0 0.0 419.19

Receptor 895 27.897 83.424 1346.058 -1245.140 0.0 0.0 419.44

Receptor 896 27.888 83.424 1346.196 -1246.146 0.0 0.0 419.71

Receptor 897 27.879 83.424 1346.347 -1247.149 0.0 0.0 420.00

Receptor 898 27.870 83.424 1346.509 -1248.151 0.0 0.0 420.30

Receptor 899 27.861 83.424 1346.681 -1249.151 0.0 0.0 420.61

Receptor 900 27.852 83.424 1346.867 -1250.149 0.0 0.0 420.93

Anadarko Petroleum Corporation

Air quality Modeling Analysis 30 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 901 27.843 83.423 1347.061 -1251.145 0.0 0.0 421.27

Receptor 902 27.834 83.423 1347.271 -1252.138 0.0 0.0 421.62

Receptor 903 27.825 83.422 1347.492 -1253.129 0.0 0.0 421.99

Receptor 904 27.816 83.421 1347.730 -1254.116 0.0 0.0 422.37

Receptor 905 27.807 83.420 1347.979 -1255.099 0.0 0.0 422.77

Receptor 906 27.798 83.419 1348.239 -1256.081 0.0 0.0 423.18

Receptor 907 27.789 83.418 1348.509 -1257.059 0.0 0.0 423.60

Receptor 908 27.780 83.416 1348.787 -1258.035 0.0 0.0 424.03

Receptor 909 27.771 83.415 1349.079 -1259.008 0.0 0.0 424.48

Receptor 910 27.762 83.413 1349.385 -1259.975 0.0 0.0 424.94

Receptor 911 27.753 83.412 1349.704 -1260.939 0.0 0.0 425.41

Receptor 912 27.744 83.410 1350.038 -1261.898 0.0 0.0 425.90

Receptor 913 27.736 83.408 1350.381 -1262.853 0.0 0.0 426.40

Receptor 914 27.727 83.406 1350.738 -1263.803 0.0 0.0 426.92

Receptor 915 27.718 83.403 1351.109 -1264.748 0.0 0.0 427.45

Receptor 916 27.709 83.401 1351.491 -1265.689 0.0 0.0 427.99

Receptor 917 27.701 83.398 1351.882 -1266.626 0.0 0.0 428.54

Receptor 918 27.692 83.396 1352.285 -1267.557 0.0 0.0 429.11

Receptor 919 27.683 83.393 1352.699 -1268.484 0.0 0.0 429.68

Receptor 920 27.675 83.390 1353.123 -1269.406 0.0 0.0 430.27

Receptor 921 27.666 83.387 1353.561 -1270.322 0.0 0.0 430.87

Receptor 922 27.657 83.384 1354.012 -1271.231 0.0 0.0 431.48

Receptor 923 27.649 83.381 1354.475 -1272.135 0.0 0.0 432.11

Receptor 924 27.640 83.378 1354.948 -1273.032 0.0 0.0 432.75

Receptor 925 27.632 83.374 1355.434 -1273.924 0.0 0.0 433.40

Receptor 926 27.623 83.371 1355.934 -1274.807 0.0 0.0 434.06

Receptor 927 27.615 83.367 1356.448 -1275.682 0.0 0.0 434.73

Receptor 928 27.607 83.363 1356.965 -1276.555 0.0 0.0 435.41

Receptor 929 27.598 83.359 1357.485 -1277.427 0.0 0.0 436.10

Receptor 930 27.590 83.355 1358.017 -1278.292 0.0 0.0 436.79

Receptor 931 27.582 83.351 1358.563 -1279.147 0.0 0.0 437.50

Receptor 932 27.574 83.347 1359.123 -1279.994 0.0 0.0 438.22

Receptor 933 27.566 83.342 1359.695 -1280.832 0.0 0.0 438.96

Receptor 934 27.557 83.339 1360.185 -1281.703 0.0 0.0 439.62

Receptor 935 27.548 83.338 1360.391 -1282.698 0.0 0.0 440.03

Receptor 936 27.539 83.338 1360.612 -1283.689 0.0 0.0 440.45

Anadarko Petroleum Corporation

Air quality Modeling Analysis 31 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 937 27.530 83.337 1360.846 -1284.678 0.0 0.0 440.89

