UNITED STATES GOVERNMENT MEMORANDUM

To: Public Information (MS 5030)

Plans Section, Office of Field 

Operations (MS 5231)

Public Information copy of Exploration Plan

Control # - N-09674

Type - Initial Exploration Plan

Lease(s) - OCS-G34019 Block - 697 Mississippi Canyon Area

Operator - Petrobras America Inc.

Drill, Complete, & Test - Subsea Well 1

%SJMMTIJQ

Attached is a copy of the subject plan for public comments on issues that 

should be addressed in an Environmental Assessment.

It has been deemed submitted as of this date and is under review for approval.

Mohammad Ashfaq

Plan Coordinator

Description -

Rig Type -

Subject:

From:

May 7, 2013
PUBLIC INFORMATION COPY

December 2012

INITIAL EXPLORATION PLAN

Lease Number: OCS-G 34019

Area/Block: Mississippi Canyon Block 697

Prospect Name: Urca

Offshore: Louisiana

Submitted by: Petrobras America Inc.

10350 Richmond Avenue

Suite 1400

Houston, Texas 77042

Gregory Roland

(713) 808-2881

groland@petrobras.com

Estimated Start-up Date: September 1, 2013 

Authorized Representative: No. Copies Being Submitted:

Melissa Flack Proprietary: 1 Copy & CD

J. Connor Consulting, Inc. Public Info: 1 Copy & CD

16225 Park Ten Place, Suite 700

Houston, Texas 77084 For BOEM:

(281) 578-3388 Plan No. N-9674

Melissa.Flack@jccteam.com Assigned to: Mohammed Ashfaq
Mississippi Canyon Block 697 (Control Number N-9674) Record of Changes

Date Section Page Revision

12/06/12 All All Initial Plan Submitted

12/17/12

Appendix B 5 Removed referral of Attachment B-1 from page

Attachment C-4 All Replaced with Well Clearance Letters only

Attachment F-1 1 Showing NPDES Permit No. on Attachment

Appendix H 1 Added OSRP Control Number

01/07/13 Attachment L-2 Page 1 Added Shorebase, Port Fourchon, to Vicinity Map

Attachment A-1 Page 1 Updated Form BOEM -0137 

04/25/13

Record of Change 1 Record of Change Reflecting all Amendments and 

Additions

Appendix H Page 1-2 Amended OSRP modification Submittal Date, approval 

date, and Revised WCD Scenario Comparison Chart
PETROBRAS AMERICA INC.

INITIAL EXPLORATION PLAN

LEASE OCS-G 34019

MISSISSIPPI CANYON BLOCK 697

APPENDIX A Plan Contents

APPENDIX B General Information

APPENDIX C Geological, Geophysical Information

APPENDIX D H2S Information

APPENDIX E Biological, Physical and Socioeconomic Information

APPENDIX F Wastes and Discharge Information

APPENDIX G Air Emissions Information

APPENDIX H Oil Spills Information

APPENDIX I Environmental Monitoring Information

APPENDIX J Lease Stipulations Information

APPENDIX K Environmental Mitigation Measures Information

APPENDIX L Support Vessels and Aircraft Information

APPENDIX M Onshore Support Facilities Information

APPENDIX N Coastal Zone Management Act (CZMA) Information

APPENDIX O Environmental Impact Analysis

APPENDIX P Administrative Information
LIST OF ATTACHMENTS

A-1 OCS Plan Information Form

A-2 Well Location Plat

A-3 Bathymetry Map

A-4 Pay.Gov Receipt

B-1 Nodal Analysis

C-1 Structure Contour Maps

C-2 3-D Seismic Lines

C-3 Geological Structure Cross Sections

C-4 Shallow Hazard Assessment

C-5 Stratigraphic Column

C-6 Time vs. Depth Tables

E-1 Bathymetry and Seafloor Features Map

F-1 Projected Generated Wastes

L-1 Solid and Liquid Waste Transportation

L-2 Vicinity Map

N-1 Louisiana Coastal Zone Management Consistency Certification

N-2 Alabama Coastal Zone Management Consistency Certification
Petrobras America Inc. Page A-1

Initial Exploration Plan December 2012

Mississippi Canyon Block 697 (OCS-G 34019)

APPENDIX A

PLAN CONTENTS

(A) PLAN INFORMATION FORM

Petrobras America Inc. (PAI) acquired the lease for Mississippi Canyon Block 697 in April 2006

under lease number OCS G-28021. The block became segregated and PAI became operator of 

lease OCS G-34019 in March 2011. Under this Exploration Plan, PAI proposes to drill and 

complete one well on lease OCS-G34019. This well will be drilled with a drillship MODU, and 

is located in approximately 7150 feet of water.

See attached OCS Plan Information Form – Form BOEM-0137, included as Attachment A-1.

(B) LOCATION

Included as Attachment A-2 is a Well Location Map depicting the proposed surface and bottom 

location of the proposed well. Included as Attachment A-3 is a bathymetry map showing the 

water depths across the lease block.

(C) SAFETY AND POLLUTION PREVENTION FEATURES

There are no proposed new or existing facilities that will be utilized for these operations. A 

description of the drilling unit is included on the OCS Plan Information Form. Rig specifications 

will be made part of the Application for Permit to Drill. 

Petrobras America Inc. will drill this well with a drillship which is equipped with a Subsea BOP. 

Once a rig is contracted, BOP information and schematics will be included as a part of the 

Application for Permit to Drill.

Safety features on the drilling unit will include well control, pollution prevention, and blowout 

prevention equipment as described in BSEE regulations 30 CFR 250 C, D, E and O; and as 

further clarified by BSEE Notices to Lessees, and current policy making invoked by the BSEE,

Environmental Protection Agency and the U.S. Coast Guard. Appropriate life rafts, life jackets, 

ring buoys, etc., will be maintained on the facility at all times.

Pollution prevention measures include installation of curbs, gutters, drip pans, and drains on 

drilling deck areas to collect all contaminants and debris. 

(D) STORAGE TANKS AND/OR PRODUCTION VESSELS

All facility tanks of 25 barrels or more.

Type of

Storage Tank

Type of

Facility

Tank Capacity 

(bbls)

Number

of Tanks

Total 

Capacity 

(bbls)

Fluid 

Gravity

(API)

Fuel Oil (Marine Diesel) Drillship 478 2 956 50°

Fuel Oil (Marine Diesel) Drillship 11,982 2 23,964 50°
Petrobras America Inc. Page A-2

Initial Exploration Plan December 2012

Mississippi Canyon Block 697 (OCS-G 34019)

Fuel Oil (Marine Diesel) Drillship 6,434 2 12,868 50°

Fuel Oil (Marine Diesel) Drillship 259 1 259 50°

Base Oil Drillship 1 1 5032 45°

(E) ADDITIONAL MEASURES

PAI does not propose additional safety, pollution prevention, or early spill detection measures 

beyond those required by 30 CFR Part 250 and Part 550.

(F) COST RECOVERY FEE

Included as Attachment A-4 is a pay.gov receipt in the amount of $3,442.00 to cover operations 

proposed in this plan.
U.S. Department of the Interior OMB Control Number: 1010-0151 

Bureau of Ocean Energy Management OMB Approval Expires: 12/31/2014

OCS PLAN INFORMATION FORM

General Information

Type of OCS Plan: Exploration Plan (EP) Development Operations Coordination Document (DOCD) 

Company Name: BOEM Operator Number: 

Address: Contact Person: 

Phone Number: 

E-Mail Address: 

Lease(s): Area: Block(s): Project Name (If Applicable): 

Objective(s): Oil Gas Sulphur Salt Onshore Base: Distance to Closest Land (Miles): 

Description of Proposed Activities (Mark all that apply)

Exploration drilling Development drilling 

Well completion Installation of production platform 

Well test flaring (for more than 48 hours) Installation of production facilities 

Installation of caisson or platform as well protection structure Installation of satellite structure 

Installation of subsea wellheads and/or manifolds Commence production 

Installation of lease term pipelines Other (Specify and describe) 

Have you submitted or do you plan to submit a Conservation Information Document to accompany this plan? Yes No 

Do you propose to use new or unusual technology to conduct your activities? Yes No 

Do you propose any facility that will serve as a host facility for deepwater subsea development? Yes No 

Do you propose any activities that may disturb an BOEM-designated high-probability archaeological area? Yes No 

Have all of the surface locations of your proposed activities been previously reviewed and approved by BOEM? Yes No 

Tentative Schedule of Proposed Activities

Proposed Activity Start Date End Date No. of Days

   

Description of Drilling Rig Description of Production Platform

Jackup Drillship Caisson Tension leg platform 

Gorilla Jackup Platform rig Well protector Compliant tower 

Semisubmersible Submersible Fixed platform Guyed tower 

DP Semisubmersible Other (Attach Description) Subsea manifold Floating production system 

Drilling Rig Name (If Known): Spar Other (Attach Description) 

Description of Lease Term Pipelines

From (Facility/Area/Block) To (Facility/Area/Block) Diameter (Inches) Length (Feet)

    

FORM BOEM-0137 (December 2011 - Supersedes all previous editions of form BOEM-0137 which may not be used.) 

Page 1 of 2 
Proposed Well/Structure Location

Well or Structure Name/Number (If renaming well or structure, reference previous name): Subsea Completion 

Anchor Radius (if applicable) in feet: Yes No 

Surface Location Bottom-Hole Location (For Wells)

Lease No. OCS OCS 

Area Name    

Block No.

Blockline 

Departures 

(in feet)

N/S Departure: F L N/S Departure: F L 

E/W Departure: F L E/W Departure: F L 

Lambert X-Y

coordinates

X: X: 

Y: Y: 

Latitude/ 

Longitude

Latitude Latitude 

Longitude Longitude 

TVD (Feet): MD (Feet): Water Depth (Feet): 

Anchor Locations for Drilling Rig or Construction Barge (If anchor radius supplied above, not necessary)

Anchor Name 

or No.

Area Block X Coordinate Y Coordinate Length of Anchor

Chain on Seafloor

     X = Y = 

     X = Y = 

     X = Y = 

     X = Y = 

     X = Y = 

     X = Y = 

     X = Y = 

     X = Y = 

Paperwork Reduction Act of 1995 Statement: The Paperwork Reduction Act of 1995 (44 U.S.C. Chapter 35) requires us 

to inform you that BOEM collects this information as part of an applicant’s Exploration Plan or Development Operations 

Coordination Document submitted for BOEM approval. We use the information to facilitate our review and data entry for 

OCS plans. We will protect proprietary data according to the Freedom of Information Act and 30 CFR 550.197. An 

agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays 

a currently valid Office of Management and Budget Control Number. The use of this form is voluntary. The public 

reporting burden for this form is included in the burden for preparing Exploration Plans and Development Operations 

Coordination Documents. We estimate that burden to average 600 hours per response, or 640 with an accompanying EP 

(1,000 hours in AKOCSR), or 690 (1,700 in AKOCSR) with an accompanying DPP or DOCD, including the time for 

reviewing instructions, gathering and maintaining data, and completing and reviewing the forms associated with subpart B. 

Direct comments regarding the burden estimate or any other aspect of this form to the Information Collection Clearance 

Officer, Bureau of Ocean Energy Management, 381 Elden Street, Herndon, VA 20170. 

2

OCS PLAN INFORMATION FORM (CONTINUED) 

Include one copy of this page for each proposed well/structure

FORM BOEM-0137 (December 2011- Supersedes all previous editions of form BOEM-0137 which may not be used.) Page 2 of 2 

OCS-G-34020

PETROBRAS

OCS-G-32343

NOBLE

OCS-G-28018

PETROBRAS OCS-G-28019

PETROBRAS

S-G-34019

TROBRAS

OCS-G-28022

NOBLE

OCS-G-31524

NOBLE

MC697

MC741

MC654

MC698

MC742

MC653

OCS-G-28021

NOBLE

COLOR SHADED BATHYMETRY MAP

"URCA" PROSPECT

BLOCK 697 (OCS-G-34019) and Vicinity

MISSISSIPPI CANYON AREA

 -6910 -6920 -6930 -6940 -6950 -6960 -6970 -6980 -6990 -7000 -7010 -7020 -7030 -7040 -7050 -7060 -7070 -7080 -7090 -7100 -7110 -7120 -7130 -7140 -7150 -7160 -7170 -7180 -7190 -7200 -7210 -7220 -7230 -7240 -7250 -7260 -7270 -7280 -7290

Depth in feet

NOTE: All AUV field data acquired Dec. 18-20, 2008.

 Survey vessels: M/V Miss Ginger, C-Surveyor III NADCON version 2.1 utilized for WGS84-NAD27 conversions.

Navigation trackline with name and direction run, fix and fix number

Contour interval = 10 feet

Zero datum = Mean Sea Level

Note: Line spacing resulted in ~75 meter (246 feet) gap between tracklines.

Multibeam Processing Sequence

Bin size = 6 meters (20 feet) within swath coverageMedian filter applied

Water column velocity corrections appliedTide corrections applied using Goddard Ocean Tide Model GOT99.2

Produced 20 feet x 20 feet triangulated-gridded dataset to fill in gaps

Color shaded image

Sun azimuth = 0°Sun elevation = 30°

Bathymetric contours (in feet)
OCS-G-32343

NOBLE

MC697

MC698

MC742

OCS-G-31524

NOBLE

OCS-G-28021

NOBLE

OCS-G-28022

NOBLE

Bathymetric contours (in feet)

AUV navigation tracklines with name and direction run, fix and fix number

 NOTE: All AUV field data acquired Dec. 18-20, 2008. Survey vessels: M/V Miss Ginger, C-Surveyor III NADCON version 2.1 utilized for WGS84-NAD27 conversions.

Depth in feet

Contour interval = 10 feet

Zero datum = Mean Sea Level

Note: Line spacing resulted in ~75 meter (246-foot) gap between tracklines.

Multibeam Processing Sequence

Bin size = 6 meters (20 feet) within swath coverageMedian filter applied

Water column velocity corrections appliedTide corrections applied using Goddard Ocean Tide Model GOT99.2

Produced 20 feet x 20 feet triangulated-gridded dataset to fill in gaps

Color shaded image

Sun azimuth = 0°Sun elevation = 30°

 -6950 -6960 -6970 -6980 -6990 -7000 -7010 -7020 -7030 -7040 -7050 -7060 -7070 -7080 -7090 -7100 -7110 -7120 -7130 -7140 -7150 -7160 -7170 -7180 -7190 -7200 -7210 -7220 -7230 -7240 -7250 -7260 -7270 -7280

SITE CLEARANCE

COLOR SHADED BATHYMETRY MAP

PROPOSED WELL No. 1

BLOCK 697 (OCS-G-34019)

MISSISSIPPI CANYON AREA

Petrobras America Inc. Page B-1

Initial Exploration Plan December 2012

Mississippi Canyon Block 697 (OCS-G 34019)

APPENDIX B

GENERAL INFORMATION

(A) APPLICATIONS AND PERMITS

Listed in the table below are additional permits/applications to be filed before operations can 

commence under this EP:

Application/Permit Issuing Agency Status

Application for Permit to Drill BSEE Not yet submitted

(B) DRILLING FLUIDS

Type of Drilling Fluid Estimated Volume of Drilling Fluid to be 

Used per Well

Water-based –

Barite, Sodium Chloride Brine, Salt, Xantham 

Gum, Poly Plus, Lime, Poly Pac UL, Caustic 

Soda, Defoam X,

Greencide 25g

82,000 bbls water base mud

Oil-based (diesel, minerals, oil) 0 bbls

Synthetic-based (internal olefin, ester)

Barite, Suremul, Surewet, Rheflat, Rhethik, 

Ecotrol RD, Rheduce, Rhebuild, Lime, 

Calcium Chloride, Vg Plus, Vg Supreme, 

Calcium Carbonate, G-Seal, Nut Plug, Vinseal

3,200 Synthetic – based mud

(C) NEW OR UNUSUAL TECHNOLOGY

PAI does not propose to use any new or unusual technology to carry out the proposed

exploration activities. 

(D) BONDING STATEMENT

The bond requirements for the activities and facilities proposed in this EP are satisfied by a 

$3,000,000.00 areawide development bond, furnished and maintained according to 30 CFR 556, 

subpart I; NTL No. 2000-G16, "Guidelines for General Lease Surety Bonds;" and additional

security under 30 CFR 556.53(d) and National NTL No. 2008-N07, “Supplemental Bond 

Procedures.” 

(E) OIL SPILL FINANCIAL RESPONSIBILITY (OSFR)

Petrobras America Inc., BOEM company number 01207 has demonstrated oil spill financial 

responsibility for the facilities proposed in this EP according to 30 CFR Part 553; and NTL No. 

2008-N05, "Guidelines for Oil Spill Financial Responsibility for Covered Facilities".
Petrobras America Inc. Page B-2

Initial Exploration Plan December 2012

Mississippi Canyon Block 697 (OCS-G 34019)

(F) DEEPWATER WELL CONTROL STATEMENT

Petrobras America Inc., BOEM company number 01207 has the financial capability to drill a 

relief well and conduct other emergency well control operations.

