UNITED STATES GOVERNMENT MEMORANDUM

To: Public Information (MS 5030)

Plans Section, Office of Field Operations (MS 5231)

Public Information copy of DOCD

Control # - S-07679

Type - Supplemental Development Operations Coordinations Document

Lease(s) - OCS-G08010 Block - 298 Green Canyon Area

Operator - Eni US Operating Co. Inc.

Drill & Complete Well No. SS 007

Drillship, DP Semisubmersible

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.

Tonya Jez

Plan Coordinator

G08010/GC/298
G08010/GC/298 1776 FSL, 2469 FWL

1776 FSL, 2469 FWL G08010/GC/298
G08010/GC/298 WELL/007
WELL/SS007 Botm Lse/Area/Blk Surface Location Surf Lse/Area/Blk Site Type/Name Description -

Rig Type - Subject: From: January 8, 2015

# SUPPLEMENTAL

DEVELOPMENT OPERATIONS

COORDINATION DOCUMENT

GREEN CANYON BLOCK 298

LEASE OCS-G 08010

PUBLIC INFORMATION COPY

Submitted by:

eni us operating co. inc.

### ENI US OPERATING CO. INC.

SUPPLEMENTAL

DEVELOPMENT OPERATIONS COORDINATON DOCUMENT

LEASE OCS-G 08010

GREEN CANYON BLOCK 298

SECTION A Plan Contents

SECTION B General Information

SECTION C Geological, Geophysical Information

SECTION D H2S Information

SECTION E Mineral Resources Conservation Information

SECTION F Biological, Physical and Socioeconomic Information

SECTION G Wastes and Discharge Information

SECTION H Air Emissions Information

SECTION I Oil Spill Information

SECTION J Environmental Monitoring Information

SECTION K Lease Stipulations Information

SECTION L Environmental Mitigation Measures Information

SECTION M Related Facilities and Operations Information

SECTION N Support Vessels and Aircraft Information

SECTION O Onshore Support Facilities Information

SECTION P Coastal Zone Management Act (CZMA) Information

SECTION Q Environmental Impact Analysis

SECTION R Administrative InformationEni US Operating Co. Inc. P age 1

Supplemental DOCD May 19, 2014 Green Canyon Block 298 (OCS-G 08010) Public Information 

### SECTION A

P LAN CONTENTS

(a) Plan Information Form This Supplemental Development Operations Coordination Document (S-DOCD) provides for the drilling, completion, installation of lease term pipelines, jumpers, associated umbilical’s, and commencement of production from Lease OCS-G 08010, Well No. 007 (to be renamed SS007).

Eni is planning to further develop the Allegheny Field located in the Green Canyon Block 254 by adding production from an additional well (Well No. 007 {to be renamed SS007}) in Green Canyon Block 298.Well No. 007, to be renamed SS007, is expected to spud on or about November 15,2014.

Eni recently drilled, completed and is currently producing Lease OCS-G 08010, Green Canyon Block 298, SS006 (ST01BP01) as of September 16, 2012. Other wells located in the vicinity and are currently producing consist of Lease OCS-G 08010, Well No.’s 001 (ST03BP01), SS005 (ST00BP05), 004
(ST04BP01).

See attached OCS Plan Information Form – Form BOEM-137, included under this section showing the activity schedule.

(b) Location A Well Location Map showing the proposed surface and bottom-hole location of the proposed well is included in this plan along with a Bathymetry Map showing the water depths across the lease block.

The pipeline, jumpers and associated umbilical will be installed using a dynamically positioned installation vessel; therefore no anchors will be associated with these development activities.

(c) Safety and Pollution Prevention Features Eni will use a dynamically positioned rig or similar with subsea BOP’s, and will comply with all of the regulations of the ABS, IMO and USCG. All drilling operations will be conducted under the provisions of 30 CFR, Part 250, Subpart D, and other applicable regulations and notice to lessees, including those regarding the avoidance of potential drilling hazards and safety and pollution prevention control. Such measures as inflow detection and well control, monitoring for loss of circulation and seepage loss, and casing design will be our primary safety measures.

Pollution prevention measures include installation of curbs, gutters, drip pans, and drains on drilling deck areas to collect all contaminants and debris. All discharges will be in accordance with applicable EPA NPDES permits.

(d) Storage Tanks and/or Production Vessels

Type of

S torage Tank Type of Facility Tank Capacity (bbls) Number

of Tanks Total

Capacity (bbls) Fluid Gravity

(API)

Fuel Oil (Marine Diesel) DP Drillship 901 4 3604 0.35

Fuel Oil (Marine Diesel) DP Drillship 19,386.8 2 38,773.6 0.35

Fuel Oil (Marine Diesel) DP Drillship 988 2 1976 0.35Eni US Operating Co. Inc. Page 2

Supplemental DOCD May 19, 2014 Green Canyon Block 298 (OCS-G 08010) Public Information Type of Storage Tank Type of Facility Tank Capacity

(bbls) Number

of Tanks Total

Capacity (bbls) Fluid

Gravity (API)
Fuel Oil (Marine
Diesel) DP Drillship 4,400 1 4,400 0.35

Fuel Oil (Marine Diesel) DP Drillship 1.26 4 5.04 0.35

Fuel Oil (Marine
Diesel) DP Drillship 1.58 1 1.58 0.35

Fuel Oil (Marine
Diesel) DP Drillship 4.76 1 4.76 0.35

Fuel Oil (Marine
Diesel) DP Drillship 225 2 450 0.35

Liquid Mud DP Drillship 51.3 1 51.3

--

Drill Water DP Drillship 559 1 559

--

Potable Water DP Drillship 199.6 1 199.6

--

Type of Storage Tank Type of Facility Tank Capacity

(bbls) Number

of Tanks Total

Capacity (bbls) Fluid

Gravity (API)

Fuel Oil (Marine
Diesel) DP Semi 16,700 1 16,700 36°

Active Mud Pits DP Semi 4,500 1 4,500 NA

Reserve Liquid Mud Storage DP Semi 11,750 1 11,750 NA

Drill Water DP Semi 14,000 1 14,000 NA

Potable Water DP Semi 1,570 1 1,570 NA

(e) Processing Fee A Pay.gov receipt is being included in this plan in the amount of $4,238.00 to cover the cost and processing fee for the proposed operations being conducted under this plan

(f) Pollution Prevention Measures

Pursuant to NTL 2008-G04 the proposed operations covered by this DOCD do not require Eni to specifically address the discharges of oils and greases from the rig during rainfall or routine operations. Nevertheless, Eni has provided this information as part of its response to (c) above.