Receptor 938 27.521 83.336 1361.094 -1285.663 0.0 0.0 441.35

Receptor 939 27.512 83.335 1361.355 -1286.645 0.0 0.0 441.82

Receptor 940 27.503 83.333 1361.631 -1287.623 0.0 0.0 442.30

Receptor 941 27.494 83.332 1361.917 -1288.598 0.0 0.0 442.80

Receptor 942 27.486 83.330 1362.219 -1289.568 0.0 0.0 443.31

Receptor 943 27.477 83.329 1362.531 -1290.535 0.0 0.0 443.83

Receptor 944 27.468 83.327 1362.860 -1291.496 0.0 0.0 444.37

Receptor 945 27.459 83.325 1363.201 -1292.453 0.0 0.0 444.92

Receptor 946 27.450 83.323 1363.558 -1293.404 0.0 0.0 445.49

Receptor 947 27.441 83.321 1363.927 -1294.351 0.0 0.0 446.07

Receptor 948 27.433 83.318 1364.311 -1295.291 0.0 0.0 446.66

Receptor 949 27.424 83.316 1364.706 -1296.227 0.0 0.0 447.27

Receptor 950 27.415 83.313 1365.114 -1297.158 0.0 0.0 447.89

Receptor 951 27.407 83.311 1365.534 -1298.083 0.0 0.0 448.52

Receptor 952 27.398 83.308 1365.970 -1299.001 0.0 0.0 449.16

Receptor 953 27.389 83.305 1366.419 -1299.912 0.0 0.0 449.82

Receptor 954 27.381 83.301 1366.879 -1300.817 0.0 0.0 450.49

Receptor 955 27.372 83.298 1367.353 -1301.716 0.0 0.0 451.17

Receptor 956 27.364 83.295 1367.840 -1302.608 0.0 0.0 451.87

Receptor 957 27.355 83.291 1368.341 -1303.491 0.0 0.0 452.57

Receptor 958 27.347 83.287 1368.857 -1304.367 0.0 0.0 453.29

Receptor 959 27.339 83.283 1369.379 -1305.238 0.0 0.0 454.02

Receptor 960 27.330 83.280 1369.849 -1306.139 0.0 0.0 454.70

Receptor 961 27.322 83.277 1370.331 -1307.033 0.0 0.0 455.40

Receptor 962 27.313 83.273 1370.829 -1307.919 0.0 0.0 456.11

Receptor 963 27.305 83.269 1371.338 -1308.798 0.0 0.0 456.83

Receptor 964 27.297 83.265 1371.860 -1309.670 0.0 0.0 457.56

Receptor 965 27.288 83.261 1372.394 -1310.534 0.0 0.0 458.30

Receptor 966 27.280 83.257 1372.942 -1311.389 0.0 0.0 459.05

Receptor 967 27.272 83.253 1373.503 -1312.235 0.0 0.0 459.82

Receptor 968 27.264 83.249 1374.071 -1313.078 0.0 0.0 460.59

Receptor 969 27.256 83.244 1374.648 -1313.914 0.0 0.0 461.37

Receptor 970 27.248 83.240 1375.239 -1314.740 0.0 0.0 462.16

Receptor 971 27.240 83.235 1375.843 -1315.556 0.0 0.0 462.97

Receptor 972 27.232 83.230 1376.460 -1316.364 0.0 0.0 463.78

Anadarko Petroleum Corporation

Air quality Modeling Analysis 32 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 973 27.224 83.225 1377.088 -1317.161 0.0 0.0 464.60

Receptor 974 27.216 83.220 1377.728 -1317.950 0.0 0.0 465.43

Receptor 975 27.208 83.216 1378.297 -1318.788 0.0 0.0 466.21

Receptor 976 27.200 83.212 1378.817 -1319.661 0.0 0.0 466.95

Receptor 977 27.191 83.208 1379.350 -1320.526 0.0 0.0 467.71

Receptor 978 27.183 83.204 1379.899 -1321.381 0.0 0.0 468.47

Receptor 979 27.175 83.200 1380.459 -1322.229 0.0 0.0 469.25

Receptor 980 27.167 83.195 1381.031 -1323.069 0.0 0.0 470.04

Receptor 981 27.159 83.191 1381.616 -1323.900 0.0 0.0 470.83

Receptor 982 27.151 83.186 1382.214 -1324.721 0.0 0.0 471.64

Receptor 983 27.143 83.181 1382.824 -1325.534 0.0 0.0 472.46

Receptor 984 27.135 83.176 1383.446 -1326.337 0.0 0.0 473.29

Receptor 985 27.127 83.171 1384.081 -1327.130 0.0 0.0 474.12

Receptor 986 27.120 83.166 1384.729 -1327.912 0.0 0.0 474.97

Receptor 987 27.112 83.161 1385.390 -1328.684 0.0 0.0 475.83

Receptor 988 27.104 83.155 1386.062 -1329.445 0.0 0.0 476.69

Receptor 989 27.097 83.150 1386.745 -1330.196 0.0 0.0 477.57

Receptor 990 27.089 83.144 1387.442 -1330.936 0.0 0.0 478.45

Receptor 991 27.082 83.138 1388.149 -1331.664 0.0 0.0 479.34

Receptor 992 27.075 83.132 1388.868 -1332.381 0.0 0.0 480.24

Receptor 993 27.068 83.126 1389.598 -1333.087 0.0 0.0 481.15

Receptor 994 27.061 83.120 1390.341 -1333.779 0.0 0.0 482.06

Receptor 995 27.054 83.114 1391.094 -1334.461 0.0 0.0 482.98

Receptor 996 27.047 83.107 1391.857 -1335.130 0.0 0.0 483.91

Receptor 997 27.040 83.100 1392.632 -1335.786 0.0 0.0 484.85

Receptor 998 27.033 83.094 1393.417 -1336.429 0.0 0.0 485.79

Receptor 999 27.027 83.087 1394.213 -1337.058 0.0 0.0 486.74

Receptor 1000 27.019 83.081 1394.912 -1337.780 0.0 0.0 487.62

Receptor 1001 27.011 83.077 1395.479 -1338.624 0.0 0.0 488.42

Receptor 1002 27.003 83.072 1396.059 -1339.459 0.0 0.0 489.23

Receptor 1003 26.995 83.068 1396.653 -1340.284 0.0 0.0 490.05

Receptor 1004 26.987 83.063 1397.260 -1341.100 0.0 0.0 490.88

Receptor 1005 26.979 83.058 1397.878 -1341.906 0.0 0.0 491.71

Receptor 1006 26.972 83.053 1398.509 -1342.703 0.0 0.0 492.56

Receptor 1007 26.964 83.048 1399.152 -1343.490 0.0 0.0 493.42

Receptor 1008 26.956 83.043 1399.808 -1344.266 0.0 0.0 494.28

Anadarko Petroleum Corporation

Air quality Modeling Analysis 33 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 1009 26.948 83.037 1400.475 -1345.032 0.0 0.0 495.15