(G) BLOWOUT SCENARIO

Estimated flow rate – The calculated Worst Case Discharge estimate for Mississippi Canyon 

Block 697 is 132,975 bbls of oil.

Potential for the Well to Bridge over:

The Late Miocene (Serravallian) reservoirs expected to be encountered in the Urca prospect are

deepwater turbidite channel and lobe sands with assumed water drive mechanism. Although the 

flow rate is likely to decline over the duration of a blowout, for WCD purposes we have used a 

constant flow rate of 132,975 barrels per day with no decline. Using this conservative approach 

to the WCD calculations, the reservoirs also are considered very unlikely to bridge over due to 

the high compressive strength of the rocks.

Likelihood of Surface Intervention:

In the unlikely event of a “kick” or loss of well control event, surface intervention, defined as the 

normal well control methods which include wellbore fluid control or overbalance, diverter and 

BOP operations to shut‐in the well from the surface will be the primary response. The present

well design is based on predicted pore pressure and fracture gradient estimates derived from the 

best available data. The well design in conjunction with actual pore pressure, actual fluids and

actual fracture gradients encountered will dictate the use of either the Cap and Stack or Cap and 

Flow method to regain control of the well. The assumption that the well can be shut‐in with the 

present well design and selected BOP is based on predicted measurements of the pore pressure, 

fluids and fracture gradients. Relief well planning will commence in conjunction with the subsea 

capping efforts.

Arrangements for Drilling Relief Wells / Estimated Blowout Duration:

Should surface intervention prove unsuccessful, PAI has evaluated two additional potential 

scenarios to kill a blowout, seafloor intervention and a relief well. This would involve subsea 

intervention in the form of ROV control of the BOP stack via hot stabs, a shut off device 

mounted on the BOP stack or LMRP, or diverting flow to a surface vessel. Seafloor intervention 

would take an estimated 10 days to kill the well, which would result in a total discharge volume 

of 2.65MM barrels of oil. In parallel with this operation, a rig will be mobilized (approximately 

20 deepwater rigs capable of this water depth and hook loads currently work in the GOM) to drill 

a relief well, estimated to be 14 days to contract, 14 days to mobilize and 69 days to kill the well 

as Shown in Table 1, which would result in a total discharge volume of 12.89MM barrels of oil.
Petrobras America Inc. Page B-3

Initial Exploration Plan December 2012

Mississippi Canyon Block 697 (OCS-G 34019)

Table 1: Timeline for drilling a relief well

Operation Minimum Time Required Maximum Time Required

Contract a rig 0 14

MOB 7 14

Riserless Operations 7 14

Drilling Operations 30 45

Kill Operations 3 10

Total Days 47 97

Rig Type Capable of Drilling a Relief Well / Rig Package Constraints:

Should a relief well be required, a deepwater rig currently located in the GOM would be 

contracted to drill the relief well. As of November 2010, there are approximately 20 rigs in the 

GOM capable of drilling an Urca relief well. The rig must be capable of drilling to a depth of 

18,000 feet in a water depth of 7,150 feet. This rig will be a rig of no constraints. There are no 

platforms or other structures in the vicinity for drilling a relief well. PAI expects to have a 2‐rig 

operation by the end of 2012, with a rig operating in the Cascade/Chinook Field while the other 

is operating at the Urca Prospect.

The requirements for dynamically positioned rigs include both a deadman system to shut‐in the 

well in the event of complete loss of communication to the subsea Blowout Prevention 

Equipment (BOPE) and an autoshear system to shut‐in the well in the event of an accidental 

disconnect. ROV hot stabs will be in place and function tested to ensure that they are capable of 

closing one pipe ram, closing the blind shear ram, and unlatching the LMRP.

In the event of a blowout, the 97‐day window may be necessary to secure a rig, mobilize to the

location, drill the relief well and kill the blowout well as shown on Table 1. PAI will work with 

specific partners and industry to develop rig‐sharing agreements to allow faster mobilization in 

the event of an emergency.

Measures to Enhance the Ability to Prevent a Blowout:

Well Control Training

PAI requires certified well control training for drilling supervisors, operations superintendents, 

drilling engineers, and the drilling contractor requires training for tool pushers, drillers & 

assistant drillers, floor hands, and other appropriate personnel through an operations training 

program with a professional organization and in accordance with BSEE/BOEM requirements. 

The curriculum consists of training in blowout prevention technology and well control. 

Successful completion results in participant certification.
Petrobras America Inc. Page B-4

Initial Exploration Plan December 2012

Mississippi Canyon Block 697 (OCS-G 34019)

Inspection of Well Control Equipment

The rig and its equipment will have undergone a comprehensive inspection and testing program

pursuant to 30 CFR 250 “Increased Safety Measures for Energy Development in the OCS”; 

Final Rule October 14, 2010. Routine functional and pressure testing during future drilling and 

completion operations will be conducted in compliance with PAI and BSEE/BOEM 

requirements.

Measures to reduce the likelihood of a Blowout:

Well Control during Drilling Operations

Effective well control during drilling and completion reduces the likelihood of a blowout and 

relies on a number of interrelated processes and procedures. The drilling or completion fluid 

provide Primary Well Control during operations with the fluid density providing hydrostatic 

pressure on the wellbore which exceeds the pore pressures within the drilled or open hole 

formations. This overbalance prevents fluid flow from the pore space in the formation to flow 

into the wellbore. Subsea‐mounted BOPE will provide Secondary Well Control during drilling or 

completion operations. In the event that primary well control is lost, the BOPE will contain the 

influx out of the wellbore.

Well Control drills/exercises are an integral part of the rig teams training and will be performed 

on a frequent basis to ensure the human element is prepared, and the well can be shut in quickly 

and properly. Certified training of Gulf of Mexico personnel will include hands‐on simulator 

practice at recognizing kicks, well shut‐in, and circulating the kicks out of the wellbore. Well 

specific shut‐in procedures will be posted on the rig.

Well Control Monitoring and Procedures

Automatic and manual monitoring equipment will be installed to detect abnormal variation in the 

mud system volumes and drilling parameters. If an influx of formation fluid into the wellbore 

occurs, the BOPE will be used to immediately shut‐in the well. The well will be drilled 

according to a location specific pore pressure profile and detailed safe mud weight envelope. Too 

low of a mud weight could result in an under‐balance in the well, and an influx of formation 

fluids. Conversely, too high of a mud weight may result in lost circulation to a weak formation, 

which could lead to a drop in fluid level (total hydrostatic column) resulting in an underbalanced

condition. The mud weight envelope is designed to provide the proper balance for well control 

for the formation and pore pressure encountered.

Measures to Enhance Ability to Conduct Effective and Early Intervention in the Event of a 

Blowout:

In case an uncontrolled influx of formation fluid (water or hydrocarbon), or “Kick” does occur, 

Secondary Well Control methods will be employed, i.e., the kick is quickly detected, the pumps 

are turned off, the annulus will be shut in using the annular, the drill pipe positioned relative to 

the annular, and the annulus isolated. The internal barrier in the Drill Pipe is a downhole check 

valve near the bit and a surface‐mounted valve. These barriers will contain the influx and any 

associated build‐up of surface pressure. It will also prevent further influx of formation fluid into 

the wellbore.
Petrobras America Inc. Page B-5

Initial Exploration Plan December 2012

Mississippi Canyon Block 697 (OCS-G 34019)

To kill an influx, surface pressures will be allowed to stabilize and then the SIDP (Shut In Drill 

Pipe) and SICP (Shut In Casing Pressure) are measured. These pressures will enable the 

calculation of the new killweight mud density needed to regain primary well control. A standard 

well‐kill procedure will be implemented to circulate the kill‐weight mud and safely remove 

formation fluids from the hole. Mud gas separators and degassers will be used to safely remove 

gas from the mud as it is circulated out of the hole. After this procedure is completed, the kill 

effectiveness will be confirmed and the well will be circulated around, the BOPE opened up and 

the fluid levels monitored. Drilling operations will resume when the well has been brought under 

control and a static condition exists.
Petrobras America Inc. Page C-1

Initial Exploration Plan December 2012

Mississippi Canyon Block 697 (OCS-G 34019)

APPENDIX C

GEOLOGICAL AND GEOPHYSICAL INFORMATION

(A) GEOLOGICAL DESCRIPTION

Proprietary Information.

(B) STRUCTURE CONTOUR MAPS

Proprietary Information.

(C) INTERPRETED 3-D SEISMIC LINE(S) 

Proprietary Information.

(D) GEOLOGICAL STRUCTURE CROSS-SECTIONS

Proprietary Information.

(E) SHALLOW HAZARDS REPORT

A shallow hazards survey was conducted over Mississippi Canyon Block 697 by C&C 

Technology on behalf of PAI in December 2008. 

One hard copy and one CD of the Shallow Hazard Report and Archaeological Survey, along with 

the Site Clearance Report are being submitted to the BOEM under separate cover.

(F) SHALLOW HAZARDS ASSESSMENT

Utilizing the 3D seismic exploration data, a shallow hazards assessment was prepared for the 

proposed surface locations, and is included as Attachment C-4.

(G) HIGH-RESOLUTION SEISMIC LINES

Proprietary Information.

(H) STRATIGRAPHIC COLUMN

Proprietary Information.

(I) TIME VS DEPTH TABLES

Proprietary Information.
MC697 Well No. 1 Site Clearance Letter 10615 Shadow Wood Drive, Houston, TX 77043 Job No. 120932

1

November 14, 2012 

Petrobras America, Inc. 

10350 Richmond Ave., Suite 1400 

Houston, TX 77042 

713-808-2770 

Attn: Mr. David Huff 

Site Clearance Letter 

Proposed Well No. 1 Surface Location 

Block 697 (OCS-G-34019), Mississippi Canyon Area 

Petrobras America Inc. (Petrobras) contracted C & C Technologies, Inc. (C&C) to prepare a well site clearance 

letter for the drilling location of the proposed Well No. 1 in Block 697 (OCS-G-34019), Mississippi Canyon (MC) 

Area. The data used for the site clearance letter include a high-resolution geophysical dataset acquired with C&C’s 

C-Surveyor IIITM Autonomous Underwater Vehicle (AUV) in December 2008 and an exploration-quality 3D seismic 

volume, collected by TGS-NOPEC in March of 2003, provided by Petrobras. C&C completed the geohazard report 

titled “Archaeological and Shallow Hazard Report, “Urca” Prospect, Block 697 and Vicinity, Mississippi Canyon 

Area” This site clearance letter is based on findings provided within that report. 

This letter provides a tophole drilling prognosis and addresses seafloor conditions to meet current regulations. The 

reporting and mapping presented in this letter comply with the Bureau of Ocean Energy Management (BOEM) and 

the Bureau of Safety and Environmental Enforcement (BSEE) guidelines provided in NTL No. 2008-G05 (Shallow 

Hazards Program), NTL No. 2009-G40 (Deepwater Benthic Communities), NTL No. 2005-G07 (Archaeological 

Resource Surveys and Reports), and NTL No. 2011-Joint-G01 (Revisions to the List of OCS Lease Blocks 

Requiring Archaeological Resource Surveys and Reports). The depth limit of the investigation is approximately two 

seconds of two-way traveltime below the seafloor. Seafloor conditions are addressed to assess the impact of drilling 

activities on potential deepwater benthic communities within a 2,000-foot radius of the proposed surface location. 

 

WELL LOCATION 

The geodetic datum is the North American Datum of 1927 (NAD 27) on the Clarke 1866 Ellipsoid. The projection 

is the Universal Transverse Mercator (UTM), Zone 16 North (16N) with a central meridian at 87° 00' W, a false 

easting of 1,640,416.67 feet at the central meridian, and a false northing of 0.00 feet at 00° 00' N. Units are in US 

survey feet. The surface location of the proposed MC697 Well No. 1 is displayed on the enclosed maps (Sheets 1 

through 6). Figure 1 consists of a wavelet and an amplitude spectrum showing the frequency content versus the 

amplitudes of the data collected at the proposed drill center. 
MC697 Well No. 1 Site Clearance Letter 10615 Shadow Wood Drive, Houston, TX 77043 Job No. 120932

2

The coordinates of the proposed surface location and bottom hole locations for proposed Well No. 1 and calls from 

Block MC697 are tabulated below: 

Well No. 1 Block 

Coordinates 

Latitude Longitude Calls From Block 697 

Easting Northing Mississippi Canyon 

Surface 697 1,277,877′ 10,271,889′ 28° 18' 03.253" N 88° 07' 37.056" W 7,569′ FSL 5,163′ FEL

Bottom 697 1,278,890′ 10,272,755′ 28° 18' 11.923" N 88° 07' 25.812" W 7,405′ FNL 4,150′ FEL

BATHYMETRY AND SEAFLOOR GRADIENTS 

The water depth at the proposed Well No. 1 surface location is 7,161 feet below sea level (BSL) (Sheet 1, Color 

Shaded Bathymetry Map). Water depths within the 2,000-foot radius range from 7,128 feet BSL in the northwest to 

7,176 feet BSL in the southeast. The seafloor is generally undulating in the vicinity of the proposed well location. 

The seafloor at the proposed well site slopes southeast at a gradient of less than 1° (Sheet 2, Seafloor Gradient Map). 

SEAFLOOR HAZARDS 

Seafloor amplitudes from 3D seismic data (Sheet 3, Seafloor Amplitude Map) and sonar imagery from AUV data 

(Sheet 4, Side Scan Sonar Mosaic Map) exhibit a seafloor of relatively low-amplitude reflection within the 

2,000-foot radius, suggesting the seafloor consists mostly of fine-grained sediments. 

Eleven unidentified sonar contacts were recorded within the archaeological and hazard assessment area but only one 

occurs within the 2000-foot drilling radius of the proposed Well No. 1 (Sheet 5, Seafloor Features and Hazard Map). 

Sonar Contact No. 6 occurs 1,104 feet west of the proposed surface location and measures 12.9 feet long, 5.3 feet wide, 

with no measurable height (Sheet 5, Seafloor Features and Hazard Map). This contact should be avoided by all 

development activities by a minimum of 100 feet. Sonar Contact No. 6 is not recommended for avoidance based on 

archaeological potential. No other sonar contacts occur within 2,000 feet of the proposed Well No. 1 surface location. 

There are no fault scarps within 2,000 feet of the proposed Well No. 1 surface location. 

No sonar contacts or areas are recommended for investigation or avoidance on the basis of archaeological potential. 

POTENTIAL DEEPWATER BENTHIC COMMUNITIES 

Examination of side scan sonar imagery (Sheet 4, Side Scan Sonar Mosaic Map) and the 3D seafloor amplitudes 

(Sheet 3, Seafloor Amplitude Map) shows no evidence of hydrocarbon seepage or surficial high-amplitude areas that 

might support high-density deepwater benthic communities within 2,000 feet of the proposed Well No. 1 location. 

 
MC697 Well No. 1 Site Clearance Letter 10615 Shadow Wood Drive, Houston, TX 77043 Job No. 120932

3

MAN-MADE HAZARDS 

A review of the C&C and BOEM databases shows no existing wells, pipelines, cables, or any other man-made 

infrastructure occur within the 2,000-foot drilling radius (Sheet 5, Seafloor Features and Hazard Map). 

SUBSURFACE FEATURES 

The approximately 185 feet of the uppermost AUV subbottom profile consist of continuous, stratified reflectors of 

varying amplitudes, representing hemipelagic clays interlaced with fine-grained turbidites (Figure 2). Below the 

stratified layer, a series of mass transport deposits is evident to the limit of the subbottom profiler penetration. 3D 

seismic data were used to assess subsurface geology deeper than the AUV penetration depth. 

Using the 3D seismic data, seven stratigraphic units of distinct seismic character were assessed (Figures 3 and 4). A 

detailed description of the sequence units can be found in the Archaeological and Shallow Hazard Report. Petrobras 

provided C&C with a check shot survey data elevation used to derive the total vertical depth (TVD) in feet from the 

corresponding two-way traveltime in seconds from an analog well. An equation derived from the check shot survey 

data was used to calculate structure depth below sea level: 

Y = 185.5T2 + 1990T 

where Y = depth below sea level in feet, and T = two-way traveltime in seconds. 

One buried fault crosses the wellbore around 3,233 feet BSF (3.845 seconds TWT) (Sheet 6, Subsurface Features 

and Hazard Map). Proper precautions should be taken when drilling through this unit. 

The upper 525 feet (2.928 to 3.015 seconds TWT BSL) of the proposed wellbore (Unit A) consists of parallel, low 

amplitude reflectors that are suggestive of hemipelagic clay interbedded with fine-grained turbidites (Figures 3 to 5). 