(g) Additional Measures Health, safety, and environment are the primary topics in pre-tour and pre-job safety meetings. The discussion around no harm to people or environment is a key mindset. All personnel are reminded daily to inspect work areas for safety issues as well as potential pollution issues.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

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

### 2

7 GENERAL INFORMATION

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

Company Name: Eni US Operating Co. Inc. Operator Number: 02782

Address: 1200 Smith Street, Suite 1700 Contact Person: Brenda Montalvo

Houston, Texas 77002 Phone Number: (713) 393-6259

If a service fee is required under 30 CFR 550.125(a) provide the Amount paid $4,238.00 Receipt No. 24FQ46KL

Project and Worst Case Discharge (WCD) Information

Lease: G08010 Area: GC Block: 298 Project Name (If Applicable): Allegheny South

Objective(s): Oil Gas Sulphur Salt Onshore Support Base(s): Fourchon, LA

Platform/Well Name: 007 (SS007) Total Volume of WCD: 147,099 BOPD API Gravity: 43°

Distance to Closest Land (Miles): 94 Volume from uncontrolled blowout: 14.7 BOPD

Have you previously provided information to verify the calculations and assumptions for your WCD? Yes X No

If so, provide the Control number of the EP or DOCD with which this information was provided

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

Do you propose to use a vessel with anchors to install or modify a structure? Yes X No

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

Description of Proposed Activities Scheduled (Mark all that apply)

Proposed Activity Start Date End Date No. of Days Development drilling 02/01/2015 03/02/2015 30 Well completion 03/03/2015 04/01/2015 30

Installation of subsea wellheads and/or manifolds 04/02/2015 04/03/2015 2 Installation of lease term pipeline and umbilical 04/04/2015 04/05/2015 9 Commence production 04/10/2015

Description of Drilling Rig Description of Structure

Jackup X Drillship Caisson X Tension leg platform Gorilla Jackup Platform rig Fixed platform Compliant tower

Semisubmersible Submersible Spar Guyed Tower

X DP Semisubmersible Other (Attach Description) Floating Production System Other (Attach Description)

Drilling Rig Name (If Known):

Description of Lease Term Pipelines

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

Well No. 007 GC298 Existing South REM GC298 (lease pipeline) 6 12330 Platform A (Allegheny) GC254 Well No. 007, GC298 (umbilical) 4 17154U.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
Include one copy of this page for each proposed well/structure

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

### 2

7 Proposed Well/Structure Location

Well or Structure Name/Number (If renaming well or structure, reference previous name): Well No. 007 to be

renamed SS007 Previously reviewed under an approved EP or DOCD? YES X NO

Is this an existing well

or structure? YES X NO If this is an existing well or structure, list the Complex ID or

API No.

Do you plan to use a subsea BOP or surface BOP on a floating facility to conduct your proposed activities? X YES NO

WCD info For wells, volume of uncontrolled

blowout (Bbls/day): 14.7 BOPD F or structures, volume of all storage and pipelines (Bbls): API Gravity of fluid: 43

Surface Location Bottom-Hole Location (For Wells) Completion (For multiple completions, enter separate lines)

Lease No. OCS-G 08010

Area Name Green Canyon

Block No. 298

Blockline Departures (in feet) 1,776’ FSL

2,469’ FWL

Lambert X-Y

Coordinates X: 2,521,029’

Y: 10,044,336’

Latitude/ Longitude Latitude 27  ̊ 39’ 09.71” N

Longitude 90  ̊ 16’ 45.87” W

Water Depth (Feet): 3,400’

Anchor Radius (if applicable) in 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 or SeafloorEni US Operating Co. Inc. Page 3

Supplemental DOCD May 19, 2014 Green Canyon Block 298 (OCS-G 08010) Public Information 

### SECTION B

GENERAL INFORMATION

(a) Applications and Permits No additional applications or permits from other agencies are required at this time to be submitted and approved other than an Application for Permit to Drill (APD) to the appropriate BSEE District.

(b) Drilling Fluids Drilling fluids to be used for this well are described in Table 1 under Section F of this plan.

(c) Production Proprietary Information

(d) Oil Characteristics Proprietary Information

(e) New or Unusual Technology

Eni does not propose to use any new or unusual technolog y to carry out the proposed development

activities.

(f) Bonding Statement The bond requirements for the activities and facilities proposed in this DOCD are satisfied by areawide development bond, furnished and maintained according to 30 CFR 2 56, subpart I; NTL No. 2000-G16, "Guidelines for General Lease Surety Bonds;" and additional security under 30 CFR 256.53(d) and National NTL No. 2008-N07, “Supplemental Bond Procedures.”

(g) Oil Spill Financial Responsibility In accordance with 30 CFR 253; and NTL 2008-N05, “Guidelines for Oil Spill Financial Responsibility for Covered Facilities”, Eni US Operating Co. Inc., BOEM company number 02782, maintains coverage for the activities proposed under this DOCD.



### ( h) Deepwater Well Control Statement Eni US Operating Co. Inc., BOEM company number 02782, has the financial capability to drill a relief well and conduct other emergency well control operations

(i) Suspensions of Production Lease OCS-G 08010 is held by Unit Agreement No. 754395015 approved, effective 6/1/95. The unit agreement consists of OCS-G07049, G08010 and G08876.



### (j) Blowout Scenario Should a blow-out occur, the formation types in this area do not tend to bridge over of their own accord. Eni will use sub-surface BOPs with accumulator bottles attached to the BOP skid package. Sufficient accumulator bottles to activate the BOPs are located on the BOP skid package. The control lines are fed from the rig to the sub-surface control system which activates the BOP. Two activation systems exist to allow rig floor activation or remote activation of the BOPs. Remote Operated Vehicle (ROV) activation is also built into the BOPs. In addition, a “deadman” switch exists in case of a rig “drift off” or loss of rig positioning. This system will activate the BOP and release the LMRP allowing the rig to float free to protect the well and well control systemsEni US Operating Co. Inc. Page 4

Supplemental DOCD May 19, 2014 Green Canyon Block 298 (OCS-G 08010) Public Information I f the BOP and wellhead remain intact but do not close upon activation from the rig, ROVs located either on the rig or a stand-by boat shall be launched to attempt to close the BOPs by pumping into the secondary intervention devices located on the BOP within twelve (12) hours, unless the area is deemed unsafe. Once the area is deemed safe to enter, ships will launch ROVs to perform the intervention actions. If the ROV intervention is successful, Eni would return the rig, if undamaged, to the location and begin re-attachment and procedures to control the well once the BOPs are opened.

The present calculated release from the wellbore is 147,099 Bbls of oil per day and 1137 MM cubic feet of gas per day. If a relief well to kill the original well was required; it would be expected to take 100 days to complete kill of the original well.

An approximate breakdown of this time using only DP rigs would include:

Time of obtain rig, rig to temporarily abandon well they are presently on, and move to location of blowout: 10 days

Drill to depth 60 days Drill to intersect point 20 days Drill Intersection 7 days Kill with downhole kill procedure 3 days

Flow Rate per Day Duration of Blowout Total Volumes
Oil – 147,099 BOPD 100 Days 14,709,900 BBL Gas – 1137 MMCF per day 100 Days 113,700 MMCF

Therefore a total release if the well did not bridge over would be 14.7 million barrels of oil and 113.7 Bcf of gas. The closest structure to the location is the Eni US Operating Co. Inc. Allegheny MTLP approximately 5 miles from well center. Use of the MTLP to drill a relief well would not be feasible due to distance from the well to the TLP. Eni would use only Dynamically Positioned (DP) rigs for the relief well operations. Eni would use two (2) to possibly three (3) rigs to ensure the blow-out well could be brought under control even if one relief well encountered problems while drilling.

Eni follows the BSEE schedule for BOP tests and expects and demands that BOPs are kept functional by the contractors. Eni will shut down operations for any repairs needed on well control devices anytime they are not considered functional and safe. Eni uses Company Representatives with many years of experience in drilling operations. The Company Representatives constantly communicate with the OIM on the rig to ensure the safety of all personnel and equipment. All Company representatives are trained in

well control and maintain Well Control Certificates.