Receptor 1010 26.941 83.032 1401.155 -1345.788 0.0 0.0 496.04

Receptor 1011 26.933 83.026 1401.846 -1346.532 0.0 0.0 496.93

Receptor 1012 26.926 83.020 1402.549 -1347.266 0.0 0.0 497.83

Receptor 1013 26.919 83.015 1403.265 -1347.987 0.0 0.0 498.73

Receptor 1014 26.912 83.008 1403.992 -1348.697 0.0 0.0 499.65

Receptor 1015 26.904 83.003 1404.698 -1349.420 0.0 0.0 500.55

Receptor 1016 26.896 82.999 1405.187 -1350.312 0.0 0.0 501.30

Receptor 1017 26.887 82.996 1405.691 -1351.195 0.0 0.0 502.06

Receptor 1018 26.879 82.992 1406.208 -1352.072 0.0 0.0 502.83

Receptor 1019 26.871 82.988 1406.737 -1352.940 0.0 0.0 503.61

Receptor 1020 26.863 82.984 1407.277 -1353.802 0.0 0.0 504.40

Receptor 1021 26.854 82.980 1407.833 -1354.654 0.0 0.0 505.20

Receptor 1022 26.846 82.976 1408.331 -1355.541 0.0 0.0 505.96

Receptor 1023 26.837 82.973 1408.834 -1356.425 0.0 0.0 506.73

Receptor 1024 26.829 82.969 1409.347 -1357.303 0.0 0.0 507.50

Receptor 1025 26.821 82.965 1409.874 -1358.174 0.0 0.0 508.29

Receptor 1026 26.813 82.961 1410.413 -1359.037 0.0 0.0 509.08

Receptor 1027 26.804 82.957 1410.966 -1359.890 0.0 0.0 509.89

Receptor 1028 26.796 82.953 1411.532 -1360.736 0.0 0.0 510.70

Receptor 1029 26.788 82.949 1412.112 -1361.572 0.0 0.0 511.53

Receptor 1030 26.780 82.944 1412.703 -1362.399 0.0 0.0 512.37

Receptor 1031 26.772 82.939 1413.307 -1363.218 0.0 0.0 513.21

Receptor 1032 26.764 82.935 1413.921 -1364.029 0.0 0.0 514.06

Receptor 1033 26.756 82.930 1414.546 -1364.830 0.0 0.0 514.92

Receptor 1034 26.748 82.925 1415.181 -1365.625 0.0 0.0 515.79

Receptor 1035 26.741 82.920 1415.826 -1366.411 0.0 0.0 516.67

Receptor 1036 26.733 82.914 1416.484 -1367.187 0.0 0.0 517.55

Receptor 1037 26.725 82.909 1417.124 -1367.976 0.0 0.0 518.42

Receptor 1038 26.717 82.905 1417.698 -1368.815 0.0 0.0 519.25

Receptor 1039 26.709 82.900 1418.283 -1369.648 0.0 0.0 520.09

Receptor 1040 26.701 82.896 1418.878 -1370.473 0.0 0.0 520.93

Receptor 1041 26.693 82.891 1419.486 -1371.289 0.0 0.0 521.78

Receptor 1042 26.685 82.886 1420.101 -1372.099 0.0 0.0 522.64

Receptor 1043 26.677 82.882 1420.726 -1372.902 0.0 0.0 523.51

Receptor 1044 26.669 82.877 1421.364 -1373.694 0.0 0.0 524.38

Anadarko Petroleum Corporation

Air quality Modeling Analysis 34 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Receptor Id.

Latitude (deg)

(North) 1

Longitude (deg)

(West) 1

LCC Coordinates

X (km)

LCC Coordinates

Y (km)

Elevation 1

(meters)

Height

(meters)

Distance from the 

Drillship (km)

Class II Modeling Receptor placed 25- miles from nearest State Seaward Boundary- Receptor Information

Anadarko Petroleum Corporation

Receptor 1045 26.662 82.871 1422.015 -1374.476 0.0 0.0 525.27

Receptor 1046 26.654 82.866 1422.679 -1375.246 0.0 0.0 526.16

1

 Lat/ Long coordinates for receptors were obtained from EPA Region IV. Based on Personal Communication, E-mail from Mr. Stan Krivo 

(EPA Region IV) and Mr. Rahul Pendse (Trinity) on October 1, 2012. The elevation was set to zero since these receptors will be above water.

Anadarko Petroleum Corporation

Air quality Modeling Analysis 35 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Class II Receptor

8/24/2013
Emissions Speciation Percentage 

(% of Total PM10) 

 Actual Emissions 

(Max. lb/hr) Reference

Total PM10 (TPM10) 100% 27.00 1

Condensable portion of TPM10 (CPM) 13.4% 3.63 2

Organic portion of CPM (SOA) 13.4% 3.63 3

Inorganic portion of CPM 0.0% 0.00 3

Filterable portion of TPM10 (FPM10) 86.6% 23.37 2

Coarse Filterable (PMC) 3.0% 0.80 4

Fine Filterable (PMF) 83.6% 22.57 2

Elemental Carbon (EC) 0.0% 0.00 5

5. Elemental Carbon has been assumed to be 0% due to lack of representative data or emission factors.

3. No representative data or emission factors were available for determining inorganic (SO4 and NO3) condensable 

emissions. Per AP-42, Table 3.4-1 Gaseous Emission Factors for Large Stationary Diesel and All Stationary DualFuel Engines, footnote d, all sulfur in the fuel is assumed to be converted to SO2

. Therefore, inorganic condensable 

emissions from the MODU were assumed to be zero. Based on guidance provided in Procedure for Speciation of 

Emissions for VISTAS BART Modeling, July 18, 2006, 100% of non-H2SO4 condensable mass was assumed to be 

organic condensables (SOA).

4. The percentage of Coarse filterable (PMC) in TPM10 was calculated as the difference between the percentages of 

FPM10 and Fine Filterable (PMF).

Drillship Particulate Emissions Speciation

 Anadarko Petroleum Corporation

1. Total PM10 (TPM10) emissions from the MODU was calculated as the sum total of TPM10 emissions from all 

emission sources, which primarily comprise of diesel-fired engines. TPM10 emissions for the individual emission 

sources were calculated as the sum of filterable PM10 (FPM10) emissions and condensable particulate emissions 

(CPM).

2. AP-42, Table 3.4-2 Particulate and Particle-sizing Emission Factors for Large Uncontrolled Stationary Diesel 

Engines was used to speciate TPM10 into FPM10 and CPM. Filterable particulate < 3 um was used as a surrogate for 

PMF/ Filterable PM2.5. 