Unit B occurs between 525 and 612 feet BML (3.015 to 3.043 seconds TWT BSL) and consists of parallel, moderate 

amplitude reflectors. The sediments are interpreted as sand sheets. Unit C occurs approximately 612 to 904 feet 

BML (3.043 to 3.136 seconds TWT BSL) and consists of parallel, low amplitude reflectors interpreted as mud-rich 

turbidite deposits. Unit D occurs between 904 and 1,407 feet BML (3.136 to 3.294 seconds TWT BSL) and exhibits 

parallel, low to moderate amplitude reflectors. This unit is interpreted as channel fills with some sands. Unit E 

occurs between 1,407 and 2,467 feet BML (3.294 to 3.618 seconds TWT BSL) and consists of parallel to 

sub-parallel, moderate to high amplitude reflectors interpreted as mass transport deposits and channel fills with some 

sands. Unit F occurs 2,467 to 3,288 feet BML (3.618 to 3.861 seconds TWT BSL) and consists mostly of low 

amplitude, subparallel reflectors interpreted as channel fills and clay-prone mass transport deposits. Unit G occurs 

between 3,288 and 4,883 feet BML (3.861 and 4.316 seconds TWT) and is comprised of variable amplitude, 

subparallel to chaotic reflectors interpreted as channel fills and clay-prone mass transport deposits. 
MC697 Well No. 1 Site Clearance Letter 10615 Shadow Wood Drive, Houston, TX 77043 Job No. 120932

4

No amplitude anomalies occur within 246 feet (75 meters) of the proposed Well No. 1 surface location (Sheet 6, 

Subsurface Features and Hazard Map). 

SHALLOW GAS 

Anomalies of very high amplitude are interpreted as potential intervals of fluid/gas saturation usually associated 

with porous sands. Interval amplitude anomalies were produced utilizing a Vatmin SMT function with envelopes 

ranging from 10 milliseconds below each picked horizon (including seafloor) to 10 milliseconds above the next 

horizon. Seismic amplitude anomalies in Units A through G are exhibited on the Subsurface Features and Hazard 

Map (Sheet 6). 

Shallow gas potential is represented in the Tophole Prognosis Diagram in Figure 4. Units A, B, C, and D are 

assessed as having a low risk of gas hazards. Units E, F, and G are assessed as having a moderate risk of gas. 

SHALLOW WATER FLOWS (SWF) 

Shallow water flows (SWF) are overpressured, unconsolidated sands that are encountered in the tophole sections of 

some wells drilled in the deepwater areas of the Gulf of Mexico. Sands with SWF potential often lie below a seal 

that prevents dewatering and compaction after deposition and form in unconsolidated and overpressured sands. The 

pressure rises with overburden causing a potentially hazardous condition for drilling operations. Some SWF 

intervals have proven difficult or impossible to detect on seismic profiles. 

Two SWFs are recorded approximately 4.5 miles west-northwest and 9.5 miles northwest of the study area at depths 

of 1,971 feet and 1,246 feet BML in MC696 and MC607, respectively. Both events resulted in a low severity SWF, 

and the well integrity was maintained. 

Unit A is assessed as having a negligible risk of SWF (Figure 5). Units C and G indicate a low risk of shallow water 

flow. Possible sheet sands with high amplitudes in Unit B (525–612 feet BML or 3.015–3.043 seconds TWT BSL), 

Unit D (904–1,407 feet BML or 3.136–3.294 seconds TWT BSL), Unit E (1,407–2,467 feet BML or 3.294–3.618 

seconds TWT BSL), and Unit F (2,467–3,288 feet BML or 3.618–3.861 seconds TWT BSL) are assessed as having 

a moderate risk of SWF. 

CONCLUSIONS 

The water depth at the proposed Well No. 1 surface location is 7,161 feet below MSL. The seafloor is generally 

undulating in the vicinity of the proposed well location. The seafloor at the proposed well site slopes southeast at a 

gradient of less than 1°. 
MC697 Well No. 1 Site Clearance Letter 10615 Shadow Wood Drive, Houston, TX 77043 Job No. 120932

5

One sonar contact, Sonar Contact No. 6, occurs 1,104 feet west of the proposed Well No. 1 surface location. No 

wells, pipelines, cables, or any other man-made infrastructure occur within the 2,000-foot drilling radius. 

No fault scarps occur within 2,000 feet of the proposed Well No. 1 location. 

There are no areas of high backscatter or high seafloor amplitudes within the 2,000-foot drilling radius. Potential 

impacts to deepwater benthic communities are considered very low. 

 

One buried fault intersects the proposed well bore at approximately 3,233 feet BSF (3.845 seconds TWT). Proper 

precautions should be taken when drilling through this unit. 

No seismic amplitude anomalies occur within 246 feet of the proposed well location. 

Units A, B, C, and D are assessed as having a low risk of gas, and Units E, F, and G are assessed as having a 

moderate risk of gas. 

Unit A has a negligible risk of shallow water flow. Units C and G have a low risk of SWF. Units B, D, E, and F show 

possible sand sheets with high-amplitude reflectivity that suggests a moderate risk of SWF. 

No sonar contacts or areas are recommended for investigation or avoidance on the basis of archaeological potential. 

Thank you for this opportunity to be of service. Please contact us if you have any questions concerning this 

assessment. 

Sincerely, 

 Mary Brookshire Dan Warren 

Marine Geologist Senior Marine Archaeologist 

C&C Technologies, Inc. 

Office: 713-468-1536 

Direct: 832-468-4729 

Fax: 713-468-1115 

Enclosures 

Figure 1. Wavelet and amplitude spectrum from Crossline 10101, 2.818–4.317 seconds, traces 9810–10360. 
MC697 Well No. 1 Site Clearance Letter 10615 Shadow Wood Drive, Houston, TX 77043 Job No. 120932

6

Figure 2. Subbottom profiler line 114 showing parallel reflectors and mass transport deposits along the well path. 

Figure 3. Seismic Inline 11080 through the Well No. 1 surface location. 

Figure 4. Seismic Crossline 10101 through the Well No. 1 surface location. 

Figure 5. Tophole Prognosis chart for proposed Well No. 1 in Block 697, Mississippi Canyon Area. 

Sheet 1 Color Shaded Bathymetry Map 

Sheet 2 Seafloor Gradient Map 

Sheet 3 Seafloor Amplitude Map 

Sheet 4 Side Scan Sonar Mosaic Map 

Sheet 5 Seafloor Features and Hazard Map 

Sheet 6 Subsurface Features and Hazard Map 

Reference No. 120932 
MC697 Well No. 1 Site Clearance Letter 10615 Shadow Wood Drive, Houston, TX 77043 

7

Figure 1. Wavelet and amplitude spectrum from Crossline 10101, 2.818–4.317 seconds, traces 9810–10360. 
MC697 Well No. 1 Site Clearance Letter 10615 Shadow Wood Drive, Houston, TX 77043 

8

Figure 2. Subbottom profiler line 114 showing parallel reflectors and mass transport deposits along the well pa
MC697 Well No. 1 Site Clearance Letter 10615 Shadow Wood Drive, Houston, TX 77043 

9

Figure 3. Seismic Inline 11080 through the Well No. 1 surface location. 
MC697 Well No. 1 Site Clearance Letter 10615 Shadow Wood Drive, Houston, TX 77043 

10

Figure 4. Seismic Crossline 10101 through the Well No. 1 surface location. 
MC697 Well No. 1 Site Clearance Letter 10615 Shadow Wood Drive, Houston, TX 77043 

11

Figure 5. Tophole Prognosis chart for proposed Well No. 1 in Block 697, Mississippi Canyon Area.
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Initial Exploration Plan December 2012

Mississippi Canyon Block 697 (OCS-G 34019)

APPENDIX D

HYDROGEN SULFIDE INFORMATION

(A) CONCENTRATION

PAI does not anticipate encountering any H2S during the proposed operations.

(B) CLASSIFICATION

In accordance with Title 30 CFR 250.490(c), PAI requests that Mississippi Canyon Block 697 be 

classified by the BSEE as H2S absent. 
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Initial Exploration Plan December 2012

Mississippi Canyon Block 697 (OCS-G 34019)

APPENDIX E

BIOLOGICAL, PHYSICAL AND SOCIOECONOMIC INFORMATION

(A) DEEPWATER BENTHIC COMMUNITIES 

Activities proposed in this EP will disturb seafloor areas in water depths of 300 meters (984 feet) 

or greater; therefore, information as outlined in Attachment A of NTL No. 2009-G40, 

“Deepwater Benthic Communities”, is provided below. PAI will avoid all high-density 

deepwater benthic communities by 2,000 feet from the proposed mud and cuttings discharge 

location and 250 feet from the location of all other seafloor disturbances.

MAPS

Attached to this EP is a map(s) prepared using 3-D seismic data depicting seafloor and shallow 

geological features and areas, and the surface location(s) of the proposed well(s) with a radius 

circle of 2000 feet around the well. The map is included as Attachment E-1.

ANALYSIS

Mississippi Canyon Block 697 well location No.1

Using 3-D seismic information, all seafloor features and areas that could be disturbed by the 

activities proposed in this plan have been identified. The likelihood of these proposed activities 

disturbing these seafloor and shallow geologic features is discussed in the following summary:

Well Location 1: Features or areas that could support high-density deepwater benthic 

communities are not located within 2000 feet of any proposed muds and cuttings discharge 

location. The statement letter for the proposed well is included on page 2 of the Site Clearance 

Letter included in Attachment C-4.

(B) TOPOGRAPHIC FEATURES MAP 

Activities proposed in this EP do not fall within 305 meters (1000 feet) of a topographic “no 

activity zone”, therefore no map is required.

(C) TOPOGRAPHIC FEATURES STATEMENT (SHUNTING)

All activities proposed under this EP will be conducted outside all Topographic Feature 

Protective Zones; therefore, shunting of drill cuttings and drilling fluids is not required. 

(D) LIVE BOTTOMS (PINNACLE TREND) MAP

Mississippi Canyon Block 697 is not located within 61 meters (200 feet) of any pinnacle trend 

feature; therefore, a live bottom bathymetric map is not required. 

(E) LIVE BOTTOMS (LOW RELIEF) STIPULATION 

Mississippi Canyon Block 697 is not located within 100 feet of any pinnacle trend feature with 

vertical relief equal to or greater than 8 feet; therefore, live bottom (low relief) maps are not 

required.
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(F) POTENTIALLY SENSITIVE BIOLOGICAL FEATURES

Mississippi Canyon Block 697 is not located within 30 meters (100 feet) of potentially sensitive 

biological features; therefore, biologically sensitive area maps are not required.

(G) REMOTELY OPERATED VEHICLE (ROV) SURVEYS 

Mississippi Canyon Block 697 falls within Grid No. 17, an area which BOEM classifies as 

having inadequate ROV coverage. 

Pursuant to NTL No. 2008-G06, operators may be required to conduct remotely operated vehicle 

(ROV) surveys during pre-spudding and post-drilling operations for the purpose of biological 

and physical observations. 

If required, surveys will be conducted immediately prior and upon completion of drilling 

operations. 

A rig based ROV equipped with video imaging capabilities will be used. The survey pattern will 

consist of six transects centered on the well location with tracks extending approximately 100 

meters away from the well on bearings of 30 degrees, 90 degrees, 150 degrees, 210 degrees, 270 

degrees and 330 degrees. The seafloor will be videotaped continuously along each track.

Biological and physical observations as described in the subject NTL and Form BOEM-0141 

will be made prior to commencing drilling operations and also following the completion of 

drilling operations, but prior to moving the rig off location. The observations will be 

documented using Form BOEM-0141 or a facsimile and submitted to the BOEM within 60 days 

after the second survey is completed.

(H)THREATENED AND ENDANGERED SPECIES, CRITICAL HABITAT, AND MARINE 

MAMMAL INFORMATION

Under Section 7 of the Endangered Species Act (ESA) all federal agencies must ensure that any 

actions they authorize, fund, or carry out are not likely to jeopardize the continued existence of a 

listed species, or destroy or adversely modify its designated critical habitat.

In accordance with 30 CFR 550, Subpart B, effective May 14, 2007, and further outlined in NTL 

2008-G04, lessees/operators are required to address site-specific information on the presence of 

federally listed threatened or endangered species and critical habitat designated under the ESA 

and marine mammals protected under the Marine Mammal Protection Act (MMPA) in the area 

of proposes activities under this plan.

There are five species of sea turtles that may be found in the Gulf of Mexico (see table below), 

NOAA fisheries currently lists all five of these turtles as endangered (E) or threatened (T).
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Mississippi Canyon Block 697 (OCS-G 34019)

Species Scientific Name Status

Potential Presence

Critical Habitat Designated 

in the Gulf of Mexico Lease Area Coastal

Sea Turtles

Loggerhead Turtle Carettsa Caretta T x x None

Green Turtle Chelonia mydas T,E x x None

Leatherback Turtle Dermochelys corlacea E x x None

Hawksbill Turtle Eretmochelys imbricata E x x None

Kemp’s ridley turtle Lepidochelys kempli E x x None

Currently there are no designated critical habitats for the listed species in the Gulf of Mexico 

Outer Continental Shelf; however, it is possible that one or more of these species could be seen 

in the area of our operations.

(I) ARCHAEOLOGICAL REPORT

Mississippi Canyon 697 has been determined to have a high potential for containing 

archaeological properties; therefore, an Archaeological Survey Report has been prepared in 

accordance with NTL 2005-G07 "Archaeological Surveys and Reports" and is being submitted 

under separate cover.

(J) AIR AND WATER QUALITY INFORMATION

Air and water quality information is not required by BOEM to be included in this plan.

(K) SOCIOECONOMIC INFORMATION

Not applicable to this plan.
OCS-G-32343

NOBLE

MC697

MC698

MC742

OCS-G-31524

NOBLE

OCS-G-28021

NOBLE

OCS-G-28022

NOBLE

TGS survey inline number

Inline spacing = 41.01' (12.5m)

TGS survey crossline number

Crossline spacing = 41.01' (12.5m)Sonar contact & reference number

Mud volcano

Apex of linear mound on seafloorSuggested sonar contact avoidance area

Navigation trackline with name and direction run, fix and fix number

NOTE: 3D Seismic data acquired by TGS in March 2003.

 All AUV field data acquired Dec. 18-20, 2008. Survey vessels: M/V Miss Ginger, C-Surveyor III NADCON version 2.1 utilized for WGS84-NAD27 conversions.

SITE CLEARANCE

SEAFLOOR FEATURES & HAZARD MAP

PROPOSED WELL No. 1

BLOCK 697 (OCS-G-34019)

MISSISSIPPI CANYON AREA

Fault scarp with seafloor displacement (Hachures on downthrown side)
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APPENDIX F

WASTES AND DISCHARGES INFORMATION

(A) PROJECTED GENERATED WASTES

Table 1, “Wastes You Will Generate, Treat and Downhole Dispose or Discharge to the GOM”

is included in this section as Attachment F-1.
Type of Waste Composition Projected Amount Discharge rate Discharge Method 

Water-based drilling fluid Continuous phase and suspending medium for solids is water miscible fluid 82,000 bbls per well 2,000 bbls per hour per well Discharged at seabed (prior to marine riser installation); no free oil 

Cuttings wetted with water-based fluid

Particles generated by drilling into geologic formationsadhering to water based drilling fluids 3,200 bbls per well 35 bbls per hour per well Discharged at seabed (prior to marine riser installation); no free oil 

Cuttings wetted with syntheticbased fluid Particles generated by drilling into geologic formations adhering to synthetic based drilling fluids (internal olefin) 3,200 bbls per well 45 bbls per hour per well Discharged overboard line from cuttings dry

free oil 

Domestic waste Discharge from galleys, sinks, and showers 255,000 gallons per month 50 gallons per day per person POB 170 Discharge overboard; no floating solids Sanitary waste Human body waste from toilets and urinals 153,000 gallons per month 30 gallons per day per personPOB 170 Discharge overboard via treatment unit, no 

solids 

Deck Drainage Deck washing and rain water

3,000 bbls per month (dependent on rainfall)

100 bbls per day (dependent on rainfall)

Discharge overboard; no free oil 

Well treatment fluids XL Boraite 7500 bbls per well 400 bbls per well Discharge overboard; no free oil 

Well completion fluids Salt solutions, weighted brines, polymers, and various additives 9,000 bbls per well 200 bbls per hour per well Gravity oil/water separation then water disc

overboard with no free oil 

Workover fluids included in well completion fluids NA NA NA Desalinization unit discharge Seawater associated with making fresh water from seawater vis Osmosis 15,000 blls per month 500 BBls per day (dependent on use) Discharge overboard; no free oil Blowout preventer fluid Stack Magic at 3% (95% water and 2% glycol) 300 bbls per well 55 bbls per month Subsea discharge 

Ballast water Ballast water returned to sea without addition of chemicals 45,000 bbls per month 1,500 bbls per day Discharge overboard; no free oil 

Bilge water Bilge water returned to sea without addition of chemicals 600 bbls per month 20bbls/day Gravity oil/water separation then water disc

overboard with no free oil 

Excess cement at seafloor Discharges that occur at seabed prior to installation of marine riser 1000 bbls per well 400 bbls per hour per well Discharged at seabed (prior to marine riser installation); no free oil Seawater Uncontaminated Seawater 90,000 bbls per month No limit. Discharge overboard; no free oil Fire water included in seawater above NA NA NA Cooling water included in seawater above NA NA NA Produced water NA NA NA NA 

Table . WASTES GENERATED, TREATED AND DISPOSED OR DISCHARGED TO THE GOM BY DRILLING RIGProjected generated waste Projected ocean discharges 
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Initial Exploration Plan December 2012

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APPENDIX G

AIR EMISSIONS INFORMATION

(A) EMISSIONS WORKSHEETS AND SCREENING QUESTIONS

Screen Procedures for EP’s Yes No

Is any calculated Complex Total (CT) Emission amount (tons) associated with your 

proposed exploration activities more than 90% of the amounts calculated using the 

following formulas: CT = 3400D2/3 for CO, and CT = 33.3D for the other air pollutants 

(where D = distance to shore in miles)?