Eni uses multiple liners to cover potential production zones to reduce the risk of loss of well integrity.

Eni foresees no restrictions for DP rigs to work in the area to perform well intervention and control. Eni would review and hire DP rigs for relief well operations to prevent usage of mooring systems therefore saving time to bring the well under control. If the original well bore is considered un-usable; Eni would drill from some distance to prevent either oil or gas from the damaged well from affecting the intervention activities. Flammable meters on the intervention rigs would be supplemented with additional detectors on the rig to ensure protection of personnel and equipment. If detectors registered high levels of LELs, the rigs would be shut down during that time to protect personnel and the equipment.Eni US Operating Co. Inc. Page 5

Supplemental DOCD May 19, 2014 Green Canyon Block 298 (OCS-G 08010) Public Information E ni maintains additional materials on board the rig in order to “weight-up” the mud system to control any upsets or well control issues. Mud pits are monitored constantly by personnel when operations are ongoing. In addition, automatic alarms are located in the pits and will sound if pits receive abnormal amounts of return fluids to alert of possible flow control problems. Personnel on the rig floor are trained to monitor the systems and respond immediately if a problem is noted or if alarms sound and will take all necessary steps including operating the BOPs to maintain control of the well.Eni US Operating Co. Inc. Page 6

Supplemental DOCD May 19, 2014 Green Canyon Block 298 (OCS-G 08010) Public Information 

### SECTION C

GEOLOGICAL AND GEOPHYSICAL INFORMATION

(e) Shallow Hazards Report A survey was conducted over Green Canyon Block 298. Copies of the report are being submitted with this plan under separate cover.

(f) Shallow Hazards Assessment A shallow hazards assessment has been prepared for the proposed surface location, evaluating seafloor and subsurface geological and manmade features and conditions that may adversely affect drilling operations, and is included as with this plan.



### Attachments
1) Site Clearance LetterEni US Operating Co. Inc. P age 

### 7

S upplemental DOCD May 19, 2014 Green Canyon Block 298 (OCS-G 08010) Public Information 

### SECTION D

H YDROGEN SULFIDE INFORMATION

(a) Concentration Eni does not anticipate encountering any H 2 S during the proposed operations.

( b) Classification In accordance with Title 30 CFR 250.490(c), Eni requests that Green Canyon Block 298 be classified by

BOEM as H 2 S absent.

( c) H2S Contingency Plan Eni does not anticipate encountering H2S while conducting the proposed development activities; however

in the event it is encountered, Eni will submit to the appropriate BSEE district office an H 2 S Contingency

P lan prepared according to 30 CFR 250.490(f) before conducting the proposed exploration activities.

(d) Modeling Report Not applicable

### Eni US Operating Co. Inc. Page 8

Supplemental DOCD May 19, 2014 

### Green Canyon Block 298 (OCS-G 08010) Public Information 

### SECTION E

MINERAL RESOURCE CONSERVATION INFORMATION

(a) Technology & Reservoir Engineering Practices and Procedures The reservoir will be initially produced by natural energy (aquifer and rock compaction). We may consider gas lift in the late life if we need more energy to enhance recovery.

(b) Technology and Recovery Practices and Procedures Detail Petrel and Eclipse model has been completed and these tools will be used to ensure maximum recovery from the reservoir.

(c) Reservoir Development Proprietary InformationEni US Operating Co. Inc. Page 9

Supplemental DOCD May 19, 2014 Green Canyon Block 298 (OCS-G 08010) Public Information 

### SECTION F BIOLOGICAL, PHYSICAL AND SOCIOECONOMIC INFORMATION

(a) High-Density Deepwater Benthic Communities Information Activities proposed in this plan will disturb seafloor areas in water depths greater the 300 meters (984 feet), therefore, a report as described in Attachment A of NTL No. 2009-G40 "Deepwater Benthic Communities" has been conducted 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 assessment enclosed in Section C of this DOCD address a radius of 2,000 ft around the proposed surface location. Eni proposed to drill the well with a dynamically positioned rig, therefore no anchors will be deployed, and surface impacts will be restricted to the seafloor in the immediate vicinity of the

borehole.

(b) Topographic Features Map Activities proposed in this DOCD do not fall within 305 meters (1000 feet) of a topographic “no activity

zone”.

(c) Topographic Features Statement All activities proposed under this DOCD 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 Green Canyon Block 298 is not located within 61 meters (200 feet) of any live-bottom (pinnacle trend)

features.

(e) Live Bottoms (Low Relief) Map Green Canyon Block 298 is not located within 100 feet of any live-bottom (low-relief) features.

(f) Potentially Sensitive Biological Features Green Canyon Block 298 is not located within 30 meters (100 feet) of potentially sensitive biological

features.

(g) Remotely Operated Vehicle (ROV) Surveys Eni is familiar with the ROV Survey and reporting provisions of NTL 2008-G06

. Green Canyon Block 298 is located in Grid 13 in the Grid EA and ROV Status Report. The report indicates that Grid 13 has Adequate ROV survey coverage, therefore Eni is not required to submit a plan for an ROV monitoring survey per NTL 2008-G04.

(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 the 30 CFR 550, Subpart B, and further outlined in Notice to Lessees (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.Eni US Operating Co. Inc. Page 10

Supplemental DOCD May 19, 2014 Green Canyon Block 298 (OCS-G 08010) Public Information N OAA Fisheries currently lists the Sperm Whale, Leatherback Turtle, Green Turtle, Hawksbill Turtle, and the Kemp’s Ridley Turtle as endangered and the Loggerhead Turtle and Gulf Sturgeon as threatened. 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 The proposed drilling location lies within an area designated as archaeologically sensitive by BOEM as set forth in Notice to Lessees 2005-G07 and 2008-G05 (BOEM, 2005 and 2008). Tesla Offshore, LLC surveyed all of Block 298, with extended survey coverage into Blocks 253, 254, 297, 341, and 342, Green Canyon Area. The survey was conducted between August and October, 2005 along a 300 meter grid. The resulting archaeological assessment report was submitted to Eni under Tesla Job No. 05-353-11; this original assessment was prepared prior to the requirement for archaeological assessments in deepwater, therefore NTL-compliant, revised report was prepared and submitted to Eni under Tesla Job No. 14-021- 11. Eni contacted Tesla Offshore, LLC to provide this archaeological analysis (NTL No. 2005-G07) in accordance with the Bureau of Ocean Energy Management (BOEM) Gulf Of Mexico OCS Region.

(j) Air and Water Quality Information Pursuant to NTL 2008-G04 the proposed operations covered by this DOCD do not require Eni to provide additional information relating to air and water quality information.