Anadarko Petroleum Corporation

Air quality Modeling Analysis 36 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - DS PM Speciation

8/24/2013
Emissions Speciation Percentage 

(% of Total PM10) 

 Actual Emissions 

(Max. lb/hr) Reference

Total PM10 (TPM10) 100% 3.00 1

Condensable portion of TPM10 (CPM) 13.4% 0.40 2

Organic portion of CPM (SOA) 13.4% 0.40 3

Inorganic portion of CPM 0.0% 0.00 3

Filterable portion of TPM10 (FPM10) 86.6% 2.60 2

Coarse Filterable (PMC) 3.0% 0.09 4

Fine Filterable (PMF) 83.6% 2.51 2

Elemental Carbon (EC) 0.0% 0.00 5

5. Elemental Carbon has been assumed to be 0% due to lack of representative data or emission factors.

3. No representative data or emission factors were available for determining inorganic (SO4 and NO3) condensable 

emissions. Per AP-42, Table 3.4-1 Gaseous Emission Factors for Large Stationary Diesel and All Stationary DualFuel Engines, footnote d, all sulfur in the fuel is assumed to be converted to SO2

. Therefore, inorganic condensable 

emissions from the MODU were assumed to be zero. Based on guidance provided in Procedure for Speciation of 

Emissions for VISTAS BART Modeling, July 18, 2006, 100% of non-H2SO4 condensable mass was assumed to be 

organic condensables (SOA).

4. The percentage of Coarse filterable (PMC) in TPM10 was calculated as the difference between the percentages of 

FPM10 and Fine Filterable (PMF).

SuppO\%RDWParticulate Emissions Speciation

 Anadarko Petroleum Corporation

1. Total PM10 (TPM10) emissions from the MODU was calculated as the sum total of TPM10 emissions from all 

emission sources, which primarily comprise of diesel-fired engines. TPM10 emissions for the individual emission 

sources were calculated as the sum of filterable PM10 (FPM10) emissions and condensable particulate emissions 

(CPM).

2. AP-42, Table 3.4-2 Particulate and Particle-sizing Emission Factors for Large Uncontrolled Stationary Diesel 

Engines was used to speciate TPM10 into FPM10 and CPM. Filterable particulate < 3 um was used as a surrogate for 

PMF/ Filterable PM2.5. 

Anadarko Petroleum Corporation

Air quality Modeling Analysis 37 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - SV PM Speciation

8/24/2013
Species

Dry Deposition Phase 

(Gas/ Particle)1

Wet Deposition 

Modeled? (Yes/ No)2

Geometric Mass 

Mean Diameter 3 

(microns)

Geometric Standard 

Deviation 3 

(microns)

SO2 Gas Yes N/A N/A

SO4 Particle Yes 0.48 2.0

NOx Gas No N/A N/A

HNO3 Gas Yes N/A N/A

NO3 Particle Yes 0.48 2.0

SOA Particle Yes 0.48 2.0

PMC Particle Yes 6.5 0.0

PMF Particle Yes 1.75 0.0

Anadarko Petroleum Corporation

Deposition Analysis - Input Parameters

2 Both wet and dry fluxes have been estimated for all pollutant species except NOx, in accordance with the FLAG Phase I 

revised report. Both dry and wet deposition were disabled for NOx and PM10 Increment Modeling.

3

 The average particle diameter for each speciated particulate (PM) category has been taken as the geometric mass mean 

diameter for that category. Geometric standard deviation has been assumed to be zero for all PM categories. Default 

CALPUFF values have been used for SOA, SO4, and NO3 particles.

1 Gas phase deposition has been analyzed for SO2

, NOx, and HNO3, and particle phase deposition for SO4, NO3, and PM 

categories, in accordance with the U.S. Forest Service – Air Quality Program, National Park Service – Air Resources 

Division, U.S. Fish and Wildlife Service – Air Quality Branch, Phase I Report of the Federal Land Managers’ Air Quality 

Related Values Workgroup (FLAG), October 2010. (FLAG Phase I Revised).

Anadarko Petroleum Corporation

Air quality Modeling Analysis 39 of 39

Ana_EPA It_A - Class II Modeling Inputs v1 - Deposition

8/24/2013
Anadarko Petroleum Corporation Trinity Consultants 

APPENDIX E: MODEL FILES ON DVD 

 
Anadarko Petroleum Corporation Trinity Consultants 

LIST OF FLM CLASS I AQRV MODELING FILES ON DVD – DRILLING 

OPERATIONS 

The DVD included with this appendix contains all of the input and output data files used to 

generate the results from the FLM Class I AQRV analysis presented in this report. The 

following section provides a description of the contents of each folder included in the 

attached DVD. 

Breton NWR Files 

1. CALPUFF Input and Output Files 

B01ITA.cpi – Input file for year 2001. 

b01ita.cpl – Output file for year 2001. 

B02ITa.cpi – Input file for year 2002. 

b02ita.cpl – Output file for year 2002. 

03.cpi – Input file for year 2003. 

b03ita.cpl – Output file for year 2003. 

2. POSTUTIL Input and Output Files 

b01NSa.inp – Input file for 2001 to combine wet and dry fluxes for N and S deposition. 

b01nsa.lst – Output file for 2001 to combine wet and dry fluxes for N and S deposition. 

b02NSa.inp – Input file for 2002 to combine wet and dry fluxes for N and S deposition. 

b02nsa.lst – Output file for 2002 to combine wet and dry fluxes for N and S deposition. 

b03NSa.inp – Input file for 2003 to combine wet and dry fluxes for N and S deposition. 

b03nsa.lst – Output file for 2003 to combine wet and dry fluxes for N and S deposition. 

b01alma.inp – Input file for 2001 to perform Ammonia Limiting method (ALM) 

b01alma.lst – Output file for 2001 to perform Ammonia Limiting method (ALM) 

b02alma.inp – Input file for 2002 to perform Ammonia Limiting method (ALM) 

b02alma.lst – Output file for 2002 to perform Ammonia Limiting method (ALM) 

b03alma.inp – Input file for 2003 to perform Ammonia Limiting method (ALM) 

b03alma.lst – Output file for 2003 to perform Ammonia Limiting method (ALM) 

3. &$LPOST Input and Output Files 

B01Na.inp – Input file for 2001 to calculate nitrogen deposition. 