X

Do your emission calculations include any emission reduction measures or modified 

emission factors? X

Are your proposed exploration activities located east of 87.5° W longitude? X

Do you expect to encounter H2S at concentrations greater than 20 parts per million (ppm)? X

Do you propose to flare or vent natural gas for more than 48 continuous hours from any 

proposed well? X

Do you propose to burn produced hydrocarbon liquids? X

There are no existing facilities or activities co-located with the currently proposed activities, 

therefore the Complex Total Emissions are the same as the Plan Emissions and are provided in 

the table below.

Air Pollutant

Plan 

Emission 

Amounts1

(tons)

Calculated 

Exemption 

Amounts2

(tons)

Calculated 

Complex Total 

Emission 

Amounts3

(tons)

Carbon Monoxide (CO) 483.81 61,537.44 483.81

Particular Matter (PM) 64.51 2,564.10 64.51

Sulphur Dioxide (SO2) 295.93 2,564.10 295.93

Nitrogen Oxides (NOx) 2,217.45 2,564.10 2,217.45

Volatile Organic Compounds (VOC) 66.52 2,564.10 66.52

1

For activities proposed in your EP, list the projected emissions calculated from the worksheets.

2

List the exemption amounts for your proposed activities calculated by using the formulas in 30 CFR 550.303(d). 3

List the complex total emissions associated with your proposed activities calculated from the worksheets.

This information was calculated by: Melissa Flack

(281) 578-3388

melissa.flack@jccteam.com
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Initial Exploration Plan December 2012

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APPENDIX H

OIL SPILLS INFORMATION

(A) OIL SPILL RESPONSE PLANNING

All the proposed activities and facilities in the Exploration Plan will be covered by the Oil Spill 

Response Plan (OSRP) in accordance with 30 CFR 254 and approved on April 16, 2013. PAI

(BOEM Operator No. 01207) submitted the last modification to the Plan filed on January 14, 

2013 and March 1, 2013, and was approved April 16, 2013. 

(B) SPILL RESPONSE SITES

Primary Response Equipment Location Preplanned Staging Location

Houma , LA

Harvey, LA

Venice, LA

Houma , LA

Harvey, LA

Venice, LA

(C) OSRO INFORMATION

PAI’s primary equipment provider is Clean Gulf Associates (CGA). The Marine Spill Response 

Corporation’s (MSRC) STARS network will provide closest available personnel, as well as an 

MSRC supervisor to operate the equipment.

(D) WORST-CASE SCENARIO COMPARISON

Category Regional OSRP

WCD

EP

WCD

Type of Activity >10 Mile Drilling Exploratory Drilling

Facility Location (Area/Block) MC 697 MC 697

Facility Designation 1 1

Distance to Nearest Shoreline 

(miles) 77 77

Volume

 Storage Tanks (Total) 

Uncontrolled blowout

Total Volume

132,975 132,975

Type of Oil(s)

(crude, condensate, diesel) Crude Crude

API Gravity 29° 29°

Since PAI has the capability to respond to the appropriate worst-case spill scenario included in 

its regional OSRP approved on April 16, 2013, and since the worst-case scenario determined for 

our EP does not replace the appropriate worst-case scenario in our regional or subregional 

OSRP, I hereby certify that PAI has the capability to respond, to the maximum extent 
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Mississippi Canyon Block 697 (OCS-G 34019)

practicable, to a worst-case discharge, or a substantial threat of such a discharge, resulting from 

the activities proposed in our EP.

PAI submitted the new worst-case scenario to the BSEE GOMR for inclusion in our Regional 

OSRP (Control No. O-262) on January 14, 2013 and March 1, 2013. That OSRP was approved 

on April 16, 2013.

(E) SPILL RESPONSE DISCUSSION FOR NEPA ANALYSIS

SPILL RESPONSE DISCUSSION

For the purpose of NEPA and Coastal Zone Management Act analysis, the largest spill volume 

originating from the proposed activity would be a well blowout during drilling operations, 

estimated to be 132,975 barrels of crude oil with an API gravity of 29°.

Land Segment and Resource Identification

Trajectories of a spill and the probability of it impacting a land segment have been projected 

utilizing information in the BSEE Oil Spill Risk Analysis Model (OSRAM) for the Central and 

Western Gulf of Mexico available on the BSEE website. The results are shown in Figure 1. The 

BSEE OSRAM identifies an 11% probability of impact to the shorelines of Plaquemines Parish, 

Louisiana within 30 days. Plaquemines Parish includes Barataria Bay, the Mississippi River 

Delta, Breton Sound and the affiliated islands and bays. This region is an extremely sensitive 

habitat and serves as a migratory, breeding, feeding and nursery habitat for numerous species of 

wildlife. Beaches in this area vary in grain particle size and can be classified as fine sand, shell 

or perched shell beaches. Sandy and muddy tidal flats are also abundant.

Response

PAI will make every effort to respond to the Worst Case Discharge as effectively as practicable. 

A description of the response equipment under contract to contain and recover the Worst Case 

Discharge is shown in Figure 2.

Using the estimated chemical and physical characteristics of crude oil, an ADIOS weathering 

model was run on a similar product from the ADIOS oil database. The results indicate 12% or 

approximately 15,957 barrels of crude oil would be evaporated/dispersed within 24 hours, with 

approximately 117,018 barrels remaining.

Spill Response MC 697 A Barrels of Oil 

WCD Volume 132,975

Less 12% natural evaporation/dispersion 15,957

Remaining volume 117,018

Daily dispersant capability 7,540

Figure 2 outlines equipment, personnel, materials and support vessels as well as temporary 

storage equipment available to respond to a spill of approximately 117,018 barrels. The volume 
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Initial Exploration Plan December 2012

Mississippi Canyon Block 697 (OCS-G 34019)

accounts for the amount remaining after evaporation/dispersion at 24 hours. The list estimates 

individual times needed for procurement, load out, travel time to the site and deployment. Figure 

2 also indicates how operations will be supported. 

PAI’s Oil Spill Response Plan includes alternative response technologies such as dispersants and 

in-situ burn. Strategies will be decided by Unified Command based on the size of the spill, 

weather and potential impacts. If aerial dispersants are utilized, 8 sorties (9,600 gallons) from 

two of the DC-3 aircrafts and 4 sorties (8,000 gallons) from the Basler aircraft would provide a 

daily dispersant capability of 7,540 barrels. If the conditions are favorable for in-situ burning, the 

proper approvals have been obtained and the proper planning is in place, in-situ burning of oil 

may be attempted. Slick containment boom would be immediately called out and on-scene as 

soon as possible. Offshore response strategies may include attempting to skim utilizing the 

HOSS Barge, nine Fast Response Units (FRUs), and nine sets of Koseq skimming arms, with a 

total derated skimming capacity of 241,720 barrels. Temporary storage associated with 

skimming equipment equals 23,700 barrels. If additional storage is needed, a 25,000 barrel 

storage barge, two 23,000 barrel storage barges, a 47,000 barrel storage barge, and a 107,285 

barrel storage barge may be mobilized and centrally located to provide temporary storage 

allowing the skimmers to stay in the area of operations as much as possible. Safety is first 

priority. Air monitoring will be accomplished and operations deemed safe prior to any 

containment/skimming attempts. 

If the spill went unabated, shoreline impact in Plaquemines Parish, Louisiana would depend 

upon existing environmental conditions. Shoreline protection would include the use of CGA’s 

near shore and shallow water skimmers with a totaled derated skimming capacity of 74,126 

barrels. Temporary storage associated with skimming equipment equals 725 barrels. If additional 

storage is needed, a 23,000 barrel storage barge and three 20,000 barrel storage barges may be

mobilized and centrally located to provide temporary storage allowing the skimmers to stay in 

the area of operations as much as possible. Onshore response may include the deployment of 

shoreline boom on beach areas, or protection and sorbent boom on vegetated areas. Letters of 

Intent from OMI Environmental and AMPOL ensure access to 147,000 feet of 18” shoreline 

protection boom. Figure 2 outlines individual times needed for procurement, load out, travel 

time to the site and deployment. Strategies would be based upon surveillance and real time 

trajectories that depict areas of potential impact given actual sea and weather conditions. The 

State of Louisiana Initial Oil Spill Response Plan for Plaquemines Parish and Unified Command 

would be consulted to ensure that environmental and special economic resources would be 

correctly identified and prioritized to ensure optimal protection. Shoreline protection strategies 

depict the protection response modes applicable for oil spill clean-up operations. The State of 

Louisiana Initial Oil Spill Response Plan provides detailed shoreline protection strategies for this 

area, and it describes necessary action to keep the oil spill from entering Louisiana’s coastal 

wetlands, based on the assumption that removal of the released oil will be much easier and less 

damaging to fragile coastal ecosystems if done in the open waters of the Gulf of Mexico. 

Supervisory personnel have the option to modify the deployment and operation of equipment 

allowing a more effective response to site-specific circumstances. PAI’s contract Spill 

Management Team holds a copy of the State of Louisiana Initial Oil Spill Response Plan.
Petrobras America Inc. Page H-4

Initial Exploration Plan December 2012

Mississippi Canyon Block 697 (OCS-G 34019)

Based on the anticipated worst case discharge scenario, PAI can be onsite with contracted oil 

spill recovery equipment with adequate response capacity to contain and recover surface 

hydrocarbons, and prevent land impact, to the maximum extent practicable, within an estimated 

89 hours (based on the equipment’s Effective Daily Recovery Capacity (EDRC)).

Initial Response Considerations

Actual actions taken during an oil spill response will be based on many factors which include but 

are not limited to:

• Weather

• Equipment and materials availability

• Ocean currents and tides

• Location of the spill 

• Product spilled 

• Amount spilled

• Environmental risk assessments 

• Trajectory and product analysis

• Well status, i.e., shut in or continual release

PAI will take action to provide a safe, aggressive response to contain and recover as much of the 

spilled oil as quickly as it is safe to do so. In an effort to protect the environment, response 

actions will be designed to provide an “in-depth” protection strategy meant to recover as much 

oil as possible as far from environmentally sensitive areas as possible. Safety will take 

precedence over all other considerations during these operations. 

Upon notification of a spill, the following actions will be taken:

• Information will be confirmed

• An assessment will be made and initial objectives set

• OSROs and appropriate agencies will be notified 

• ICS 201, Initial Report Form will be completed 

• Initial Safety plan will be written and published

• Unified Command will be established

o Overall safety plan developed to reflect the operational situation and coordinated 

objectives

o Areas of responsibility established for Source Control and each surface operational 

site

o On-site command and control established

Offshore Response Actions

Equipment Deployment

Surveillance

• Surveillance Aircraft will be deployed within two hours of Qualified Individual (QI)

notification, or at first light
Petrobras America Inc. Page H-5

Initial Exploration Plan December 2012

Mississippi Canyon Block 697 (OCS-G 34019)

• Provide trained observer to provide on site status reports

• Provide command and control platform at the site if needed

• Continual surveillance of oil movement by remote sensing systems, aerial photography 

and visual confirmation 

• Continual monitoring of vessel assets using vessel monitoring systems 

Dispersant application assets

• Put Airborne Support Inc. (ASI) on standby

• With the Federal On-Scene Coordinator (FOSC), conduct analysis to determine 

appropriateness of dispersant application

• Gain FOSC approval for use of dispersants on the surface

• Deploy aircraft in accordance with a plan developed for the actual situation

• Coordinate movement of dispersants, aircraft, and support equipment and personnel

• Confirm dispersant availability for current and long range operations

• Start ordering dispersant stocks required for expected operations 

Containment boom

• Call out early and expedite deployment to be on scene ASAP

• Ensure boom handling and mooring equipment is deployed with boom

• Provide continuing reports to vessels to expedite their arrival at sites that will provide for 

their most effective containment 

• Use Vessels of Opportunity (VOO) to deploy and maintain boom 

Dedicated off-shore skimming systems

General

• Deployed to the highest concentration of oil

• Assets deployed at safe distance from aerial dispersant and in-situ burn operations

CGA HOSS Barge

• Use in areas with heaviest oil concentrations

• Consider for use in areas of known debris (seaweed, and other floating materials)

CGA FRUs

• To the area of the thickest oil

• Use as far off-shore as allowed

• VOOs 140’ – 180’ in length

• VOOs with minimum of 18’ x 38’ or 23’ x 50’ of optimum deck space

T&T Koseq Skimming Systems

• To the area of the thickest oil

• Use as far off-shore as allowed

• VOOs with a minimum of 2,000 bbls storage capacity

• VOOs at least 200’ in length
Petrobras America Inc. Page H-6

Initial Exploration Plan December 2012

Mississippi Canyon Block 697 (OCS-G 34019)

• VOOs with deck space of 100’ x 40’ to provide space for arms, tanks, and crane

Storage Vessels

• Establish availability of CGA contracted assets

• Early call out (to allow for tug boat acquisition and deployment speeds)

• Phase mobilization to allow storage vessels to arrive at the same time as skimming 

systems

• Position as closely as possible to skimming assets to minimize offloading time

Vessels of Opportunity (VOO)

• Use PAI’s contracted resources as applicable

• Industry vessels are usually best for deployment of Vessel of Opportunity Skimming 

Systems (VOSS)

• Acquire additional resources as needed 

• Consider use of local assets, i.e. fishing and pleasure craft

• Expect mission specific and safety training to be required

• Plan with the US Coast Guard for vessel inspections

In-situ Burn assets

• Determine appropriateness of in-situ burn operation in coordination with the FOSC and 

affected State On-Scene Coordinator (SOSC)

• Determine availability of fire boom and selected ignition systems

• Start ordering fire boom stocks required for expected operations

• Contact boom manufacturer to provide training if required

• Determine assets to perform on water operation

• Build operations into safety plan

• Conduct operations in accordance with an approved plan

Near Shore Response Actions

Timing

• Place near shore assets on standby and deploy in accordance with planning based on the 

actual situation, actual trajectories and oil budgets

• VOO identification and training in advance of spill nearing shoreline if possible

• Outfitting of VOOs for specific missions

• Deployment of assets based on actual movement of oil 

Considerations

• Water depth, vessel draft

• Shoreline gradient

• State of the oil 

• Use of VOOs
Petrobras America Inc. Page H-7

Initial Exploration Plan December 2012

Mississippi Canyon Block 697 (OCS-G 34019)

• Distance of surf zone from shoreline 

Equipment Deployment

Surveillance

• Provide trained observer to direct skimming operations

• Continual surveillance of oil movement by remote sensing systems, aerial photography 

and visual confirmation 

• Continual monitoring of vessel assets 

Dispersant Use

• Generally will not be approved within 3 miles of shore or with less than 10 meters of 

water depth 

• Approval would be at Regional Response Team level (Region 6) 

Vessel Deployment

Dedicated Near Shore skimming systems

• Fast Response Vessels (FRV)

• Egmopol and Marco Shallow Water Skimmer (SWS)

• Operate with aerial spotter directing systems to observed oil slicks

VOO

• Use PAI’s contracted resources as applicable

• Industry vessels are usually best for deployment of Vessel of Opportunity Skimming 

Systems (VOSS)

• Acquire additional resources as needed 

• Consider use of local assets, i.e. fishing and pleasure craft

• Expect mission specific and safety training to be required

• Plan with the US Coast Guard for vessel inspections

• Operate with aerial spotter directing systems to oil patches

Shoreline Protection Operations

Response Planning Considerations

• Environmental risk assessments (ERA) to determine priorities for area protection

• Time to acquire personnel and equipment and their availability

• Previous contingency planning contained in the appropriate Area Contingency Plan, and 

currently for Louisiana, The State of Louisiana Initial Oil Spill Response Plan, Deep 

Water Horizon, dated 2 May 2010

Actions

Placement of boom
Petrobras America Inc. Page H-8

Initial Exploration Plan December 2012

Mississippi Canyon Block 697 (OCS-G 34019)

• Position boom in accordance with the ERA based on the actual situation or the 

appropriate ACP 

• Assess timing of booming operations to ensure it is where it needs to be at time of 

impact. Consider:

o Trajectories

o Weather forecast

o Oil Impact forecast

o Verified spill movement

o Boom, manpower and vessel (shallow draft) availability

o Near shore boom and support material, (stakes, anchors, line)

Beach Preparation

Considerations and Actions

• Use of a 10 mile go/no go line to determine timing of beach cleaning

• Shoreline Cleanup and Assessment Team Reports and recommendations

• Determination of Archeological sites and gaining authority to enter 

• Monitoring of tide tables and weather to determine extent of high tides

• Pre cleaning of beaches by moving waste above high tide lines to minimize waste

• Staging of equipment and housing of response personnel as close to the job site as 

possible to maximize on-site work time

• Boom tending, repair, replacement and security (use of local assets may be advantageous) 

• Constant awareness of weather and oil movement for resource redeployment as necessary 

• In-situ burn may be considered when marshes have been impacted 

• Passive clean up of marshes should be considered and appropriate stocks of sorbent boom 

and/or sweep obtained

• Earthen berms and shoreline protection boom may be considered to protect sensitive 

inland areas 
Petrobras America Inc. Page H-9

Initial Exploration Plan December 2012

Mississippi Canyon Block 697 (OCS-G 34019)

Decanting Strategy

Recovered oil and water mixtures will typically separate into distinct phases when left in a 

quiescent state. When separation occurs, the relatively clean water phase can be siphoned or 

decanted back to the recovery point with minimal, if any, impact. Decanting therefore increases 

the effective on-site oil storage capacity and equipment operating time. FOSC/SOSC approval 

will be requested prior to decanting operations. This practice is routinely used for oil spill 

recovery.