(k) Socioeconomic Information Pursuant to NTL 2008-G04 the proposed operations covered by this DOCD do not require Eni to provide additional information relating to socioeconomic.Eni US Operating Co. Inc. Page 

### 11

Supplemental DOCD May 19, 2014 Green Canyon Block 298 (OCS-G 08010) Public Information 

### SECTION G

WASTES AND DISCHARGES INFORMATION

Projected Generated Wastes and Projected Ocean

TABLE 1.
WASTES YOU WILL GENERATE, TREAT AND DOWNHOLE DISPOSE OR DISCHARGE TO THE

GOM

(c) Modeling Report Not required by EPA under the OCS General Permit.Eni US Operating Co. Inc.Page12Supplemental DOCDMay 19, 2014Green Canyon Block 298 (OCS-G 08010)Public InformationEni US Operating Co. Inc. Page 13

Supplemental DOCD May 19, 2014 Green Canyon Block 298 (OCS-G 08010) Public Information 

### SECTION H

AIR EMISSIONS INFORMATION

(a) Emissions Worksheets and Screening Questions 

### (2) Screening Questions

Screen Procedures for DOCD’s Yes No Is any calculated Complex Total (CT) Emission amount (tons) associated with your proposed development activities more than 90% of the amounts calculated using the following formulas: CT = 3400D 2/3 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

Does or will the facility complex associated with your proposed development and production activities process production from eight or more wells? X

Do you expect to encounter H 2 S at concentrations greater than 20 parts per million (ppm)? X Do you propose to flare or vent natural gas in excess or criteria set for the under 250.1105(a)(2) and (3)? X

Do you propose to burn produced hydrocarbon liquids? X Are your proposed development and production activities located within 25 miles (40
kilometers) from shore? X

Are your proposed development and production activities located within 124 miles (200
kilometers) of the Breton Wilderness Area? X