B01NA.lst – Output file for 2001 to calculate nitrogen deposition. 

B02Na.inp – Input file for 2002 to calculate nitrogen deposition. 

B02NA.lst – Output file for 2002 to calculate nitrogen deposition. 

B03Na.inp – Input file for 2003 to calculate nitrogen deposition. 

B03NA.lst – Output file for 2003 to calculate nitrogen deposition. 

B01Sa.inp – Input file for 2001 to calculate sulfur deposition. 

B01SA.lst – Output file for 2001 to calculate sulfur deposition. 

B02Sa.inp – Input file for 2002 to calculate sulfur deposition. 

B02SA.lst – Output file for 2002 to calculate sulfur deposition. 

B03Sa.inp – Input file for 2003 to calculate sulfur deposition. 
Anadarko Petroleum Corporation Trinity Consultants 

B03SA.lst – Output file for 2003 to calculate sulfur deposition. 

B01V8A.inp – Input file for 2001 to calculate Method 8 visibility. 

B01V8A.lst – Output file for 2001 to calculate Method 8 visibility. 

B02V8A.inp – Input file for 2002 to calculate Method 8 visibility. 

B02V8A.lst – Output file for 2002 to calculate Method 8 visibility. 

B03V8a.inp – Input file for 2003 to calculate Method 8 visibility. 

B03V8A.lst – Output file for 2003 to calculate Method 8 visibility. 

St. Marks NWR and Bradwell bay Wilderness Files 

1. CALPUFF Input and Output Files 

STBB01A.cpi – Input file for year 2001. 

stbb01a.cpl – Output file for year 2001. 

SMBB02A.cpi – Input file for year 2002. 

smbb02a.cpl – Output file for year 2002. 

SMBB03A.cpi – Input file for year 2003. 

smbb03a.cpl – Output file for year 2003. 

2. POSTUTIL Input and Output Files 

SB01NSa.inp – Input file for 2001 to combine wet and dry fluxes for N and S deposition. 

sb01nsa.lst – Output file for 2001 to combine wet and dry fluxes for N and S deposition. 

SB02NSa.inp – Input file for 2002 to combine wet and dry fluxes for N and S deposition. 

sb02nsa.lst – Output file for 2002 to combine wet and dry fluxes for N and S deposition. 

SB03NSa.inp – Input file for 2003 to combine wet and dry fluxes for N and S deposition. 

sb03nsa.lst – Output file for 2003 to combine wet and dry fluxes for N and S deposition. 

3. CALPOST Input and Output Files 

SB01Na.inp – Input file for 2001 to calculate nitrogen deposition. 

SB01NA.lst – Output file for 2001 to calculate nitrogen deposition. 

SB02Na.inp – Input file for 2002 to calculate nitrogen deposition. 

SB02NA.lst – Output file for 2002 to calculate nitrogen deposition. 

SB03Na.inp – Input file for 2003 to calculate nitrogen deposition. 

SB03NA.lst – Output file for 2003 to calculate nitrogen deposition. 

SB01Sa.inp – Input file for 2001 to calculate sulfur deposition. 

SB01SA.lst – Output file for 2001 to calculate sulfur deposition. 

SB02Sa.inp – Input file for 2002 to calculate sulfur deposition. 

SB02SA.lst – Output file for 2002 to calculate sulfur deposition. 

SB03Sa.inp – Input file for 2003 to calculate sulfur deposition. 

SB03SA.lst – Output file for 2003 to calculate sulfur deposition. 

SB01V8a.inp – Input file for 2001 to calculate Method 8 visibility.

SB01V8A.lst – Output file for 2001 to calculate Method 8 visibility. 

SB02V8a.inp – Input file for 2002 to calculate Method 8 visibility. 

SB02V8A.lst – Output file for 2002 to calculate Method 8 visibility. 

SB03V8a.inp – Input file for 2003 to calculate Method 8 visibility. 

SB03V8A.lst – Output file for 2003 to calculate Method 8 visibility. 
Anadarko Petroleum Corporation Trinity Consultants 

OZONE Files 

ozone_2001_sum156.dat – Hourly ozone data for 2001 from station SUM156. 

ozone_2002_sum156.dat – Hourly ozone data for 2002 from station SUM156. 

ozone_2003_sum156.dat – Hourly ozone data for 2003 from station SUM156. 
Anadarko Petroleum Corporation Trinity Consultants 

LIST OF CLASS I PSD INCREMENT MODELING FILES ON DVD – DRILLING 

OPERATIONS 

The DVD included with this appendix contains all of the input and output data files used to generate 

the results from the Class I PSD Increment analysis presented in this report. The following section 

provides a description of the contents of each folder included in the attached DVD. 

Breton NWR Files 

1. CALPUFF Input and Output Files 

B01ITA.cpi – Input file for year 2001. 

b01ita.cpl – Output file for year 2001. 

B02ITa.cpi – Input file for year 2002. 

b02ita.cpl – Output file for year 2002. 

B03ITA.cpi – Input file for year 2003. 

b03ita.cp – Output file for year 2003. 

2. POSTUTIL Input and Output Files 

B01pm10a.inp – Input file for 2001 to combine speciated PM components into PM10. 

b01pm10a.lst – Output file for 2001 to combine speciated PM components into PM10. 

b02pm10a.inp – Input file for 2002 to combine speciated PM components into PM10. 

b02pm10a.lst – Output file for 2002 to combine speciated PM components into PM10. 

b03pma.inp – Input file for 2003 to combine speciated PM components into PM10. 

b03pma.lst – Output file for 2003 to combine speciated PM components into PM10. 

B01alma.inp – Input file for 2001 to repartition nitrate mass using ALM method. 