CGA Equipment Limitations

The capability for any spill response equipment, whether a dedicated or portable system, to 

operate in differing weather conditions will be directly in relation to the capabilities of the vessel 

the system in placed on. Most importantly, however, the decision to operate will be based on the 

judgment of the Unified Command and/or the Captain of the vessel, who will ultimately have the 

final say in terminating operations. Skimming equipment listed below may have operational 

limits which exceed those safety thresholds. As was seen in the Deepwater Horizon (DWH) oil 

spill response, vessel skimming operations ceased when seas reached 5-6 feet and vessels were 

often recalled to port when those conditions were exceeded. Systems below are some of the 

most up-to-date systems available and were employed during the DWH spill. 

Boom 3 foot seas, 20 knot winds

Dispersants Winds more than 25 knots

Visibility less than 3 nautical miles

Ceiling less than 1,000 feet.

FRU 8 foot seas

HOSS Barge/OSRB 8 foot seas

Koseq Arms 8 foot seas

OSRV 4 foot seas
Petrobras America Inc. Page H-10

Initial Exploration Plan December 2012

Mississippi Canyon Block 697 (OCS-G 34019)

Environmental Conditions in the GOM

Louisiana is situated between the easterly and westerly wind belts, and therefore, experiences 

westerly winds during the winter and easterly winds in the summer. Average wind speed is 

generally 14-15 mph along the coast. Wave heights average 4 and 5 feet. However, during 

hurricane season, Louisiana has recorded wave heights ranging from 40 to 50 feet high and 

winds reaching speeds of 100 mph. Because much of southern Louisiana lies below sea level, 

flooding is prominent. 

Surface water temperature ranges between 70 and 80 ̊F during the summer months. During the 

winter, the average temperature will range from 50 and 60 ̊F. 

The Atlantic and Gulf of Mexico hurricane season is officially from 1 June to 30 November. 

97% of all tropical activity occurs within this window. The Atlantic basin shows a very peaked

season from August through October, with 78% of the tropical storm days, 87% of the minor 

(Saffir-Simpson Scale categories 1 and 2) hurricane days, and 96% of the major (Saffir-Simpson 

categories 3, 4 and 5) hurricane days occurring then. Maximum activity is in early to mid 

September. Once in a few years there may be a hurricane occurring "out of season" - primarily in 

May or December. Globally, September is the most active month and May is the least active 

month.
Petrobras America Inc. Page H-11

Initial Exploration Plan December 2012

Mississippi Canyon Block 697 (OCS-G 34019)

FIGURE 1

TRAJECTORY BY LAND SEGMENT

Trajectory of a spill and the probability of it impacting a land segment have been projected 

utilizing PAI’s WCD and information in the BSEE Oil Spill Risk Analysis Model 

(OSRAM) for the Central and Western Gulf of Mexico available on the BSEE website 

using 30 day impact. The results are tabulated below.

Area/Block OCS-G Launch

Area

Land Segment and/or 

Resource

Conditional 

Probability (%) 

within 30 days

Drill, complete and 

test one well

MC 697 Well 1

77 miles from shore

G34019 C59 Cameron, LA

Vermilion, LA

Terrebonne, LA

Lafourche, LA

Jefferson, LA

Plaquemines, LA

St. Bernard, LA

Walton, FL

Bay, FL

1

1

2

2

1

11

2

1

1
Petrobras America Inc. Page H-12

Initial Exploration Plan December 2012

Mississippi Canyon Block 697(OCS-G 34019)

WCD Scenario– BASED ON WELL BLOWOUT DURING DRILLING OPERATIONS (77 miles from shore)

117,018 bbls of crude oil (Volume considering natural weathering)

API Gravity 29°

FIGURE 2 – Equipment Response Time to MC 697 Well 1

Dispersants/Surveillance

Dispersant/Surveillance Dispersant 

Capacity (gal)

Storage 

Capacity Persons Req. From Hrs to Procure

Hrs to 

Loadout

Travel to 

site Total Hrs

CGA

Basler 67T 2000 NA 2 Houma 1 1 0.9 2.9

ASI

DC 3 1200 NA 2 Houma 1 1 1.2 3.2

DC 3 1200 NA 2 Houma 1 1 1.2 3.2

Aero Commander NA NA 2 Houma 1 1 0.9 2.9

Offshore Response

Offshore Equipment No 

Staging EDRC Storage Capacity VOO Persons Required From Hrs to Procure

Hrs to 

Loadout

Hrs to 

GOM

Travel to 

Spill Site

Hrs to 

Deploy

Total 

Hrs

CGA

HOSS Barge 43000 4000 3 Tugs 5 Harvey 7 0 5 11.3 1 24.3

Koseq Skimming Arms (3) 53487 6000 3 Utility 18 Galveston 24 24 4 34.2 2 88.2

Koseq Skimming Arms (3) 53487 6000 3 Utility 18 Leeville 24 24 10 11.3 2 71.3

Koseq Skimming Arms (1) 17829 2000 1 Utility 6 Fourchon 24 24 9.5 11.3 2 70.8

Koseq Skimming Arms (2) 35658 4000 2 Utility 12 Venice 24 24 11 7.5 2 68.5

Recovered Oil Storage No 

Staging EDRC Storage Capacity VOO Persons Required From Hrs to Procure

Hrs to 

Loadout

Hrs to 

GOM

Travel to 

Spill Site

Hrs to 

Deploy

Total 

Hrs

K-Sea Operating (available through contract with CGA)

DBL 101 1119760 NA 107285 1 Tug 6 Venice 4 12 2 11.25 1 30.25

Enterprise Marine Services LLC (available through contract with CGA)

CTCo 2603 NA 25000 1 Tug 6 Amelia 4 12 4 26.25 1 47.25

CTCo 2608 NA 23000 1 Tug 6 Amelia 4 12 4 26.25 1 47.25

CTCo 2609 NA 23000 1 Tug 6 Amelia 4 12 4 26.25 1 47.25

CTCo 5001 NA 47000 1 Tug 6 Amelia 4 12 4 26.25 1 47.25
Petrobras America Inc. Page H-13

Initial Exploration Plan December 2012

Mississippi Canyon Block 697(OCS-G 34019)

Staging Area: Venice

Offshore Equipment With 

Staging EDRC Storage Capacity VOO Persons Req. From Hrs to Procure

Hrs to 

Loadout

Travel to 

Staging

Travel to 

Site

Hrs to 

Deploy

Total 

Hrs

CGA

FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Galveston 1 2 8 7.5 1 19.5

FRU (1) + 100 bbl Tank (1) 4251 100 1 Utility 6 Harvey 1 2 1.75 7.5 1 13.3

FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Ingleside 1 2 11 7.5 1 22.5

FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Lake Charles 1 2 5.5 7.5 1 17.0

FRU (2) + 100 bbl Tank (2) 8502 400 2 Utility 12 Leeville 1 2 3.5 7.5 1 15.0

FRU (1) + 100 bbl Tank (2) 4251 200 1 Utility 6 Morgan City 1 2 3.25 7.5 1 14.8

FRU (2) + 100 bbl Tank (4) 8502 400 2 Utility 12 Venice 1 2 0 7.5 1 11.5

Offshore Equipment With 

Staging EDRC Storage Capacity VOO Persons Req. From Hrs to Procure

Hrs to 

Loadout

Travel to 

Staging

Travel to 

Site

Hrs to 

Deploy

Total 

Hrs

CGA

42” Auto Boom (5000’) NA NA 10 Crew 20 Galveston 1 2 8 7.5 1 19.5

42” Auto Boom (10000’) NA NA 20 Crew 40 Harvey 1 2 1.75 7.5 1 13.3

42” Auto Boom (2500’) NA NA 6 Crew 12 Ingleside 1 2 11 7.5 1 22.5

42” Auto Boom (5000’) NA NA 10 Crew 20 Lake Charles 1 2 5.5 7.5 1 17.0

42” Auto Boom (2500’) NA NA 6 Crew 12 Pascagoula 1 2 4 7.5 1 15.5

Hydro-Fire Boom NA NA 8 Utility 40 Harvey (HFB) 1 4 1.75 7.5 6 20.3
Petrobras America Inc. Page H-14

Initial Exploration Plan December 2012

Mississippi Canyon Block 697(OCS-G 34019)

Nearshore Response

Nearshore Equipment No 

Staging EDRC Storage Capacity VOO Persons Required From Hrs to Procure

Hrs to 

Loadout

Hrs to 

GOM

Travel to 

Spill Site

Hrs to 

Deploy

Total 

Hrs

CGA

46’ FRV 5000 65 NA 4 Leeville 1 0 2 2.0 0 5.0

46’ FRV 5000 65 NA 4 Venice 1 0 1 2.0 0 4.0

Trinity SWS 21500 249 NA 4 Leeville 1 2 2 2.0 0 7.0

Trinity SWS 21500 249 NA 4 Venice 1 2 2 2.0 0 7.0

Enterprise Marine Services LLC (available through contract with CGA)

CTCo 2604 NA 20000 1 Tug 6 Amelia 4 12 4 15 1 36

CTCo 2605 NA 20000 1 Tug 6 Amelia 4 12 4 15 1 36

CTCo 2606 NA 20000 1 Tug 6 Amelia 4 12 4 15 1 36

CTCo 2607 NA 23000 1 Tug 6 Amelia 4 12 4 15 1 36

Staging Area: Venice

Nearshore and Inland Skimmers With 

Staging EDRC Storage Capacity VOO Persons Req. From Hrs to Procure

Hrs to 

Loadout

Travel to 

Staging

Travel to 

Deployment

Hrs to 

Deploy Total Hrs

CGA

SWS Egmopol 3000 100 NA 3 Galveston 1 2 8 2 0 13

SWS Egmopol 3000 100 NA 3 Morgan City 1 2 3.25 2 0 8.25

SWS Marco 3588 20 NA 3 Lake Charles 1 2 5.5 2 0 10.5

SWS Marco 3588 34 NA 3 Leeville 1 2 3.5 2 0 8.5

SWS Marco 3588 34 NA 3 Venice 1 2 0 2 0 5

Rope Mop 77 2 0 3 Harvey 1 2 8 2 0 13

Foilex Skim Package (TDS 150) 891 45 NA 3 Lake Charles 1 2 5.5 2 0 8

Foilex Skim Package (TDS 150) 891 45 NA 3 Galveston 1 2 8 2 0 8

Foilex Skim Package (TDS 150) 891 45 NA 3 Harvey 1 2 1.75 2 0 11

4 Drum Skimmer (Magnum 100) 686 100 1 Crew 3 Lake Charles 1 2 5.5 2 0 8

4 Drum Skimmer (Magnum 100) 686 100 1 Crew 3 Harvey 1 2 1.75 2 0 11

2 Drum Skimmer (TDS 118) 240 100 1 Crew 3 Lake Charles 1 2 5.5 2 0 8
Petrobras America Inc. Page H-15

Initial Exploration Plan December 2012

Mississippi Canyon Block 697(OCS-G 34019)

Shoreline Protection

Staging Area: Venice

Shoreline Protection 

Boom VOO Persons Req. 

Storage/Warehouse

Location

Hrs to 

Procure

Hrs to 

Loadout

Travel to 

Staging

Travel to 

Deployment Site

Hrs to 

Deploy Total Hrs

AMPOL (available through Letter of Intent)

42,000’ 18” Boom 16 Crew 40 New Iberia, LA 2 2 4 2 12 22

20,000’ 18” Boom 8 Crew 20 New Orleans, LA 2 2 2 2 6 14

OMI Environmental (available through Letter of Intent)

10,000’ 18” Boom 4 Crew 10 New Iberia, LA 1 1 4 2 3 11

10,000’ 18” Boom 4 Crew 10 Houston, TX 1 1 7.5 2 3 14.5

10,000’ 18” Boom 4 Crew 10 Port Arthur, TX 1 1 6.25 2 3 13.25

20,000’ 18” Boom 8 Crew 20 Belle Chasse, LA 1 1 1.75 2 6 11.75

10,000’ 18” Boom 4 Crew 10 Port Allen, LA 1 1 3.5 2 3 10.5

10,000’ 18” Boom 4 Crew 10 Houma, LA 1 1 3.5 2 3 10.5

15,000’ 18” Boom 6 Crew 14 Gretna, LA (Warehouse) 2 2 2 2 4 12

Beach Boom EDRC Storage 

Capacity VOO Persons Req. From Hrs to Procure

Hrs to 

Loadout

Travel to 

Staging

Travel to 

Deployment

Hrs to 

Deploy Total Hrs

CGA

Beach Boom (2000’) NA NA NA 6 Galveston 1 2 8 1 2 14

Beach Boom (1000’) NA NA NA 4 Ingleside 1 2 11 1 2 17

Beach Boom (2000’) NA NA NA 6 Pascagoula 1 2 4 1 2 10
Petrobras America Inc. Page H-16

Initial Exploration Plan December 2012

Mississippi Canyon Block 697(OCS-G 34019)

Wildlife Response EDRC Storage 

Capacity VOO Persons Req. From Hrs to Procure

Hrs to 

Loadout

Travel to 

Staging

Travel to 

Deployment

Hrs to 

Deploy Total Hrs

CGA

Wildlife Support Trailer NA NA NA 2 Houma 1 2 3 1 2 9

Bird Scare Guns (24) NA NA NA 2 Belle Chasse 1 2 1.5 1 2 7.5

Bird Scare Guns (12) NA NA NA 2 Galveston 1 2 8 1 2 14

Bird Scare Guns (24) NA NA NA 2 Houma 1 2 3 1 2 9

Bird Scare Guns (12) NA NA NA 2 Ingleside 1 2 11 1 2 17

Bird Scare Guns (24) NA NA NA 2 Lake Charles 1 2 5.5 1 2 11.5

Bird Scare Guns (24) NA NA NA 2 Pascagoula 1 2 4 1 2 10

Response Asset Total

Offshore EDRC 241,720

Offshore Recovered Oil Storage 248,985

Nearshore / Shallow Water EDRC 74,126

Nearshore / Shallow Water Recovered Oil Storage 83,725
Petrobras America Inc. Page I-1

Initial Exploration Plan December 2012

Mississippi Canyon Block 697 (OCS-G 34019)

APPENDIX I

ENVIRONMENTAL MONITORING INFORMATION

(A) MONITORING SYSTEMS

Petrobras America Inc. will operate in accordance with NTL 2009-G02, to gather ocean current 

data for all floating MODU’s in water depths greater than 1,312 feet.

Monitoring and testing per Region 6 NPDES General Permit requirements will be completed. 

Monitoring and reporting applicable statistics to the BOEM and BSEE Gulf of Mexico Region 

(GOMR) regarding evacuation. 

(B) INCIDENTAL TAKES

There is no reason to believe that any of the endangered species or marine mammals as listed in 

the ESA will be “taken” as a result of the operations proposed under this plan. 

To date, it has been documented that the use of explosives and/or seismic devices can affect 

marine life. Operations proposed in this plan will not be utilizing either of these devices.

(C) FLOWER GARDEN BANKS NATIONAL MARINE SANCTUARY

Mississippi Canyon Block 697 is not located in the Flower Garden Banks National Marine 

Sanctuary; therefore, the requested information is not required in this EP.
Petrobras America Inc. Page J-1

Initial Exploration Plan December 2012

Mississippi Canyon Block 697 (OCS-G 34019)

APPENDIX J

LEASE STIPULATIONS INFORMATION

Exploration activities are subject to the following stipulation attached to Lease OCS-G 34019

Mississippi Canyon Block 697. 

Military Warning Area (MWA)

OCS-G 34019 is not located in a MWA, however, vessels and helicopters associated with 

exploration activities may traverse MWA Eglin Water Test Area (EWTA)-1. The Air Armament 

Center will be contacted in order to coordinate and control the electromagnetic emissions during 

the proposed operations.