This information was calculated by: Brenda Montalvo (713) 393-6259 brenda.montalvo@enipetroleum.comDOCD AIR QUALITY SCREENING CHECKLISTOMB Control No. 1010-0151OMB Approval Expires: 12/31/2011(under renewal at OMB)COMPANYEni US Operating Co. Inc.AREAGreen CanyonBLOCK298LEASEG08010PLATFORMWELL007 (to be renamed SS007)COMPANY CONTACTBrenda MontalvoTELEPHONE NO.(713) 393-6259REMARKSDrill, complete, and install lease term pipeline, jumpers, associated umbilical,and commencement of production from Lease G 08010, Well No. 007 (to berenamed SS007) using aDP SemiLEASE TERM PIPELINE CONSTRUCTION INFORMATION:YEAR NUMBER OFTOTAL NUMBER OF CONSTRUCTION DAYSPIPELINES20142015 2920162017201820192020202120222023FORM BOEM-0139(October 2011- Supersedes all previous versions of form BOEM-0139 which may not be used).AIR EMISSIONS CUMPUTATION FACTORSFuel Usage Conversion FactorsNatural Gas Turbines Natural Gas Engines Diesel Recip. Engine REF. DATESCF/hp-hr 9.524 SCF/hp-hr 7.143 GAL/hp-hr 0.0483AP42 3.2-1 4/76 & 8/84Equipment/Emission Factorsunits PM SOx NOx VOC CO REF. DATENG Turbinesgms/hp-hr0.00247 1.3 0.01 0.83AP42 3.2-1& 3.1-1 10/96NG 2-cycle leangms/hp-hr0.00185 10.9 0.43 1.5AP42 3.2-1 10/96NG 4-cycle leangms/hp-hr0.00185 11.8 0.72 1.6AP42 3.2-1 10/96NG 4-cycle richgms/hp-hr0.00185 10 0.14 8.6AP42 3.2-1 10/96Diesel Recip. < 600 hp.gms/hp-hr 1 1.468 14 1.12 3.03AP42 3.3-1 10/96Diesel Recip. > 600 hp.gms/hp-hr 0.32 1.468 11 0.33 2.4AP42 3.4-1 10/96Diesel Boilerlbs/bbl 0.084 2.42 0.84 0.008 0.21AP42 1.3-12,14 9/98NG Heaters/Boilers/Burners lbs/mmscf 7.6 0.593 100 5.5 84AP42 1.4-1, 14-2, & 14-37/98NG Flareslbs/mmscf0.593 71.4 60.3 388.5AP42 11.5-1 9/91Liquid Flaringlbs/bbl 0.42 6.83 2 0.01 0.21AP42 1.3-1 & 1.3-3 9/98Tank Vaporslbs/bbl0.03E&P Forum 1/93Fugitiveslbs/hr/comp.0.0005API Study 12/93Glycol Dehydrator Ventlbs/mmscf6.6La. DEQ1991Gas Ventinglbs/scf0.0034Sulphur Content Source Value UnitsFuel Gas3.33 ppmDiesel Fuel0.4 % weightProduced Gas( Flares) 3.33 ppmProduced Oil (Liquid Flaring)1% weightFORM BOEM-0139(October 2011 - Supersedes all previous versions of form BOEM-0139 which may not be used).Page 2AIR EMISSIONS CALCULATIONS - FIRST YEARCOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONE REMARKSEni US Operating Co. Inc. Green Canyon298 G08010007 (to be renamed SS007)Brenda Montalvo(713) 393-6259OPERATIONSEQUIPMENTRATING MAX. FUEL ACT. FUEL RUN TIMEMAXIMUM POUNDS PER HOURESTIMATED TONSDiesel EnginesHP GAL/HR GAL/DNat. Gas EnginesHP SCF/HR SCF/DBurnersMMBTU/HRSCF/HRSCF/DHR/DDAYSPMSOxNOxVOCCOPMSOxNOxVOCCODRILLINGPRIME MOVER>600hp diesel37478 1810.1874 43444.50 24 60 26.42 121.18 908.06 27.24 198.12 19.02 87.25 653.80 19.61 142.65DP SemiPRIME MOVER>600hp diesel00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel00 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew)2065 99.7395 2393.75 10 8 1.46 6.68 50.03 1.50 10.92 0.06 0.27 2.00 0.06 0.44VESSELS>600hp diesel(supply)2065 99.7395 2393.75 12 17 1.46 6.68 50.03 1.50 10.92 0.15 0.68 5.10 0.15 1.11VESSELS>600hp diesel(tugs)00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PIPELINEPIPELINE LAY BARGE diesel8800 425.04 10200.96 24 9 6.20 28.45 213.22 6.40 46.52 0.67 3.07 23.03 0.69 5.02INSTALLATION SUPPORT VESSEL diesel2065 99.7395 2393.75 24 9 1.46 6.68 50.03 1.50 10.92 0.16 0.72 5.40 0.16 1.18PIPELINE BURY BARGE diesel00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00SUPPORT VESSEL diesel00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00FACILITYDERRICK BARGE diesel00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew)00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply)00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRODUCTIONRECIP.<600hp diesel - North Crane(1)174 8.4042 201.70 24 365 0.38 0.56 5.37 0.43 1.16 1.68 2.46 23.50 1.88 5.09RECIP.<600hp diesel - South Crane(1)174 8.4042 201.70 24 365 0.38 0.56 5.37 0.43 1.16 1.68 2.46 23.50 1.88 5.09RECIP.<600hp diesel - Firewater Pump #1375 18.1125 434.70 24 365 0.83 1.21 11.56 0.93 2.50 3.62 5.31 50.65 4.05 10.96RECIP.<600hp diesel - Firewater Pump #2(1)375 18.1125 434.70 24 365 0.83 1.21 11.56 0.93 2.50 3.62 5.31 50.65 4.05 10.96RECIP.<600hp diesel - Auxiliary Generator(1)536 25.8888 621.33 24 365 1.18 1.73 16.53 1.32 3.58 5.17 7.59 72.40 5.79 15.67RECIP.<600hp diesel - Emergency Generator(1)280 13.524 324.58 24 365 0.62 0.91 8.63 0.69 1.87 2.70 3.97 37.82 3.03 8.19RECIP.<600hp diesel - Escape Capsule #1(1)36 1.7388 41.73 24 365 0.08 0.12 1.11 0.09 0.24 0.35 0.51 4.86 0.39 1.05RECIP.<600hp diesel - Escape Capsule #2(1)36 1.7388 41.73 24 365 0.08 0.12 1.11 0.09 0.24 0.35 0.51 4.86 0.39 1.05RECIP.<600hp diesel - Escape Capsule #3(1)36 1.7388 41.73 24 365 0.08 0.12 1.11 0.09 0.24 0.35 0.51 4.86 0.39 1.05RECIP.<600hp diesel - Auxiliary Air Compressor(1)75 3.6225 86.94 24 365 0.17 0.24 2.31 0.19 0.50 0.72 1.06 10.13 0.81 2.19RECIP.>600hp diesel - Turbine Diesel Generator #1(1)6130 296.079 7105.90 24 365 4.32 19.82 148.52 4.46 32.41 18.92 86.82 650.54 19.52 141.94RECIP.>600hp diesel - Turbine Diesel Generator #2(1)6130 296.079 7105.90 24 365 4.32 19.82 148.52 4.46 32.41 18.92 86.82 650.54 19.52 141.94SUPPORT VESSEL diesel(1)2400 115.92 2782.08 24 365 1.69 7.76 58.15 1.74 12.69 7.41 33.99 254.70 7.64 55.57TURBINE nat gas - HPC Turbine Compressor(1)10310 98192.44 2356618.56 24 365 7.27 0.06 29.52 0.23 18.85 31.83 0.25 129.31 0.99 82.56TURBINE nat gas - Turbine Natural Gas Generator #1(1)6130 58382.12 1401170.88 24 365 4.32 0.03 17.55 0.14 11.21 18.92 0.15 76.88 0.59 49.09TURBINE nat gas - Turbine Natural Gas Generator #2(1)6130 58382.12 1401170.88 24 365 4.32 0.03 17.55 0.14 11.21 18.92 0.15 76.88 0.59 49.09RECIP.4 cycle lean nat gas0 0 0.00 0 00.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.4 cycle rich nat gas00 0.00 0 00.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER nat gas0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC.BPD SCF/HR COUNTTANK- Dry Oil Storage Tank1000024 36512.5054.75TANK- Wet Oil Storage Tank1000024 3650.00 0.00 12.50 0.00 0.00 0.00 54.75 0.00FLARE-00 00.000.00PROCESS VENT-00.000.00FUGITIVES-11500.03655.750.00GLYCOL STILL VENT-00 00.000.00DRILLINGOIL BURN00 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE00 00.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002015 YEAR TOTAL67.85 223.98 1755.86 85.22 410.15 155.22 329.86 2811.41 201.69 731.87EXEMPTIONCALCULATIONDISTANCE FROM LAND IN MILES3130.203130.203130.203130.2070290.6494.0Drill, complete, and install lease term pipeline, jumpers, associated umbilical, and commencement ofproduction from Lease G 08010, Well No. 007 (to be renamed SS007) using a DP SemiFORM BOEM-0139(October 2011- Supersedes all previous versions of form BOEM-0139 which may not be used).Page 3AIR EMISSIONS CALCULATIONS - SECOND YEARCOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONE REMARKSEni US Operating Co. Inc.Green Canyon298 G08010007 (to be renamed SS007)Brenda Montalvo(713) 393-6259OPERATIONSEQUIPMENTRATINGMAX. FUELACT. FUELRUN TIMEMAXIMUM POUNDS PER HOURESTIMATED TONSDiesel EnginesHPGAL/HRGAL/DNat. Gas EnginesHPSCF/HRSCF/DBurnersMMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING PRIME MOVER>600hp diesel00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PIPELINE PIPELINE LAY BARGE diesel00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION SUPPORT VESSEL diesel00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PIPELINE BURY BARGE diesel00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00FACILITY DERRICK BARGE diesel00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew)00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply)00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRODUCTIONRECIP.<600hp diesel - North Crane(1)174 8.4042 201.70 24 365 0.38 0.56 5.37 0.43 1.16 1.68 2.46 23.50 1.88 5.09RECIP.<600hp diesel - South Crane(1)174 8.4042 201.70 24 365 0.38 0.56 5.37 0.43 1.16 1.68 2.46 23.50 1.88 5.09RECIP.<600hp diesel - Firewater Pump #1 375 18.1125 434.70 24 365 0.83 1.21 11.56 0.93 2.50 3.62 5.31 50.65 4.05 10.96RECIP.<600hp diesel - Firewater Pump #2(1)375 18.1125 434.70 24 365 0.83 1.21 11.56 0.93 2.50 3.62 5.31 50.65 4.05 10.96RECIP.<600hp diesel - Auxiliary Generator(1)536 25.8888 621.33 24 365 1.18 1.73 16.53 1.32 3.58 5.17 7.59 72.40 5.79 15.67RECIP.<600hp diesel - Emergency Generator(1)280 13.524 324.58 24 365 0.62 0.91 8.63 0.69 1.87 2.70 3.97 37.82 3.03 8.19RECIP.<600hp diesel - Escape Capsule #1(1)36 1.7388 41.73 24 365 0.08 0.12 1.11 0.09 0.24 0.35 0.51 4.86 0.39 1.05RECIP.<600hp diesel - Escape Capsule #2(1)36 1.7388 41.73 24 365 0.08 0.12 1.11 0.09 0.24 0.35 0.51 4.86 0.39 1.05RECIP.<600hp diesel - Escape Capsule #3(1)36 1.7388 41.73 24 365 0.08 0.12 1.11 0.09 0.24 0.35 0.51 4.86 0.39 1.05RECIP.<600hp diesel - Auxiliary Air Compressor(1)75 3.6225 86.94 24 365 0.17 0.24 2.31 0.19 0.50 0.72 1.06 10.13 0.81 2.19RECIP.>600hp diesel - Turbine Diesel Generator #1(1)6130 296.079 7105.90 24 365 4.32 19.82 148.52 4.46 32.41 18.92 86.82 650.54 19.52 141.94RECIP.>600hp diesel - Turbine Diesel Generator #2(1)6130 296.079 7105.90 24 365 4.32 19.82 148.52 4.46 32.41 18.92 86.82 650.54 19.52 141.94SUPPORT VESSEL diesel(1)2400 115.92 2782.08 24 365 1.69 7.76 58.15 1.74 12.69 7.41 33.99 254.70 7.64 55.57TURBINE nat gas - HPC Turbine Compressor(1)10310 98192.44 2356618.56 24 365 7.27 0.06 29.52 0.23 18.85 31.83 0.25 129.31 0.99 82.56TURBINE nat gas - Turbine Natural Gas Generator #1(1)6130 58382.12 1401170.88 24 365 4.32 0.03 17.55 0.14 11.21 18.92 0.15 76.88 0.59 49.09TURBINE nat gas - Turbine Natural Gas Generator #2(1)6130 58382.12 1401170.88 24 365 4.32 0.03 17.55 0.14 11.21 18.92 0.15 76.88 0.59 49.09RECIP.4 cycle lean nat gas00 0.00 000.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.4 cycle rich nat gas00 0.00 000.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER nat gas0 0.00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC.BPDSCF/HRCOUNTTANK- Dry Oil Storage Tank1000024 36512.5054.75TANK- Wet Oil Storage Tank1000024 3650.00 0.00 12.50 0.00 0.00 0.00 54.75 0.00FLARE-0000.000.00PROCESS VENT-000FUGITIVES-11500.03655.7525.19GLYCOL STILL VENT-0000.000.00DRILLING OIL BURN000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE0000.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002016YEAR TOTAL30.8654.31484.4947.08132.76135.17237.862122.07206.19581.47EXEMPTIONCALCULATIONDISTANCE FROM LAND IN MILES3130.20 3130.20 3130.20 3130.20 70290.6494.0Drill, complete, and install lease term pipeline, jumpers, associated umbilical, and commencementof production from Lease G 08010, Well No. 007 (to be renamed SS007) using a DP SemiFORM BOEM-0139October 2011 - Supersedes all previous versions of form BOEM-0139 which may not be used).Page 4AIR EMISSIONS CALCULATIONSCOMPANYAREABLOCKLEASEPLATFORM WELLEni US Operating Co. Inc. Green Canyon 298G08010007 (to be renamed SS007)EmittedSubstanceYearPMSOxNOxVOCCO2015155.22329.86 2811.41 201.69731.872016135.17237.86 2122.07 206.19581.47Allowable0.003130.20 3130.20 3130.2070290.64FORM BOEM-0139(October 2011 - Supersedes all previous versions of form BOEM-0139 which may not be used).Page 5DOCD AIR QUALITY SCREENING CHECKLISTOMB Control No. 1010-0151OMB Approval Expires: 12/31/2011(under renewal at OMB)COMPANYEni US Operating Co. Inc.AREAGreen CanyonBLOCK298LEASEG08010PLATFORMWELL007 (to be renamed SS007)COMPANY CONTACTBrenda MontalvoTELEPHONE NO.(713) 393-6259REMARKSDrill, complete, and install lease term pipeline, jumpers, associated umbilical,and commencement of production from Lease G 08010, Well No. 007 (to berenamed SS007) using aDrillshipLEASE TERM PIPELINE CONSTRUCTION INFORMATION:YEAR NUMBER OFTOTAL NUMBER OF CONSTRUCTION DAYSPIPELINES20142015 2920162017201820192020202120222023FORM BOEM-0139(October 2011- Supersedes all previous versions of form BOEM-0139 which may not be used).AIR EMISSIONS CUMPUTATION FACTORSFuel Usage Conversion FactorsNatural Gas Turbines Natural Gas Engines Diesel Recip. Engine REF. DATESCF/hp-hr 9.524 SCF/hp-hr 7.143 GAL/hp-hr 0.0483AP42 3.2-1 4/76 & 8/84Equipment/Emission Factorsunits PM SOx NOx VOC CO REF. DATENG Turbinesgms/hp-hr0.00247 1.3 0.01 0.83AP42 3.2-1& 3.1-1 10/96NG 2-cycle leangms/hp-hr0.00185 10.9 0.43 1.5AP42 3.2-1 10/96NG 4-cycle leangms/hp-hr0.00185 11.8 0.72 1.6AP42 3.2-1 10/96NG 4-cycle richgms/hp-hr0.00185 10 0.14 8.6AP42 3.2-1 10/96Diesel Recip. < 600 hp.gms/hp-hr 1 1.468 14 1.12 3.03AP42 3.3-1 10/96Diesel Recip. > 600 hp.gms/hp-hr 0.32 1.468 11 0.33 2.4AP42 3.4-1 10/96Diesel Boilerlbs/bbl 0.084 2.42 0.84 0.008 0.21AP42 1.3-12,14 9/98NG Heaters/Boilers/Burners lbs/mmscf 7.6 0.593 100 5.5 84AP42 1.4-1, 14-2, & 14-37/98NG Flareslbs/mmscf0.593 71.4 60.3 388.5AP42 11.5-1 9/91Liquid Flaringlbs/bbl 0.42 6.83 2 0.01 0.21AP42 1.3-1 & 1.3-3 9/98Tank Vaporslbs/bbl0.03E&P Forum 1/93Fugitiveslbs/hr/comp.0.0005API Study 12/93Glycol Dehydrator Ventlbs/mmscf6.6La. DEQ1991Gas Ventinglbs/scf0.0034Sulphur Content Source Value UnitsFuel Gas3.33 ppmDiesel Fuel0.4 % weightProduced Gas( Flares) 3.33 ppmProduced Oil (Liquid Flaring)1% weightFORM BOEM-0139(October 2011 - Supersedes all previous versions of form BOEM-0139 which may not be used).Page 2AIR EMISSIONS CALCULATIONS - FIRST YEARCOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONE REMARKSEni US Operating Co. Inc. Green Canyon298 G08010007 (to be renamed SS007)Brenda Montalvo(713) 393-6259OPERATIONSEQUIPMENTRATING MAX. FUEL ACT. FUEL RUN TIMEMAXIMUM POUNDS PER HOURESTIMATED TONSDiesel EnginesHP GAL/HR GAL/DNat. Gas EnginesHP SCF/HR SCF/DBurnersMMBTU/HRSCF/HRSCF/DHR/DDAYSPMSOxNOxVOCCOPMSOxNOxVOCCODRILLINGPRIME MOVER>600hp diesel29556 1427.5548 34261.32 24 60 20.83 95.57 716.11 21.48 156.24 15.00 68.81 515.60 15.47 112.50DrillshipPRIME MOVER>600hp diesel00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER diesel00 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew)2065 99.7395 2393.75 10 7 1.46 6.68 50.03 1.50 10.92 0.05 0.23 1.75 0.05 0.38VESSELS>600hp diesel(supply)2065 99.7395 2393.75 12 13 1.46 6.68 50.03 1.50 10.92 0.11 0.52 3.90 0.12 0.85VESSELS>600hp diesel(tugs)00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PIPELINEPIPELINE LAY BARGE diesel8800 425.04 10200.96 24 9 6.20 28.45 213.22 6.40 46.52 0.67 3.07 23.03 0.69 5.02INSTALLATION SUPPORT VESSEL diesel2065 99.7395 2393.75 24 9 1.46 6.68 50.03 1.50 10.92 0.16 0.72 5.40 0.16 1.18PIPELINE BURY BARGE diesel00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00SUPPORT VESSEL diesel00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00FACILITYDERRICK BARGE diesel00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew)00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply)00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRODUCTIONRECIP.<600hp diesel - North Crane(1)174 8.4042 201.70 24 365 0.38 0.56 5.37 0.43 1.16 1.68 2.46 23.50 1.88 5.09RECIP.<600hp diesel - South Crane(1)174 8.4042 201.70 24 365 0.38 0.56 5.37 0.43 1.16 1.68 2.46 23.50 1.88 5.09RECIP.<600hp diesel - Firewater Pump #1375 18.1125 434.70 24 365 0.83 1.21 11.56 0.93 2.50 3.62 5.31 50.65 4.05 10.96RECIP.