B01alma.lst – Output file for 2001 to repartition nitrate mass using ALM method. 

b02alma.inp – Input file for 2002 to repartition nitrate mass using ALM method. 

b02alma.lst – Output file for 2002 to repartition nitrate mass using ALM method. 

b03alma.inp – Input file for 2003 to repartition nitrate mass using ALM method. 

b03alma.lst – Output file for 2003 to repartition nitrate mass using ALM method. 

3. CALPOST Input and Output File 

B01PMa.inp – Input file for 2001 to calculate PM10 concentration. 

B01PM10A.lst – Output file for 2001 to calculate PM10 concentration. 

B02PM10a.inp – Input file for 2002 to calculate PM10 concentration. 

B02PM10A.lst – Output file for 2002 to calculate PM10 concentration. 

B03PM10a.inp – Input file for 2003 to calculate PM10 concentration. 

B03PM10A.lst – Output file for 2003 to calculate PM10 concentration. 

B01PMFa.inp - – Input file for 2001 to calculate PMF concentration. 

B01PMFA.lst - Output file for 2001 to calculate PMF concentration. 

B01PMCa.inp - – Input file for 2001 to calculate PMC concentration. 

B01PMCA.lst – Output file for 2001 to calculate PMC concentration. 

B02PMFa.inp – Input file for 2002 to calculate PMF concentration. 

B02PMFA.lst – Output file for 2002 to calculate PMF concentration. 

B02PMCa.inp - – Input file for 2002 to calculate PMC concentration. 

B02PMCA.lst – Output file for 2002 to calculate PMC concentration. 
Anadarko Petroleum Corporation Trinity Consultants 

B03PMFA.inp – Input file for 2003 to calculate PMF concentration. 

B03PMFA.lst – Output file for 2003 to calculate PM2.5 concentration. 

B03PMCA.inp - – Input file for 2003 to calculate PMC concentration. 

B03PMCA.lst – Output file for 2003 to calculate PMC concentration 

B01NOa.inp – Input file for 2001 to calculate NO2 concentration. 

B01NO2A.lst – Output file for 2001 to calculate NO2 concentration. 

B02NOa.inp – Input file for 2002 to calculate NO2 concentration. 

B02NO2A.lst – Output file for 2002 to calculate NO2 concentration. 

B03NOa.inp – Input file for 2003 to calculate NO2 concentration. 

B03NOA.lst – Output file for 2003 to calculate NO2 concentration. 

St. Marks NWR and Bradwell bay Wilderness Files 

1. CALPUFF Input and Output Files 

SMBB01A.cpi – Input file for year 2001. 

smbb01a.cpl – Output file for year 2001. 

SMBB02A.cpi – Input file for year 2002. 

smbb02a.cpl – Output file for year 2002. 

SMBB03A.cpi – Input file for year 2003. 

smbb03a.cpl – Output file for year 2003. 

2. POSTUTIL Input and Output Files 

SB01pma.inp – Input file for 2001 to combine speciated PM components into PM10. 

sb01pma.lst – Output file for 2001 to combine speciated PM components into PM10. 

SB02pma.inp – Input file for 2002 to combine speciated PM components into PM10. 

sb02pma.lst – Output file for 2002 to combine speciated PM components into PM10. 

SB03PMainp – Input file for 2003 to combine speciated PM components into PM10. 

sb03pma.lst – Output file for 2003 to combine speciated PM components into PM10. 

SB01alma.inp – Input file for 2001 to repartition nitrate mass using ALM method. 

sb01alma.lst – Output file for 2001 to repartition nitrate mass using ALM method. 

SB02alma.inp – Input file for 2002 to repartition nitrate mass using ALM method. 

sb02alma.lst – Output file for 2002 to repartition nitrate mass using ALM method. 

SB03alma.inp – Input file for 2003 to repartition nitrate mass using ALM method. 

sb03alma.lst – Output file for 2003 to repartition nitrate mass using ALM method. 

3. CALPOST Input and Output Files 

SB01PMa.inp – Input file for 2001 to calculate PM10 concentration. 

SB01PMA.lst – Output file for 2001 to calculate PM10 concentration. 

SB02PMa.inp – Input file for 2002 to calculate PM10 concentration. 

SB02PMA.lst – Output file for 2002 to calculate PM10 concentration. 

SB03PMa.inp – Input file for 2003 to calculate PM10 concentration. 

SB03PMA.lst – Output file for 2003 to calculate PM10 concentration. 

SB01PMFa.inp – Input file for 2001 to calculate PMF concentration. 

SB01PMFA.lst – Output file for 2001 to calculate PM2.5 concentration. 

SB02PMFa.inp – Input file for 2002 to calculate PMF concentration. 

SB02PMFA.lst – Output file for 2002 to calculate PMF concentration. 

SB03PMFa.inp – Input file for 2003 to calculate PMF concentration. 
Anadarko Petroleum Corporation Trinity Consultants 

SB03PMFA.lst – Output file for 2003 to calculate PMF concentration. 

SB01PMCa.inp - Input file for 2001 to calculate PMC concentration. 

SB01PMCA.lst - Output file for 2001 to calculate PMC concentration 

SB02PMCa.inp – Input file for 2002 to calculate PMC concentration. 

SB02PMCA.lst – Output file for 2002 to calculate PMC concentration. 

SB03PMCa.inp – Input file for 2003 to calculate PMC concentration. 

SB03PMCA.lst – Output file for 2003 to calculate PMC concentration 

SB01NOa.inp – Input file for 2001 to calculate NO2 concentration. 

SB01NO2A.lst – Output file for 2001 to calculate NO2 concentration. 

SB02NOa.inp – Input file for 2002 to calculate NO2 concentration. 

SB02NOA.lst – Output file for 2002 to calculate NO2 concentration. 

SB03NOa.inp – Input file for 2003 to calculate NO2 concentration. 

SB03NOA.lst – Output file for 2003 to calculate NO2 concentration.