Marine Protected Species

Lease Stipulation No. 6 is meant to reduce the potential taking of marine protected species. PAI

will operate in accordance with NTL 2012-G01-JOINT, to minimize the risk of vessel strikes to 

protected species and report observations of injured or dead protected species, and the prevention

of intentional and/or accidental introduction of debris into the marine environment.
Petrobras America Inc. Page K-1

Initial Exploration Plan December 2012

Mississippi Canyon Block 697 (OCS-G 34019)

APPENDIX K

ENVIRONMENTAL MITIGATION MEASURES INFORMATION

(A) MEASURES TAKEN TO AVOID, MINIMIZE, AND MITIGATE IMPACTS

Not applicable to this plan. 

(B) INCIDENTAL TAKES

PAI will adhere to the requirements as set forth in the following documents, as applicable, to 

avoid or minimize impacts to any of the species listed in the ESA as a result of the operations 

conducted herein:

• NTL 2012-G01-JOINT, “Vessel Strike Avoidance and Injured/Dead Protected Species 

Reporting”

• NTL BSEE 2012-G01, “Marine Trash and Debris Awareness and Elimination”

• NTL 2012-G02-JOINT, “Implementation of Seismic Survey Mitigation Measures and 

Protected Species Observer Program”
Petrobras America Inc. Page L-1

Initial Exploration Plan December 2012

Mississippi Canyon Block 697 (OCS-G 34019)

APPENDIX L

SUPPORT VESSELS AND AIRCRAFT INFORMATION

(A) GENERAL

The most practical, direct route from the shorebase as permitted by weather and traffic 

conditions will be utilized.

Type

Maximum Fuel 

Tank Capacity

Maximum 

Number in Area 

at Any Time

Trip Frequency 

or Duration

Offshore Service Vessel

(PSV) 8,900 bbls 3 2 roundtrips /week

Fast Supply Vessel 

(FSV) / Crew Boat 800 bbls 2 3 roundtrips /week

Helicopters 674 gals 1 1 roundtrips /day

(B) DIESEL OIL SUPPLY VESSELS

Size of Fuel Supply 

Vessel

Capacity of Fuel 

Supply Vessel

Frequency of Fuel 

Transfers

Route Fuel Supply 

Vessel Will Take

280’ 8,900 bbls 2 roundtrips /week

Shortest route from 

Port Fourchon, LA to 

Mississippi Canyon 

Block 697 and return 

to Port Fourchon, LA.

*Please note the actual vessels have not yet been contracted.

Table 2, “Wastes You Will Transport and/or Dispose of Onshore” is included in this section as 

Attachment L-1.

(E) VICINITY MAP

Enclosed as Attachment L-2 is a vicinity map showing the location of the activities proposed 

herein relative to the shoreline with the distance of the proposed activities from the shoreline and 

the primary route(s) of the support vessels and aircraft that will be used when traveling between 

the onshore support facilities and the drilling unit.
Solid and Liquid Wastes 

transportation 

Type of Waste Composition Transport Method Name/Location of Facility Amount 

Oil-based drilling fluid or mud NA NA NA NA Synthetic-based drilling fluid or mud 

 Continuous phase of the drilling fluid is a synthetic material

Tanks or drums on offshore support vessels

US Liquids (Port Fourchon, LA) or Newpark Services (Port Fourchon, LA)

750 bbls per well 

Cuttings wetted with Water-based fluid NA NA NA NA Cuttings wetted with Synthetic-based fluid NA NA NA NA Cuttings wetted with oil-based fluids NA NA NA NA Produced sand NA NA NA NA Trash and debris

Non-hazardous garbage, trash, and debris that can not be recycled

Containers on offshore support vessels Waste Management (Raceland, LA)

Two standar(25 m3) 

containers pweek

Used oil Lube oils (maintenance) Tote Tanks on offshore vessels Martin (Port Fourchon, LA10 totes per week 

Wash water NA NA NA NA Chemical product wastes NA NA NA NA 

Waste Disp

Table . WASTES TRANSPORTED AND /OR DISPOSED OF ONSHORE FROM DRILLING RIG

Projected generated waste
!!

!!

!!

!!

!!

!!

!!

!! !!

!!

Mississippi Canyon

Main Pass

West Delta

Grand Isle

Viosca Knoll

Main Pass South & East

Breton Sound

West Delta South

Grand Isle South

Ewing Bank

Venice

Lafitte

Fourchon

Grand Isle

River Ridge

Fort Jackson

Lafourche

Plaquemines

Jefferson

Petrobras America Inc. Vicinity Map

Mississippi Canyon 697

MC697

~77 Miles to shore

~137 Miles to Fourchon, LA Shorebase
Petrobras America Inc. Page M-1

Initial Exploration Plan December 2012

Mississippi Canyon Block 697 (OCS-G 34019)

APPENDIX M

ONSHORE SUPPORT FACILITIES INFORMATION

(A) GENERAL

Name of Shorebase Location Existing/New/Modified

Fourchon Service Base Port Fourchon, Louisiana Existing

MI Drilling Fluids Port Fourchon, Louisiana Existing

(B) SUPPORT BASE CONSTRUCTION OR EXPANSION

There will be no new construction of an onshore support base, nor will we expand the existing 

shorebase as a result of the operations proposed in this Exploration Plan.

(C) WASTE DISPOSAL

Table 2, “Wastes You Will Transport and/or Dispose of Onshore” is included in Appendix L as 

Attachment L-1.
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Mississippi Canyon Block 697 (OCS-G 34019)

APPENDIX N

COASTAL ZONE MANAGEMENT (CZMA) INFORMATION

Mississippi Canyon Block 697 is located offshore Louisiana and Alabama. Relevant enforceable 

policies were considered in certifying consistency for Louisiana. 

A certificate of Coastal Zone Management Consistency for the state of Louisiana is enclosed as

Attachment N-1. 
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Mississippi Canyon Block 697 (OCS-G 34019)

ALABAMA COASTAL ZONE MANAGEMENT

CONSISTENCY CERTIFICATION

INITIAL EXPLORATION PLAN – MISSISSIPPI CANYON BLOCK 697

A certificate of Coastal Zone Management Consistency for the state of Alabama is enclosed as 

Attachment N-2. The OCS related oil and gas development activities having potential impact on the 

Alabama Coastal Zone are based on the location of the proposed facilities, access to those sites, best 

practical techniques for operations and production equipment, guidelines for the prevention of adverse 

environmental effects, effective environmental protection, emergency plans and contingency plans. 

Alabama policies have been addressed below or are cross referenced to the appropriate sections of the 

plan:

Topic Cross 

Reference

Comments

Coastal Resource Use Policies

Coastal Development Dock and port facilities in LA will be used. There will be no new construction, 

dredging, or filling in Alabama state waters. There will be no new commercial 

development or capital improvements in Alabama’s coastal zone, nor will there be 

any employment effects.

Mineral Resource Exploration 

and Extraction

Proposed exploratory operations will take place 132 miles from Alabama’s 

coastline.

Commercial Fishing Appendix O There will be little or no impact on commercial fishing under normal operations.

Hazard Management Appendix C A Shallow Hazards Report has been prepared and submitted to BOEM in order to 

identify and assess the seafloor and shallow geologic conditions in this block. No 

significant geological hazards are reported.

Shoreline Erosion Proposed exploration operations will take place 132 miles from Alabama’s 

coastline. Dock and port facilities will be located in LA and vessels will follow the 

shortest direct route to the project area. There will be no new construction, 

dredging, or filling in Alabama state waters and this project will have no impact 

on Alabama coastal erosion.

Recreation Appendix O There are no known recreational uses of the lease area.

Transportation Appendix L This lease is not located in within the USCG-designated fairway or shipping lane.

Natural Resource Protection 

Policies

Biological Productivity Appendix O There will be no impacts to the coastal waters or shorelines of Alabama under 

normal operations during this project.

Water Quality Appendix O There would be no impacts to water quality within Alabama coastal waters under 

normal operating conditions.

Water Resources Appendix O

Air Quality Appendix G The Air Quality Emissions Report (AQR) prepared in accordance with BOEM 

requirements shows that the projected emissions are below the exemption levels; 

therefore. According to 30 CFR 550.303, the emissions will not significantly

affect the air quality. 

Wetlands and Submerged 

Grassbeds

Appendix O There will be no freshwater, nearshore or estuarine operations associated with this 

project and there will be no impacts to Alabama wetlands or submerged grassbeds 

under normal operations.

Beach and Dune Protection Appendix O There will be no impacts to Alabama beaches and dunes under normal operations.

Wildlife Habitat Protection Appendix O

Endangered Species Appendix O

Cultural Resources Protection Appendix E This block is not located in an area determined to have historic or prehistoric 

cultural resources. However, an Archaeological Report was previously submitted 

under separate cover to BOEM. It was determined that no man-made facilities or

seafloor obstructions were located in this block.




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APPENDIX O

ENVIRONMENTAL IMPACT ANALYSIS (EIA) 

Petrobras America Inc. (PAI)

Initial Exploration Plan

Mississippi Canyon Block 697

OCS-G 34019

(A) IMPACT PRODUCING FACTORS

ENVIRONMENTAL IMPACT ANALYSIS WORKSHEET

Environment

Resources

Impact Producing Factors (IPFs)

Categories and Examples

Refer to recent GOM OCS Lease Sale EIS for a more complete list of IPFs

Emissions 

(air, noise, 

light, etc.)

Effluents 

(muds, cutting, 

other 

discharges to 

the water 

column or 

seafloor)

Physical 

disturbances to 

the seafloor (rig 

or anchor 

emplacements, 

etc.)

Wastes sent 

to shore for 

treatment 

or disposal

Accidents 

(e.g., oil 

spills, 

chemical 

spills, H2S 

releases)

Discarded

Trash &

Debris

Site-specific at Offshore 

Location

Designated topographic features (1) (1) (1)

Pinnacle Trend area live bottoms (2) (2) (2)

Eastern Gulf live bottoms (3) (3) (3)

Benthic communities (4)

Water quality X X

Fisheries X X

Marine Mammals X(8) X X(8) X

Sea Turtles X(8) X X(8) X

Air quality X(9)

Shipwreck sites (known or 

potential)

(7)

Prehistoric archaeological sites X(7)

Vicinity of Offshore Location

Essential fish habitat X X(6)

Marine and pelagic birds X X

Public health and safety (5)

Coastal and Onshore

Beaches X(6) X

Wetlands X(6)

Shore birds and coastal nesting 

birds

X6)

Coastal wildlife refuges

Wilderness areas
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Footnotes for Environmental Impact Analysis Matrix

1) Activities that may affect a marine sanctuary or topographic feature. Specifically, if the well or platform site or any 

anchors will be on the seafloor within the:

o 4-mile zone of the Flower Garden Banks, or the 3-mile zone of Stetson Bank;

o 1000-m, 1-mile or 3-mile zone of any topographic feature (submarine bank) protected by the Topographic 

Features Stipulation attached to an OCS lease;

o Essential Fish Habitat (EFH) criteria of 500 ft. from any no-activity zone; or

o Proximity of any submarine bank (500 ft. buffer zone) with relief greater than 2 meters that is not protected by the 

Topographic Features Stipulation attached to an OCS lease.

2) Activities with any bottom disturbance within an OCS lease block protected through the Live Bottom (Pinnacle Trend) 

Stipulation attached to an OCS lease.

3) Activities within any Eastern Gulf OCS block where seafloor habitats are protected by the Live Bottom (Low-Relief) 

Stipulation attached to an OCS lease.

4) Activities on blocks designated by the BOEM as being in water depths 300 meters or greater.

5) Exploration or production activities where H2S concentrations greater than 500 ppm might be encountered.

6) All activities that could result in an accidental spill of produced liquid hydrocarbons or diesel fuel that you determine 

would impact these environmental resources. If the proposed action is located a sufficient distance from a resource that 

no impact would occur, the EIA can note that in a sentence or two.

7) All activities that involve seafloor disturbances, including anchor emplacements, in any OCS block designated by the 

BOEM as having high-probability for the occurrence of shipwrecks or prehistoric sites, including such blocks that will 

be affected that are adjacent to the lease block in which your planned activity will occur. If the proposed activities are 

located a sufficient distance from a shipwreck or a prehistoric site that no impact would occur, the EIA can note that in 

a sentence or two.

8) All activities that you determine might have an adverse effect on endangered or threatened marine mammals or sea 

turtles or their critical habitats.

9) Production activities that involve transportation of produced fluids to shore using shuttle tankers or barges.
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(B) Analysis

Site-Specific at Mississippi Canyon Block 697

Proposed operations consist of the drilling, completion, and potential testing of one well location.

The operations will be conducted with a drillship.

1. Designated Topographic Features

Potential IPFs on topographic features include effluents, and accidents. 

Effluents: Mississippi Canyon Block 697 is 90 miles from the closest designated Topographic 

Features Stipulation Block (Sackett Bank); therefore, no adverse impacts are expected. 

Accidents: It is unlikely that an accidental surface or subsurface spill would occur from the 

proposed activities (refer to statistics in Item 5, Water Quality). Oil spills cause damage to benthic 

organisms only if the oil contacts the organisms. Oil from a surface spill can be driven into the water 

column; measurable amounts have been documented down to a 10 m depth. At this depth, the oil is 

found only at concentrations several orders of magnitude lower than the amount shown to have an 

effect on corals. Because the crests of topographic features in the Northern Gulf of Mexico are found 

below 10 m, no oil from a surface spill could reach their sessile biota. Oil from a subsurface spill is not 

applicable due to the distance of these blocks from a topographic area. The activities proposed in this 

plan will be covered by PAI’s Regional OSRP (refer to information submitted in Appendix H).

There are no other IPFs (including emissions, physical disturbances to the seafloor and wastes sent to 

shore for disposal) from the proposed activities, which could impact topographic features.

2. Pinnacle Trend Area Live Bottoms

Potential IPFs on pinnacle trend area live bottoms include effluents and accidents. 

Effluents: Mississippi Canyon Block 697 is 62 miles from the closest live bottom (pinnacle trend) 

area; therefore, no adverse impacts are expected. 

Accidents: It is unlikely that an accidental surface or subsurface spill would occur from the 

proposed activities (refer to statistics in Item 5, Water Quality). Oil spills have the potential to foul 

benthic communities and cause lethal and sublethal effects on live bottom organisms. Oil from a 

surface spill can be driven into the water column; measurable amounts have been documented down to 

a 10 m depth. At this depth, the oil is found only at concentrations several orders of magnitude lower 

than the amount shown to have an effect on marine organisms. Oil from a subsurface spill is not 

applicable due to the distance of these blocks from a live bottom (pinnacle trend) area. The activities 
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proposed in this plan will be covered by PAI’s Regional OSRP (refer to information submitted in 

Appendix H). 

There are no other IPFs (including emissions, physical disturbances to the seafloor and wastes sent to 

shore for disposal) from the proposed activities which could impact a live bottom (pinnacle trend) area. 

3. Eastern Gulf Live Bottoms

Potential IPFs on Eastern Gulf live bottoms include effluents and accidents.

Effluents: Mississippi Canyon Block 697 is not located in an area characterized by the existence of 

live bottoms; therefore, no adverse impacts are expected.

Accidents: It is unlikely that an accidental surface or subsurface spill would occur from the 

proposed activities (refer to statistics in Item 5, Water Quality). Oil spills cause damage to live bottom 

organisms only if the oil contacts the organisms. Oil from a surface spill can be driven into the water 

column; measurable amounts have been documented down to a 10 m depth. At this depth, the oil is 

found only at concentrations several orders of magnitude lower than the amount shown to have an 

effect on marine invertebrates. Oil from a subsurface spill is not applicable due to the distance of these 

blocks from a live bottom area. The activities proposed in this plan will be covered by PAI’s Regional 

OSRP (refer to information submitted in Appendix H). 

There are no other IPFs (including emissions, physical disturbances to the seafloor and wastes sent to 

shore for disposal) from the proposed activities which could impact an Eastern Gulf live bottom area. 

4. Benthic Communities 

There are no IPFs (including emissions, physical disturbances to the seafloor, wastes sent to shore for 

disposal, or accidents) from the proposed activities that could cause impacts to benthic communities.

A drillship is being used for the proposed activities; therefore, only an insignificant amount of seafloor 

will be disturbed. Because physical disturbances to the seafloor will be minimized by the use of a 

drillship, PAI’s proposed operations in Mississippi Canyon Block 697 would not cause impacts to 

benthic communities.

5. Water Quality

IPFs that could result in water quality degradation from the proposed operations in Mississippi Canyon 

Block 697 include effluents and accidents.