<600hp diesel - Firewater Pump #2(1)375 18.1125 434.70 24 365 0.83 1.21 11.56 0.93 2.50 3.62 5.31 50.65 4.05 10.96RECIP.<600hp diesel - Auxiliary Generator(1)536 25.8888 621.33 24 365 1.18 1.73 16.53 1.32 3.58 5.17 7.59 72.40 5.79 15.67RECIP.<600hp diesel - Emergency Generator(1)280 13.524 324.58 24 365 0.62 0.91 8.63 0.69 1.87 2.70 3.97 37.82 3.03 8.19RECIP.<600hp diesel - Escape Capsule #1(1)36 1.7388 41.73 24 365 0.08 0.12 1.11 0.09 0.24 0.35 0.51 4.86 0.39 1.05RECIP.<600hp diesel - Escape Capsule #2(1)36 1.7388 41.73 24 365 0.08 0.12 1.11 0.09 0.24 0.35 0.51 4.86 0.39 1.05RECIP.<600hp diesel - Escape Capsule #3(1)36 1.7388 41.73 24 365 0.08 0.12 1.11 0.09 0.24 0.35 0.51 4.86 0.39 1.05RECIP.<600hp diesel - Auxiliary Air Compressor(1)75 3.6225 86.94 24 365 0.17 0.24 2.31 0.19 0.50 0.72 1.06 10.13 0.81 2.19RECIP.>600hp diesel - Turbine Diesel Generator #1(1)6130 296.079 7105.90 24 365 4.32 19.82 148.52 4.46 32.41 18.92 86.82 650.54 19.52 141.94RECIP.>600hp diesel - Turbine Diesel Generator #2(1)6130 296.079 7105.90 24 365 4.32 19.82 148.52 4.46 32.41 18.92 86.82 650.54 19.52 141.94SUPPORT VESSEL diesel(1)2400 115.92 2782.08 24 365 1.69 7.76 58.15 1.74 12.69 7.41 33.99 254.70 7.64 55.57ROV/Intervention Vessel diesel (1)00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00TURBINE nat gas - HPC Turbine Compressor(1)10310 98192.44 2356618.56 24 365 7.27 0.06 29.52 0.23 18.85 31.83 0.25 129.31 0.99 82.56TURBINE nat gas - Turbine Natural Gas Generator #1(1)6130 58382.12 1401170.88 24 365 4.32 0.03 17.55 0.14 11.21 18.92 0.15 76.88 0.59 49.09TURBINE nat gas - Turbine Natural Gas Generator #2(1)6130 58382.12 1401170.88 24 365 4.32 0.03 17.55 0.14 11.21 18.92 0.15 76.88 0.59 49.09RECIP.4 cycle lean nat gas0 0 0.00 0 00.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.4 cycle rich nat gas00 0.00 0 00.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER nat gas0 0.00 0.00 0 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC.BPD SCF/HR COUNTTANK- Dry Oil Storage Tank1000024 36512.5054.75TANK- Wet Oil Storage Tank1000024 3650.00 0.00 12.50 0.00 0.00 0.00 54.75 0.00FLARE-00 00.000.00PROCESS VENT-00.000.00FUGITIVES-11500.03655.750.00GLYCOL STILL VENT-00 00.000.00DRILLINGOIL BURN00 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE00 00.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002015 YEAR TOTAL62.26 198.36 1563.92 79.46 368.27 151.16 311.22 2671.76 197.50 701.40EXEMPTIONCALCULATIONDISTANCE FROM LAND IN MILES3130.203130.203130.203130.2070290.6494.0Drill, complete, and install lease term pipeline, jumpers, associated umbilical, and commencement ofproduction from Lease G 08010, Well No. 007 (to be renamed SS007) using a DrillshipFORM BOEM-0139(October 2011- Supersedes all previous versions of form BOEM-0139 which may not be used).Page 3AIR EMISSIONS CALCULATIONS - SECOND YEARCOMPANYAREABLOCK LEASE PLATFORM WELLCONTACTPHONE REMARKSEni US Operating Co. Inc.Green Canyon298 G08010007 (to be renamed SS007)Brenda Montalvo(713) 393-6259OPERATIONSEQUIPMENTRATINGMAX. FUELACT. FUELRUN TIMEMAXIMUM POUNDS PER HOURESTIMATED TONSDiesel EnginesHPGAL/HRGAL/DNat. Gas EnginesHPSCF/HRSCF/DBurnersMMBTU/HR SCF/HR SCF/D HR/D DAYS PM SOx NOx VOC CO PM SOx NOx VOC CODRILLING PRIME MOVER>600hp diesel00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRIME MOVER>600hp diesel00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PIPELINE PIPELINE LAY BARGE diesel00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION SUPPORT VESSEL diesel00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PIPELINE BURY BARGE diesel00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00FACILITY DERRICK BARGE diesel00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00INSTALLATION MATERIAL TUG diesel00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(crew)00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00VESSELS>600hp diesel(supply)00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00PRODUCTIONRECIP.<600hp diesel - North Crane(1)174 8.4042 201.70 24 365 0.38 0.56 5.37 0.43 1.16 1.68 2.46 23.50 1.88 5.09RECIP.<600hp diesel - South Crane(1)174 8.4042 201.70 24 365 0.38 0.56 5.37 0.43 1.16 1.68 2.46 23.50 1.88 5.09RECIP.<600hp diesel - Firewater Pump #1 375 18.1125 434.70 24 365 0.83 1.21 11.56 0.93 2.50 3.62 5.31 50.65 4.05 10.96RECIP.<600hp diesel - Firewater Pump #2(1)375 18.1125 434.70 24 365 0.83 1.21 11.56 0.93 2.50 3.62 5.31 50.65 4.05 10.96RECIP.<600hp diesel - Auxiliary Generator(1)536 25.8888 621.33 24 365 1.18 1.73 16.53 1.32 3.58 5.17 7.59 72.40 5.79 15.67RECIP.<600hp diesel - Emergency Generator(1)280 13.524 324.58 24 365 0.62 0.91 8.63 0.69 1.87 2.70 3.97 37.82 3.03 8.19RECIP.<600hp diesel - Escape Capsule #1(1)36 1.7388 41.73 24 365 0.08 0.12 1.11 0.09 0.24 0.35 0.51 4.86 0.39 1.05RECIP.<600hp diesel - Escape Capsule #2(1)36 1.7388 41.73 24 365 0.08 0.12 1.11 0.09 0.24 0.35 0.51 4.86 0.39 1.05RECIP.<600hp diesel - Escape Capsule #3(1)36 1.7388 41.73 24 365 0.08 0.12 1.11 0.09 0.24 0.35 0.51 4.86 0.39 1.05RECIP.<600hp diesel - Auxiliary Air Compressor(1)75 3.6225 86.94 24 365 0.17 0.24 2.31 0.19 0.50 0.72 1.06 10.13 0.81 2.19RECIP.>600hp diesel - Turbine Diesel Generator #1(1)6130 296.079 7105.90 24 365 4.32 19.82 148.52 4.46 32.41 18.92 86.82 650.54 19.52 141.94RECIP.>600hp diesel - Turbine Diesel Generator #2(1)6130 296.079 7105.90 24 365 4.32 19.82 148.52 4.46 32.41 18.92 86.82 650.54 19.52 141.94SUPPORT VESSEL diesel(1)2400 115.92 2782.08 24 365 1.69 7.76 58.15 1.74 12.69 7.41 33.99 254.70 7.64 55.57TURBINE nat gas - HPC Turbine Compressor(1)10310 98192.44 2356618.56 24 365 7.27 0.06 29.52 0.23 18.85 31.83 0.25 129.31 0.99 82.56TURBINE nat gas - Turbine Natural Gas Generator #1(1)6130 58382.12 1401170.88 24 365 4.32 0.03 17.55 0.14 11.21 18.92 0.15 76.88 0.59 49.09TURBINE nat gas - Turbine Natural Gas Generator #2(1)6130 58382.12 1401170.88 24 365 4.32 0.03 17.55 0.14 11.21 18.92 0.15 76.88 0.59 49.09RECIP.4 cycle lean nat gas00 0.00 000.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00RECIP.4 cycle rich nat gas00 0.00 000.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00BURNER nat gas0 0.00 0.00 00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00MISC.BPDSCF/HRCOUNTTANK- Dry Oil Storage Tank1000024 36512.5054.75TANK- Wet Oil Storage Tank1000024 3650.00 0.00 12.50 0.00 0.00 0.00 54.75 0.00FLARE-0000.000.00PROCESS VENT-000FUGITIVES-11500.03655.7525.19GLYCOL STILL VENT-0000.000.00DRILLING OIL BURN000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00WELL TEST GAS FLARE0000.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002016YEAR TOTAL30.8654.31484.4947.08132.76135.17237.862122.07206.19581.47EXEMPTIONCALCULATIONDISTANCE FROM LAND IN MILES3130.20 3130.20 3130.20 3130.20 70290.6494.0Drill, complete, and install lease term pipeline, jumpers, associated umbilical, and commencementof production from Lease G 08010, Well No. 007 (to be renamed SS007) using a DrillshipFORM BOEM-0139October 2011 - Supersedes all previous versions of form BOEM-0139 which may not be used).Page 4AIR EMISSIONS CALCULATIONSCOMPANYAREABLOCKLEASEPLATFORM WELLEni US Operating Co. Inc. Green Canyon 298G08010007 (to be renamed SS007)EmittedSubstanceYearPMSOxNOxVOCCO2015151.16311.22 2671.76 197.50701.402016135.17237.86 2122.07 206.19581.47Allowable0.003130.20 3130.20 3130.2070290.64FORM BOEM-0139(October 2011 - Supersedes all previous versions of form BOEM-0139 which may not be used).Page 5Eni US Operating Co. Inc. Page 