OZONE Files 

ozone_2001_sum156.dat - Hourly ozone data for 2001 from station SUM156. 

ozone_2002_sum156.dat - Hourly ozone data for 2002 from station SUM156. 

ozone_2003_sum156.dat - Hourly ozone data for 2003 from station SUM156. 
Anadarko Petroleum Corporation Trinity Consultants 

LIST OF EPA CLASS II MODELING FILES ON DVD – DRILLING OPERATIONS 

The DVD included with this appendix contains all of the input and output data files used to generate the 

results from the Class II PSD analysis presented in this report. The following section provides a 

description of the contents of each folder included in the attached DVD. 

EPA Receptors Files 

1. CALPUFF Input and Output Files 

EPA01ITA.cpi – Input file for year 2001. 

epa01ita.cpl – Output file for year 2001. 

E02ITA.cpi – Input file for year 2002. 

e02ita.cpl – Output file for year 2002. 

EPA03ITA.cpi – Input file for year 2003. 

Ͳ͵.cpl – Output file for year 2003. 

2. POSTUTIL Input and Output Files 

E01pm10a.inp – Input file for 2001 to combine speciated PM components into PM10. 

e01pm10a.lst – Output file for 2001 to combine speciated PM components into PM10. 

E02pm10a.inp – Input file for 2002 to combine speciated PM components into PM10. 

e02pm10a.lst – Output file for 2002 to combine speciated PM components into PM10. 

E03pm10a.inp – Input file for 2003 to combine speciated PM components into PM10. 

e03pm10a.lst – Output file for 2003 to combine speciated PM components into PM10. 

E01almA.inp – Input file for 2001 to repartition nitrate mass using ALM method. 

e01alma.lst – Output file for 2001 to repartition nitrate mass using ALM method. 

E02almA.inp – Input file for 2002 to repartition nitrate mass using ALM method. 

e02alma.lst – Output file for 2002 to repartition nitrate mass using ALM method. 

E03almA.inp – Input file for 2003 to repartition nitrate mass using ALM method. 

e03alma.lst – Output file for 2003 to repartition nitrate mass using ALM method. 

3. CALPOST Input and Output File 

E01PM10A.inp – Input file for 2001 to calculate PM10 concentration. 

E01PM10A.lst – Output file for 2001 to calculate PM10 concentration. 

E02PM10A.inp – Input file for 2002 to calculate PM10 concentration. 

E02PM10A.lst – Output file for 2002 to calculate PM10 concentration. 

E03PM10.inp – Input file for 2003 to calculate PM10 concentration. 

E03PM10A.lst – Output file for 2003 to calculate PM10 concentration. 

E01PMFA.inp - – Input file for 2001 to calculate PMF concentration. 

E01PMFA.lst - Output file for 2001 to calculate PMF concentration. 

E01PMCA.inp - – Input file for 2001 to calculate PMC concentration. 

E01PMCA.lst – Output file for 2001 to calculate PMC concentration. 

E02PMFA.inp – Input file for 2002 to calculate PMF concentration. 

E02PMFA.lst – Output file for 2002 to calculate PMF concentration. 

E02PMC.inp - – Input file for 2002 to calculate PMC concentration. 

E02PMCA.lst – Output file for 2002 to calculate PMC concentration. 

E03PMFA.inp – Input file for 2003 to calculate PMF concentration. 
Anadarko Petroleum Corporation Trinity Consultants 

E03PMFA.lst	–	Output	file	for	2003	to	calculate	PM2.5	concentration.	

E03PMCA.inp	‐	–	Input	file	for	2003	to	calculate	PMC	concentration.	

E03PMCA.lst	–	Output	file	for	2003	to	calculate	PMC	concentration	

E01NO2A.inp	–	Input	file	for	2001	to	calculate	NO2	concentration.	

E01NO2A.lst	–	Output	file	for	2001	to	calculate	NO2	concentration.	

E02NO2A.inp	–	Input	file	for	2002	to	calculate	NO2	concentration.	

E02NO2A.lst	–	Output	file	for	2002	to	calculate	NO2	concentration.	

E03NO2A.inp	–	Input	file	for	2003	to	calculate	NO2	concentration.	

E03NO2A.lst	–	Output	file	for	2003	to	calculate	NO2	concentration.	

E01COA.inp	‐	–	Input	file	for	2001	to	calculate	CO	concentration.	

E01COA.lst	‐	Output	file	for	2001	to	calculate	CO	concentration.	

E02COA.inp	‐	–	Input	file	for	2002	to	calculate	CO	concentration.	

E02COA.lst	‐	Output	file	for	2002	to	calculate	CO	concentration.	

E03COA.inp	‐	–	Input	file	for	2003	to	calculate	CO	concentration.	

E03COA.lst	‐	Output	file	for	2003	to	calculate	CO	concentration.	

VISCREEN Files 

Ana	BHBH	–	VISCREEN	output	file.	

anaBh5	–	VISCREEN	file.	

OZONE Files 

ozone_2001_sum156.dat	‐	Hourly	ozone	data	for	2001	from	station	SUM156.	

ozone_2002_sum156.dat	‐	Hourly	ozone	data	for	2002	from	station	SUM156.	

ozone_2003_sum156.dat	‐	Hourly	ozone	data	for	2003	from	station	SUM156.	

 
Anadarko Petroleum Corporation Trinity Consultants 

APPENDIX F: Q/D ANALYSIS SUMMARY 
Pollutant PM10 (NEI) + SO2 (NEI) + NOX (NE

PM10 26.63 lb/hr 116.62 tpy Class I km

SO2 1.79 lb/hr 7.85 tpy

NOX 622.4 lb/hr 2726.19 tpy

H2SO4 0.01 lb/hr 0.06 tpy

[1] Based on maximum 24-hour emissions annualized to 8,760 hrs/yr .