Effluents: Levels of contaminants in drilling muds and cuttings and produced water discharges, 

discharge-rate restrictions and monitoring and toxicity testing are regulated by the EPA NPDES 

permit, thereby eliminating many significant biological or ecological effects. Operational discharges 

are not expected to cause significant adverse impacts to water quality.
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Accidents: Oil spills have the potential to alter offshore water quality; however, it is unlikely that an 

accidental surface or subsurface spill would occur from the proposed activities. Between 1980 and 

2000, OCS operations produced 4.7 billion barrels of oil and spilled only 0.001 percent of this oil, or 1 

bbl for every 81,000 bbl produced. The spill risk related to a diesel spill from drilling operations is 

even less. Between 1976 and 1985, (years for which data were collected), there were 80 reported 

diesel spills greater than one barrel associated with drilling activities. Considering that there were 

11,944 wells drilled, this is a 0.7 percent probability of an occurrence. If a spill were to occur, the 

water quality of marine waters would be temporarily affected by the dissolved components and small 

oil droplets. Dispersion by currents and microbial degradation would remove the oil from the water 

column and dilute the constituents to background levels. Historically, changes in offshore water quality 

from oil spills have only been detected during the life of the spill and up to several months afterwards. 

Most of the components of oil are insoluble in water and therefore float. The activities proposed in this 

plan will be covered by PAI’s Regional Oil Spill Response Plan (refer to information submitted in 

Appendix H).

There are no other IPFs (including emissions, physical disturbances to the seafloor, and wastes sent to 

shore for disposal) from the proposed activities which could cause impacts to water quality.

6. Fisheries

IPFs that could cause impacts to fisheries as a result of the proposed operations in Mississippi Canyon 

Block 697 include effluents and accidents. 

Effluents: Effluents such as drilling fluids and cuttings discharges contain components and 

properties which are detrimental to fishery resources. Moderate petroleum and metal contamination of 

sediments and the water column can occur out to several hundred meters down-current from the 

discharge point. Offshore discharges are expected to disperse and dilute to very near background 

levels in the water column or on the seafloor within 3,000 m of the discharge point, and are expected to 

have negligible effect on fisheries.

Accidents: An accidental oil spill has the potential to cause some detrimental effects on fisheries;

however, it is unlikely that such an event would occur from the proposed activities (refer to Item 5, 

Water Quality). The effects of oil on mobile adult finfish or shellfish would likely be sublethal and the 

extent of damage would be reduced to the capacity of adult fish and shellfish to avoid the spill, to 

metabolize hydrocarbons, and to excrete both metabolites and parent compounds. The activities 

proposed in this plan will be covered by PAI’s Regional OSRP (refer to information submitted in 

Appendix H). 

There are no IPFs from emissions, physical disturbances to the seafloor or wastes sent to shore for 

disposal from the proposed activities which could cause impacts to fisheries.
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7. Marine Mammals

GulfCet II studies revealed that cetaceans of the continental shelf and shelf-edge were almost 

exclusively bottlenose dolphin and Atlantic spotted dolphin. Squid eaters, including dwarf and pygmy 

killer whale, Risso’s dolphin, rough-toothed dolphin, and Cuvier’s beaked whale, occurred most 

frequently along the upper slope in areas outside of anticyclones. IPFs that could cause impacts to 

marine mammals as a result of the proposed operations in Mississippi Canyon Block 697 include 

emissions, effluents, discarded trash and debris, and accidents. 

Emissions: Noises from drilling activities, support vessels and helicopters may elicit a startle 

reaction from marine mammals. This reaction may lead to disruption of marine mammals’ normal 

activities. Stress may make them more vulnerable to parasites, disease, environmental contaminants, 

and/or predation (Majors and Myrick, 1990). There is little conclusive evidence for long-term 

displacements and population trends for marine mammals relative to noise.

Effluents: Drilling fluids and cuttings discharges contain components which may be detrimental to 

marine mammals. Most operational discharges are diluted and dispersed upon release. Any potential 

impact from drilling fluids would be indirect, either as a result of impacts on prey items or possibly 

through ingestion in the food chain (API, 1989). 

Discarded trash and debris: Both entanglement in, and ingestion of debris have caused the death 

or serious injury of marine mammals (Laist, 1997; MMC, 1999). The limited amount of marine debris, 

if any, resulting from the proposed activities is not expected to substantially harm marine mammals. 

Operators are prohibited from deliberately discharging debris as mandated by MARPOL-Annex V and 

the Marine Plastic Pollution Research and Control Act, and regulations imposed by various agencies 

including the United States Coast Guard (USCG) and the Environmental Protection Agency (EPA).

PAI will operate in accordance with the regulations and also avoid accidental loss of solid waste items 

by maintaining waste management plans, manifesting trash sent to shore, and using special precautions 

such as covering outside trash bins to prevent accidental loss of solid waste. Special caution will be 

exercised when handling and disposing of small items and packaging materials, particularly those 

made of non-biodegradable, environmentally persistent materials such as plastic or glass.

Informational placards will be posted on all vessels and facilities having sleeping or food preparation 

capabilities. All offshore personnel, including contractors and other support services-related personnel 

(e.g. helicopter pilots, vessel captains and boat crews) will be indoctrinated on waste procedures, and 

will view the video (or Microsoft PowerPoint presentation), “Think About It” (previously “All Washed 

Up: The Beach Litter Problem”). Thereafter, all personnel will view the marine trash and debris 

training video annually. Offshore personnel will also receive an explanation from PAI management or 

the designated lease operator management that emphasizes their commitment to waste management in 

accordance with NTL No. 2012-G01.
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Accidents: Collisions between support vessels and cetaceans would be unusual events, however 

should one occur, death or injury to marine mammals is possible. Contract vessel operators can avoid 

marine mammals and reduce potential deaths by maintaining a vigilant watch for marine mammals and 

maintaining a safe distance when they are sighted. Vessel crews should use a reference guide to help 

identify the twenty-eight species of whales and dolphins, and the single species of manatee that may be 

encountered in the Gulf of Mexico OCS. Vessel crews must report sightings of any injured or dead 

protected marine mammal species immediately, regardless of whether the injury or death is caused by 

their vessel, to the Marine Mammal and Sea Turtle Stranding Hotline at (888) 404-3922, the NMFS 

Southeast Regional Office at (727) 824-5312, or the Marine Mammal Stranding Network at (305) 862-

2850. In addition, if the injury or death was caused by a collision with a contract vessel, the BOEM

must be notified within 24 hours of the strike by email to protectedspecies@boemre.gov. If the vessel 

is the responsible party, it is required to remain available to assist the respective salvage and stranding 

network as needed. 

Oil spills have the potential to cause sublethal oil-related injuries and spill-related deaths to marine 

mammals. However, it is unlikely that an accidental oil spill would occur from the proposed activities 

(refer to Item 5, Water Quality). Oil spill response activities may increase vessel traffic in the area, 

which could add to changes in cetacean behavior and/or distribution, thereby causing additional stress 

to the animals. The effect of oil dispersants on cetaceans is not known. The acute toxicity of oil 

dispersant chemicals included in PAI’s OSRP is considered to be low when compared with the 

constituents and fractions of crude oils and diesel products. The activities proposed in this plan will be 

covered by PAI’s OSRP (refer to information submitted in accordance with Appendix H).

There are no other IPFs (including physical disturbances to the seafloor) from the proposed activities 

which could impact marine mammals.

8. Sea Turtles

IPFs that could cause impacts to sea turtles as a result of the proposed operations include emissions, 

effluents, discarded trash and debris, and accidents. GulfCet II studies sighted most loggerhead, 

Kemp’s ridley and leatherback sea turtles over shelf waters. Historically these species have been 

sighted up to the shelf’s edge. They appear to be more abundant east of the Mississippi River than 

they are west of the river (Fritts et al., 1983b; Lohoefener et al., 1990). Deep waters may be used by all 

species as a transitory habitat.

Emissions: Noise from drilling activities, support vessels, and helicopters may elicit a startle 

reaction from sea turtles, but this is a temporary disturbance.

Effluents: Drilling fluids and cuttings discharges are not known to be lethal to sea turtles. Most 

operational discharges are diluted and dispersed upon release. Any potential impact from drilling 

fluids would be indirect, either as a result of impacts on prey items or possibly through ingestion in the 

food chain (API, 1989).
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Discarded trash and debris: Both entanglement in, and ingestion of, debris have caused the death or 

serious injury of sea turtles (Balazs, 1985). The limited amount of marine debris, if any, resulting from 

the proposed activities is not expected to substantially harm sea turtles. Operators are prohibited from 

deliberately discharging debris as mandated by MARPOL-Annex V and the Marine Plastic Pollution 

Research and Control Act, and regulations imposed by various agencies including the United States 

Coast Guard (USCG) and the Environmental Protection Agency (EPA). PAI will operate in 

accordance with the regulations and also avoid accidental loss of solid waste items by maintaining 

waste management plans, manifesting trash sent to shore, and using special precautions such as 

covering outside trash bins to prevent accidental loss of solid waste. Special caution will be exercised 

when handling and disposing of small items and packaging materials, particularly those made of nonbiodegradable, environmentally persistent materials such as plastic or glass.

Informational placards will be posted on all vessels and facilities having sleeping or food preparation 

capabilities. All offshore personnel, including contractors and other support services-related personnel 

(e.g. helicopter pilots, vessel captains and boat crews) will be indoctrinated on waste procedures, and 

will view the video (or Microsoft PowerPoint presentation), “Think About It” (previously “All Washed 

Up: The Beach Litter Problem”). Thereafter, all personnel will view the marine trash and debris 

training video annually. Offshore personnel will also receive an explanation from PAI management or 

the designated lease operator management that emphasizes their commitment to waste management in 

accordance with NTL No. 2012-G01.

Accidents: Collisions between support vessels and sea turtles would be unusual events, however 

should one occur, death or injury to sea turtles is possible. Contract vessel operators can avoid sea 

turtles and reduce potential deaths by maintaining a vigilant watch for sea turtles and maintaining a 

safe distance when they are sighted. Vessel crews should use a reference guide to help identify the 

five species of sea turtles that may be encountered in the Gulf of Mexico OCS. Vessel crews must 

report sightings of any injured or dead protected sea turtle species immediately, regardless of whether 

the injury or death is caused by their vessel, to the Marine Mammal and Sea Turtle Stranding Hotline 

at (888) 404-3922, the NMFS Southeast Regional Office at (727) 824-5312, or the Marine Mammal 

Stranding Network at (305) 862-2850. In addition, if the injury or death was caused by a collision with 

a contract vessel, the BOEM must be notified within 24 hours of the strike by email to 

protectedspecies@boemre.gov. If the vessel is the responsible party, it is required to remain available 

to assist the respective salvage and stranding network as needed. 

All sea turtle species and their life stages are vulnerable to the harmful effects of oil through direct 

contact or by fouling of their food. Exposure to oil can be fatal, particularly to juveniles and hatchlings. 

However, it is unlikely that an accidental oil spill would occur from the proposed activities (refer to 

Item 5, Water Quality). Oil spill response activities may increase vessel traffic in the area, which 

could add to the possibility of collisions with sea turtles. The activities proposed in this plan will be 

covered by PAI’s Regional Oil Spill Response Plan (refer to information submitted in accordance with 

Appendix H).
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There are no other IPFs (including physical disturbances to the seafloor) from the proposed activities 

which could impact sea turtles.

9. Air Quality

Mississippi Canyon Block 697 is located 102 miles from the Breton Wilderness Area and 77 miles 

from shore. Applicable emissions data is included in Appendix G of the Plan.

There would be a limited degree of air quality degradation in the immediate vicinity of the proposed 

activities. Plan Emissions for the proposed activities do not exceed the annual exemption levels as set 

forth by BOEM. Accidents and blowouts can release hydrocarbons or chemicals, which could cause 

the emission of air pollutants. However, these releases would not impact onshore air quality because 

of the prevailing atmospheric conditions, emission height, emission rates, and the distance of 

Mississippi Canyon Block 697 from the coastline. There are no other IPFs (including effluents, 

physical disturbances to the seafloor, wastes sent to shore for treatment or disposal) from the proposed 

activities which would impact air quality.

10. Shipwreck Sites (known or potential)

Potential IPFs that could impact known or unknown shipwreck sites as a result of the proposed 

operations in Mississippi Canyon Block 697 include disturbances to the seafloor.

Physical disturbances to the seafloor: A drillship is being used for the proposed activities; 

therefore, only an insignificant amount of seafloor will be disturbed. Because physical disturbances to 

the seafloor will be minimized by the use of a drillship, PAI’s proposed operations in Mississippi 

Canyon Block 697 would not cause impacts to shipwreck sites.

Additionally, Mississippi Canyon Block 697 is not located in or adjacent to an OCS block designated 

by BOEM as having a high probability for occurrence of shipwrecks, therefore, no adverse impacts are 

expected.

PAI will perform an AUV/ROV survey imaging 100% of the seafloor with sector scanning sonar 

within a minimum 500’ radius of the proposed well location(s) prior to or upon commencement of 

operations. These locations will be certified by an authorized marine archaeologist and by PAI to be 

clear of seafloor archaeological resources, including historic shipwrecks. Copies of the certifications 

and a circle radius plat of the survey area will be submitted to the BOEM. Should a resource be

encountered, PAI will contact the BOEM immediately and make every reasonable effort to preserve 

and protect that cultural resource.

There are no other IPFs (including emissions, effluents, wastes sent to shore for treatment or disposal, 

or accidents) from the proposed activities that could cause impacts to shipwreck sites.
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11. Prehistoric Archaeological Sites

IPFs that could cause impacts to prehistoric archaeological sites as a result of the proposed operations 

in Mississippi Canyon Block 697 are physical disturbances to the seafloor and accidents (oil spills). 

Physical Disturbances to the seafloor: Although the operations proposed will be conducted by 

utilizing a drillship, which would cause only an insignificant amount of seafloor to be disturbed, 

Mississippi Canyon Block 697 is located inside the Archaeological Prehistoric high probability lines. 

PAI will report to BOEM the discovery of any object of prehistoric archaeological significance and 

make every reasonable effort to preserve and protect that cultural resource.

PAI will perform an AUV/ROV survey imaging 100% of the seafloor with sector scanning sonar 

within a minimum 500’ radius of the proposed well location(s) prior to or upon commencement of 

operations. These locations will be certified by an authorized marine archaeologist and by PAI to be 

clear of seafloor archaeological resources. Copies of the certifications and a circle radius plat of the 

survey area will be submitted to the BOEM. Should a resource be encountered, PAI will contact the 

BOEM immediately and make every reasonable effort to preserve and protect that cultural resource. .

Accidents: An accidental oil spill has the potential to cause some detrimental effects to prehistoric 

archaeological sites if the release were to occur subsea. However, it is unlikely that an accidental oil 

spill would occur from the proposed activities (refer to Item 5, Water Quality). The activities proposed 

in this plan will be covered by PAI’s Regional Oil Spill Response Plan (refer to information submitted 

in accordance with Appendix H).

There are no other IPFs (including emissions, effluents or wastes sent to shore for treatment or 

disposal) from the proposed activities which could impact prehistoric archeological sites.

Vicinity of Offshore Location

1. Essential Fish Habitat (EFH)

IPFs that could cause impacts to EFH as a result of the proposed operations in Mississippi Canyon 

Block 697 include effluents and accidents. EFH includes all estuarine and marine waters and substrates 

in the Gulf of Mexico. 

Effluents: The Live Bottom Low Relief Stipulation, the Live Bottom (Pinnacle Trend) Stipulation, 

and the Eastern Gulf Pinnacle Trend Stipulation would prevent most of the potential impacts on livebottom communities and EFH from operational waste discharges. Levels of contaminants in drilling 

muds and cuttings and produced-water discharges, discharge-rate restrictions, and monitoring and 

toxicity testing are regulated by the EPA NPDES permit, thereby eliminating many significant 

biological or ecological effects. Operational discharges are not expected to cause significant adverse 

impacts to EFH.
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Accidents: An accidental oil spill has the potential to cause some detrimental effects on EFH. Oil 

spills that contact coastal bays and estuaries, as well as OCS waters when pelagic eggs and larvae are 

present, have the greatest potential to affect fisheries. However, it is unlikely that an oil spill would 

occur from the proposed activities (refer to Item 5, Water Quality). The activities proposed in this plan 

will be covered by PAI’s Regional OSRP (refer to information submitted in Appendix H).

There are no other IPFs (including emissions, physical disturbances to the seafloor and wastes sent to

shore for treatment or disposal) from the proposed activities which could impact essential fish habitat.

2. Marine and Pelagic Birds 

IPFs that could impact marine birds as a result of the proposed activities include air emissions, 

accidental oil spills, and discarded trash and debris from vessels and the facilities.

Emissions: Emissions of pollutants into the atmosphere from these activities are far below 

concentrations which could harm coastal and marine birds.

Accidents: An oil spill would cause localized, low-level petroleum hydrocarbon contamination. 

However, it is unlikely that an oil spill would occur from the proposed activities (refer to Item 5, 

Water Quality). Marine and pelagic birds feeding at the spill location may experience chronic, 

nonfatal, physiological stress. It is expected that few, if any, coastal and marine birds would actually 

be affected to that extent. The activities proposed in this plan will be covered by PAI’s Regional OSRP 

(refer to information submitted in Appendix H).

Discarded trash and debris: Marine and pelagic birds could become entangled and snared in 

discarded trash and debris, or ingest small plastic debris, which can cause permanent injuries and 

death. Operators are prohibited from deliberately discharging debris as mandated by MARPOL-Annex 

V and the Marine Plastic Pollution Research and Control Act, and regulations imposed by various 

agencies including the United States Coast Guard (USCG) and the Environmental Protection Agency 

(EPA). PAI will operate in accordance with the regulations and also avoid accidental loss of solid 

waste items by maintaining waste management plans, manifesting trash sent to shore, and using special 

precautions such as covering outside trash bins to prevent accidental loss of solid waste. Special 

caution will be exercised when handling and disposing of small items and packaging materials, 

particularly those made of non-biodegradable, environmentally persistent materials such as plastic or 

glass. Informational placards will be posted on all vessels and facilities having sleeping or food 

preparation capabilities. All offshore personnel, including contractors and other support servicesrelated personnel (e.g. helicopter pilots, vessel captains and boat crews) will be indoctrinated on waste 

procedures, and will view the video (or Microsoft PowerPoint presentation), “Think About It” 

(previously “All Washed Up: The Beach Litter Problem”). Thereafter, all personnel will view the 

marine trash and debris training video annually. Offshore personnel will also receive an explanation 

from PAI management or the designated lease operator management that emphasizes their 

commitment to waste management in accordance with NTL No. 2012-G01. Debris, if any, from these 
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proposed activities will seldom interact with marine and pelagic birds; therefore, the effects will be 

negligible.

There are no other IPFs (including effluents, physical disturbances to the seafloor, or wastes sent to 

shore for treatment or disposal) from the proposed activities which could impact marine and pelagic 

birds.

3. Public Health and Safety Due to Accidents.

There are no IPFs (emissions, effluents, physical disturbances to the seafloor, wastes sent to shore for 

treatment or disposal or accidents, including an accidental H2S release) from the proposed activities 

which could cause impacts to public health and safety. In accordance with NTL No.’s 2008-G04, 

2009-G27, and 2009-G31, sufficient information is included in Appendix D to justify our request that 

our proposed activities be classified by BSEE as H2S absent. 

Coastal and Onshore

1. Beaches

IPFs from the proposed activities that could cause impacts to beaches include accidents (oil spills) and 

discarded trash and debris. 

Accidents: Oil spills contacting beaches would have impacts on the use of recreational beaches and 

associated resources. Due to the distance from shore (77 miles) and the response capabilities that 

would be implemented, no significant adverse impacts are expected. The activities proposed in this 

plan will be covered by PAI’s Regional OSRP (refer to information submitted in Appendix H). 

Discarded trash and debris: Trash on the beach is recognized as a major threat to the enjoyment 

and use of beaches. There will only be a limited amount of marine debris, if any, resulting from the

proposed activities. Operators are prohibited from deliberately discharging debris as mandated by 

MARPOL-Annex V and the Marine Plastic Pollution Research and Control Act, and regulations 

imposed by various agencies including the United States Coast Guard (USCG) and the Environmental 

Protection Agency (EPA). PAI will operate in accordance with the regulations and also avoid 

accidental loss of solid waste items by maintaining waste management plans, manifesting trash sent to 

shore, and using special precautions such as covering outside trash bins to prevent accidental loss of 

solid waste. Special caution will be exercised when handling and disposing of small items and 

packaging materials, particularly those made of non-biodegradable, environmentally persistent 

materials such as plastic or glass.

Informational placards will be posted on all vessels and facilities having sleeping or food preparation 

capabilities. All offshore personnel, including contractors and other support services-related personnel 

(e.g. helicopter pilots, vessel captains and boat crews) will be indoctrinated on waste procedures, and 

will view the video (or Microsoft PowerPoint presentation), “Think About It” (previously “All Washed 
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Up: The Beach Litter Problem”). Thereafter, all personnel will view the marine trash and debris 

training video annually. Offshore personnel will also receive an explanation from PAI management or 

the designated lease operator management that emphasizes their commitment to waste management in 

accordance with NTL No. 2012-G01.

There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes sent to 

shore for treatment or disposal) from the proposed activities which could impact beaches.

2. Wetlands

IPFs from the proposed activities that could cause impacts to wetlands include accidents (oil spills) and 

discarded trash and debris. 

Accidents: It is unlikely that an oil spill would occur from the proposed activities (refer to Item 5, 

Water Quality). Due to the distance from shore (77 miles) and the response capabilities that would be 

implemented, no impacts are expected. The activities proposed in this plan will be covered by PAI’s 

Regional OSRP (refer to information submitted in Appendix H). 

Discarded trash and debris: There will only be a limited amount of marine debris, if any, 

resulting from the proposed activities. Operators are prohibited from deliberately discharging debris as 

mandated by MARPOL-Annex V and the Marine Plastic Pollution Research and Control Act, and 

regulations imposed by various agencies including the United States Coast Guard (USCG) and the 

Environmental Protection Agency (EPA). PAI will operate in accordance with the regulations and also 

avoid accidental loss of solid waste items by maintaining waste management plans, manifesting trash 

sent to shore, and using special precautions such as covering outside trash bins to prevent accidental 

loss of solid waste. Special caution will be exercised when handling and disposing of small items and 

packaging materials, particularly those made of non-biodegradable, environmentally persistent 

materials such as plastic or glass.

Informational placards will be posted on all vessels and facilities having sleeping or food preparation 

capabilities. All offshore personnel, including contractors and other support services-related personnel 

(e.g. helicopter pilots, vessel captains and boat crews) will be indoctrinated on waste procedures, and 

will view the video (or Microsoft PowerPoint presentation), “Think About It” (previously “All Washed 

Up: The Beach Litter Problem”). Thereafter, all personnel will view the marine trash and debris 

training video annually. Offshore personnel will also receive an explanation from PAI management or 

the designated lease operator management that emphasizes their commitment to waste management in 

accordance with NTL No. 2012-G01.

There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes sent to 

shore for treatment or disposal) from the proposed activities which could impact wetlands.
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3. Shore Birds and Coastal Nesting Birds

Accidents: Oil spills could cause impacts to shore birds and coastal nesting birds. However, it is 

unlikely that an oil spill would occur from the proposed activities (refer to Item 5, Water Quality). 

Given the distance from shore (77 miles) and the response capabilities that would be implemented, no 

impacts are expected. The activities proposed in this plan will be covered by PAI’s Regional OSRP 

(refer to information submitted in Appendix H). 

Discarded trash and debris: Coastal and marine birds are highly susceptible to entanglement in 

floating, submerged, and beached marine debris: specifically plastics. Operators are prohibited from 

deliberately discharging debris as mandated by MARPOL-Annex V and the Marine Plastic Pollution 

Research and Control Act, and regulations imposed by various agencies including the United States 

Coast Guard (USCG) and the Environmental Protection Agency (EPA). PAI will operate in 

accordance with the regulations and also avoid accidental loss of solid waste items by maintaining 

waste management plans, manifesting trash sent to shore, and using special precautions such as 

covering outside trash bins to prevent accidental loss of solid waste. Special caution will be exercised 

when handling and disposing of small items and packaging materials, particularly those made of nonbiodegradable, environmentally persistent materials such as plastic or glass.

Informational placards will be posted on vessels and every facility that has sleeping or food 

preparation capabilities. All offshore personnel, including contractors and other support servicesrelated personnel (e.g. helicopter pilots, vessel captains and boat crews) will be indoctrinated on waste 

procedures, and will view the video (or Microsoft PowerPoint presentation), “Think About It” 

(previously “All Washed Up: The Beach Litter Problem”). Thereafter, all personnel will view the 

marine trash and debris training video annually. Offshore personnel will also receive an explanation 

from PAI management or the designated lease operator management that emphasizes their 

commitment to waste management in accordance with NTL No. 2012-G01.

There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes sent to 

shore for treatment or disposal) from the proposed activities that could cause impacts to shore birds 

and coastal nesting birds.

4. Coastal Wildlife Refuges

Accidents: An accidental oil spill from the proposed activities could cause impacts to coastal wildlife 

refuges. However, it is unlikely that an oil spill would occur from the proposed activities (refer to Item 

5, Water Quality). Due to the distance from shore (77 miles) and the response capabilities that would 

be implemented, no impacts are expected. The activities proposed in this plan will be covered by 

PAI’s Regional OSRP (refer to information submitted in Appendix H).

Discarded trash and debris: Operators are prohibited from deliberately discharging debris as 

mandated by MARPOL-Annex V, the Marine Plastic Pollution Research and Control Act and 

regulations imposed by various agencies including the United States Coast Guard (USCG) and the 

Environmental Protection Agency (EPA). PAI will operate in accordance with the regulations and also 

avoid accidental loss of solid waste items by maintaining waste management plans, manifesting trash 
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Mississippi Canyon Block 697 (OCS-G 34019)

sent to shore, and using special precautions such as covering outside trash bins to prevent accidental 

loss of solid waste. Special caution will be exercised when handling and disposing of small items and 

packaging materials, particularly those made of non-biodegradable, environmentally persistent 

materials such as plastic or glass.

Informational placards will be posted on vessels and every facility that has sleeping or food 

preparation capabilities. All offshore personnel, including contractors and other support servicesrelated personnel (e.g. helicopter pilots, vessel captains and boat crews) will be indoctrinated on waste 

procedures, and will view the video (or Microsoft PowerPoint presentation), “Think About It” 

(previously “All Washed Up: The Beach Litter Problem”). Thereafter, all personnel will view the 

marine trash and debris training video annually. Offshore personnel will also receive an explanation 

from PAI management or the designated lease operator management that emphasizes their 

commitment to waste management in accordance with NTL No. 2012-G01.

There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes sent to 

shore for treatment or disposal) from the proposed activities that could cause impacts to coastal 

wildlife refuges.

5. Wilderness Areas

Accidents: An accidental oil spill from the proposed activities could cause impacts to wilderness 

areas. However, it is unlikely that an oil spill would occur from the proposed activities (refer to Item 

5, Water Quality). Due to the distance from the nearest designated Wilderness Area (102 miles) and 

the response capabilities that would be implemented, no significant adverse impacts are expected. The 

activities proposed in this plan will be covered by PAI’s Regional OSRP (refer to information 

submitted in Appendix H).

Discarded trash and debris: Operators are prohibited from deliberately discharging debris as 

mandated by MARPOL-Annex V, the Marine Plastic Pollution Research and Control Act and 

regulations imposed by various agencies including the United States Coast Guard (USCG) and the 

Environmental Protection Agency (EPA). PAI will operate in accordance with the regulations and also 

avoid accidental loss of solid waste items by maintaining waste management plans, manifesting trash 

sent to shore, and using special precautions such as covering outside trash bins to prevent accidental 

loss of solid waste. Special caution will be exercised when handling and disposing of small items and 

packaging materials, particularly those made of non-biodegradable, environmentally persistent 

materials such as plastic or glass.

Informational placards will be posted on vessels and every facility that has sleeping or food 

preparation capabilities. All offshore personnel, including contractors and other support servicesrelated personnel (e.g. helicopter pilots, vessel captains and boat crews) will be indoctrinated on waste 

procedures, and will view the video (or Microsoft PowerPoint presentation), “Think About It” 

(previously “All Washed Up: The Beach Litter Problem”). Thereafter, all personnel will view the 

marine trash and debris training video annually. Offshore personnel will also receive an explanation 
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Mississippi Canyon Block 697 (OCS-G 34019)

from PAI management or the designated lease operator management that emphasizes their 

commitment to waste management in accordance with NTL No. 2012-G01.

There are no other IPFs (emissions, effluents, physical disturbances to the seafloor, or wastes sent to 

shore for treatment or disposal) from the proposed activities that could cause impacts to wilderness 

areas.

6. Other Environmental Resources Identified

There are no other environmental resources identified for this impact assessment.

(C) IMPACTS ON PROPOSED ACTIVITIES

The site–specific environmental conditions have been taken into account for the proposed activities. 

No impacts are expected on the proposed activities from site-specific environmental conditions.

(D) ENVIRONMENTAL HAZARDS

During the hurricane season, June through November, the Gulf of Mexico is impacted by an average of 

ten tropical storms (39-73 mph winds), of which six become hurricanes ( > 74 mph winds). Due to its 

location in the gulf, Mississippi Canyon Block 697 may experience hurricane and tropical storm force 

winds, and related sea currents. These factors can adversely impact the integrity of the operations

covered by this plan. A significant storm may present physical hazards to operators and vessels, 

damage exploration or production equipment, or result in the release of hazardous materials (including 

hydrocarbons). Additionally, the displacement of equipment may disrupt the local benthic habitat and 

pose a threat to local species.

The following preventative measures included in this plan may be implemented to mitigate these 

impacts:

1. Drilling & completion

a. Secure well

b. Secure rig / platform

c. Evacuate personnel

Drilling activities will be conducted in accordance with NTL No.’s 2008-G09, 2009-G10, and 2010-

N10.

2. Structure Installation

Operator will not conduct structure installation operations during Tropical Storm or 

Hurricane threat.

(E) ALTERNATIVES

No alternatives to the proposed activities were considered to reduce environmental impacts.
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(F) MITIGATION MEASURES

No mitigation measures other than those required by regulation will be employed to avoid, diminish, or 

eliminate potential impacts on environmental resources. 

(G) CONSULTATION

No agencies or persons were consulted regarding potential impacts associated with the proposed 

activities. Therefore, a list of such entities has not been provided. 

(H) PREPARER(S)

Jami Christley

J. Connor Consulting, Inc.

16225 Park Ten Place, Suite 700

Houston, TX 77084

(281) 578-3388

jami.christley@jccteam.com

(I) REFERENCES

Authors: 

American Petroleum Institute (API). 1989. Effects of offshore petroleum operations on cold water 

marine mammals: a literature review. Washington, DC: American Petroleum Institute. 385 pp.

Balazs, G.H. 1985. Impact of ocean debris on marine turtles: entanglement and ingestion. In: Shomura, 

R.S. and H.O. Yoshida, eds. Proceedings, Workshop on the Fate and Impact of Marine Debris, 26-

29 November 1984, Honolulu, HI. U.S. Dept. of Commerce. NOAA Tech. Memo. NOAA-TMNMFS-SWFC-54. Pp 387-429.

Burke, C.J. and J.A. Veil. 1995. Potential benefits from regulatory consideration of synthetic drilling 

muds. Environmental Assessment Division, Argonne National Laboratory, ANL/EAD/TM-43.

Daly, J.M. 1997. Controlling the discharge of synthetic-based drilling fluid contaminated cuttings in 

waters of the United States. U.S. Environmental Protection Agency, Office of Water. Work Plan, 

June 24, 1997.

Hansen, D.J. 198l. The relative sensitivity of seabird populations in Alaska to oil pollution. U.S. Dept. 

of the Interior, Bureau of Land Management, Alaska OCS Region, Anchorage. BLM-YK-ES-81-

006-1792.

Laist, D.W. 1997. Impacts of marine debris: entanglement of marine life in marine debris including a 

comprehensive list of species with entanglement and ingestion records. In: Coe, J.M. and D.B. 
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Initial Exploration Plan December 2012

Mississippi Canyon Block 697 (OCS-G 34019)

Rogers, eds. Marine debris: sources, impacts, and solutions. New York, NY: Springer-Verlag. Pp. 

99-139.

Majors, A.P. and A.C. Myrick, Jr. 1990. Effects of noise on animals: implications for dolphins exposed 

to seal bombs in the eastern tropical Pacific purse-seine fishery–an annotated bibliography. NOAA 

Administrative Report LJ-90-06.

Marine Mammal Commission. 1999. Annual report to Congress – 1998.

Piatt, J.F., C.J. Lensink, W. Butler, M. Kendziorek, and D.R. Nysewander. 1990. Immediate impact 

of the Exxon Valdez oil spill on marine birds. The Auk. 107 (2): 387-397

Vauk , G., E. Hartwig, B. Reineking, and E. Vauk-Hentzelt. 1989. Losses of seabirds by oil pollution 

at the German North Sea coast. Topics in Marine Biology. Ros, J.D, ed. Scient. Mar. 53 (2-

3): 749-754.

Vermeer, K. and R. Vermeer, 1975 Oil threat to birds on the Canadian west coast. The Canadian 

Field-Naturalist. 89:278-298.

Although not cited, the following were utilized in preparing this EIA:

• Hazard Surveys

• BOEM EIS’s:

o GOM Deepwater Operations and Activities. Environmental Assessment. BOEM 2000-001 

o GOM Central and Western Planning Areas Sales 166 and 168 Final Environmental Impact 

Statement. BOEM 96-0058.
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APPENDIX P

ADMINISTRATIVE INFORMATION

(A) EXEMPTED INFORMATION DESCRIPTION

The proposed bottom-hole locations of the planned well have been removed from the public 

information copy of the EP as well as any discussions of the target objectives, geologic or geophysical 

data, and any interpreted geology.

(B) BIBLIOGRAPHY

Not applicable.