Class I Area

Breton NWR

St. Marks NWR

Bradwell Bay Wilderness 

Q 2,851 tpy

d 167 kms

Q/d 17.07 tpy/km

Q 2,851 tpy

d 285 kms

Q/d 10.00 tpy/km

Q 2,851 tpy

d 281 kms

Q/d 10.14 tpy/km

Where:

Approximate Distances from the worst-case location of Anadarko Lease Blocks (nearest) to 

surrounding Class I Areas

PM10 (NEI) = net emissions increase of SO2 (NEI) = net emissions increase of SH2SO4 (NEI) = net emissions increase o

Class I Area FLM Q/d Applicability - St. Marks NWR

NE

NOx (NEI) = net emissions increase of 

167

Class I Area FLM Q/d Applicability - Bradwell Bay Wilderness

Class I Area FLM Q/d Applicability - Breton NWR

NW

Location Relative to Class I Area

NE

Anadarko Petroleum Corporation

Class I Area Q/d Applicability Analysis

Q/d =

Proposed Anadarko Emissions [1]

285281

Hourly Emissions Adjusted Annualized Emissions

Distance (kms)

Anadarko Petroleum CorporationAir Quality Modeling Analysis 1 of 1
Anadarko Petroleum Corporation Trinity Consultants 

APPENDIX G: SUMMARY OF EMISSION ESTIMATES 

Refer	to	Appendix:	B	of	Main	Application.	
Anadarko Petroleum Corporation Trinity Consultants 

APPENDIX H: WORST- CASE DRILLSHIP AND SUPPLY BOAT LOCATION 
Source Lat, dd - Lease Block Center Lon, dd - Lease Block Center

UTM Northing 

(WGS84) Lease Block 

Center 

(Zone 16)

UTM Easting 

(WGS84) Lease 

Block Center 

(Zone 16)

a1 (meters) b1 (meters)

Worst case 

Drillship 

Location wrt. 

Center

Worst case Su

Location w

Rece

Drillship 28.83 -87.50 3,189,396.00 451,423.00 - 2,414.02 + 2,414.02 NW 

Supply Boat N

Source Lat, dd - Lease Block Center Lon, dd - Lease Block Center

UTM Northing 

(WGS84) Lease Block 

Center 

(Zone 16)

UTM Easting 

(WGS84) Lease 

Block Center 

(Zone 16)

a1 (meters) b1 (meters)

Worst case 

Drillship 

Location wrt. 

Center

Worst case Su

Loca

Drillship 28.83 -87.50 3,189,396.00 451,423.00 - 2,414.02 + 2,414.02 NW 

Supply Boat wrt Class I

Worst-case Source Coordinates Determination

Anadarko Petroleum CorporationAnadarko Petroleum Corporation

Worst-case Source Coordinates Determination

(28 deg. 49 mins 5

1.5 miles

1.5 miles

X

Lease Block (3 miles X 

Worst case drillship location (wrt closest Class 1 area)

Closest Class 1 area (Breton)

b1

a1

Worst case supply boat location (wrt

closest receptor)

Anadarko Petroleum CorporationAir quality Modeling Analysis

Page 1 of 3
Source Lat, dd - Lease Block Center Lon, dd - Lease Block Center

UTM Northing 

(WGS84) Lease 

Block Center 

(Zone 16)

UTM Easting 

(WGS84) Lease 

Block Center 

(Zone 16)

a1 (meters) b1 (meters)

Worst case 

Drillship 

Location wrt. 

Center

Worst 

Supply 

Locatio

Class 

Recep

Drillship 28.83 -87.10 3,189,396.00 490,047.00 - 2,414.02 + 2,414.02 NE 

Supply Boat NE 

Source Lat, dd - Lease Block Center

UTM Northing 

(WGS84) Lease 

Block Center 

(Zone 16)

UTM Easting 

(WGS84) Lease 

Block Center 

(Zone 16)

a1 (meters) b1 (meters)

Worst case 

Drillship 

Location wrt. 

Center

UTM 

North

(WGS8

Worst 

Locat

(Zone 

Drillship 28.83 3,189,396.00 451,423.00 - 2,414.02 + 2,414.02 NW 3,191,8

Supply Boat 

Worst-case Source Coordinates Determination

Anadarko Petroleum CorporationAnadarko Petroleum Corporation

Worst-case Source Coordinates Determination

(28 deg. 49 mins 55 sec, 86 deg 6 mins 7 sec)

1.5 miles

1.5 miles

X

Lease Block (3 miles X 3 miles)

Worst case drillship location (wrt closest Class 1 area)

Closest Class 1 areas (St. Marks and Bradwell Ba

Wilderness)

b1

a1

Wor

Anadarko Petroleum CorporationAir quality Modeling Analysis

Page 2 of 3
Source Lat, dd - Lease Block Center Lon, dd - Lease Block Center

UTM Northing 

(WGS84) Lease 

Block Center 

(Zone 16)

UTM Easting 

(WGS84) Lease 

Block Center 

(Zone 16)

a1 (meters) b1 (meters)

Worst case 

Drillship 

Location wrt. 

Center

Worst case 

Support 

Vessel 

Location wr

Class II 

Receptor

Drillship 28.83 -87.50 3,189,396.00 451,423.00 - 2,414.02 + 2,414.02 NW 

Supply Boat NW 

Source Lat, dd - Lease Block Center

UTM Northing 

(WGS84) Lease 

Block Center 

(Zone 16)

UTM Easting 

(WGS84) Lease 

Block Center 

(Zone 16)

a1 (meters) b1 (meters)

Worst case 

Drillship 

Location wrt. 

Center

UTM 

Northing 

(WGS84) fo

Worst case 

Location

(Zone 16)

Drillship 28.83 3,189,396.00 451,423.00 - 2,414.02 + 2,414.02 NW 3,191,810.02 

Supply Boat 

Anadarko Petroleum Corporation

Worst-case Source Coordinates Determination

Anadarko Petroleum Corporation

Worst-case Source Coordinates Determination

(28 deg. 49 mins 52 

1.5 miles

1.5 miles

X

Lease Block (3 miles X 3 miles)

Worst case drillship location (wrt closest Class 2 receptor)

Closest Class 2 Receptor

b1

a1

Worst case supply boat location (wrt closest receptor)

Anadarko Petroleum CorporationAir quality Modeling Analysis

Page 3 of 3