### 14

Supplemental DOCD May 19, 2014 Green Canyon Block 298 (OCS-G 08010) Public Information 

### SECTION I

OIL SPILLS INFORMATION

(a) Oil Spill Response Planning (2)(i) All proposed activities in this DOCD will be covered under Eni’s Regional OSRP filed by Eni US Operating Co. Inc., BOEM/BSEE Operator Number 02782, in accordance with 30 CFR 254, approved on January 21, 2014.

(a)(2)(ii) SPILL RESPONSE SITES

Primary Response Equipment Location Preplanned Staging Location(s) Clean Gulf Associates - Venice, Louisiana Clean Gulf Associates – Galveston, Ingleside, and Houston, Texas, Intracoastal City, Venice, Lake
Charles, Leeville, Houma, and Fort Jackson,

Louisiana

(a)(2)(iii) OSRO INFORMATION Clean Gulf Associates (CGA) is the primary equipment provider and National Response Corporation (NRC) is a secondary equipment provider for Eni in the Gulf of Mexico Region. CGA maintains a dedicated fleet of vessels and other equipment permanently located at designated ports. CGA and NRC has the capability to plan the mobilization and rapid deployment of spill response resources on a 24 hour, 7 days a week basis. The Incident Commander (IC) may use other service companies if additional equipment, materials, and personnel are needed. Refer to Appendix F of our OSRP for a listing of potential support services.

(a)(2)(iv) WORST-CASE SCENARIO COMPARISON

Category Regional OSRP

WCD DOCD WCD Regional OSRP

WCD DOCD

WCD

Type of Activity Drilling Drilling Production >10

Miles Production >10

Miles

Facility Location
(Area/Block) MC 215 GC 298 MC546 GC298

Facility Designation Well Location A Well No. 007 003 Well No. SS007

Distance to Nearest
Shoreline (miles) 64.5 94 38 94

Volume Storage tanks (total)

Uncontrolled blowout Pipelines

Total Volume 309,470 147,099 156,816
1,445
158,261 147,099

1,445
148,544
Type of Oil(s)
(crude, condensate,
diesel) Oil Oil Oil Oil

API Gravity 34° 43° 41° 43°

Eni has determined that the worst-case scenario from the activities proposed in this DOCD do not supersede the worst-case scenario from our approved Regional OSRP.Eni US Operating Co. Inc. Page 

### 15

Supplemental DOCD May 19, 2014 Green Canyon Block 298 (OCS-G 08010) Public Information S ince Eni has the capability to respond to the worst-case spill scenario included in our Regional OSRP approved on January 21, 2014, therefore the worst-case scenario determined for our DOCD does not replace the worst-case scenario in our Regional OSRP. I hereby certify that Eni has the capability to respond, to the maximum extent practicable, to a worst-case discharge, or a substantial threat of such a discharge, resulting from the activities proposed in our DOCD.

Note: Attachments associated with the calculation of the worst case discharge under this plan are under Section A of this plan.

Regional OSRP

P lease view Plan Control No. N-9735

(b) Spill Response Discussion for NEPA Analysis Please see attached Spill Response Discussion prepared for this development plan.

(c) Modeling Report Not required for the location of the activities proposed in this plan.

### GC 298

May 15 , 2014 Worst Case Discharge scenario for GC 298

1) Worst Case Summary

Given the anticipated reservoir thickness and historical productivity index ENI Petroleum has

estimated that the worst case discharge from activities at GC 298 is estimated to be 148,544 barrels of oil per day for production and 147,099 barrels of oil per day for drilling. Calculations are based on formulas defined by B SE E regulations.

This individual summar y include s the following maps and information:

1. Overview Map

2. Offset Operators Map

3. Land Impact Probability Map

4. Aerial Surveillance Response Equipment Status Boards

5. Equipment Location Map

6. In

- Situ Burn Equipment Status Boards

7. Dispersant Application Map

8. Dispersant Application Status Boards

9. Slick Containment Equipment Status Boards

10. Offshore On

- Water Recovery & Storage Equipment Status Boards

11. Nearshore On

- Water Recovery Equipment Status Boards

12. Shoreline Protection & Wildlife Support Status Boards

2) Facility Informat ion

 Type of Operation: Prodcution & Drilling

 Area and Block: Green Canyon 298

 Latitude: 27 39 ’ 9.71 ” N

 Longitude: 90 16 ’ 45.86 ” W

 Distance to Shore: 94 Miles

 Water Depth: 3,400’

 API Gravity: 43 °

### GC 298

May 15 , 2014 3) Worst Case Discharge Volume

a) Drilling Volume

An ADIOS 2 model was run on a similar product based on the oil that would reach the surface.

The res ults indicate 28% of the product would be evaporated / naturally dispersed into the water column within 24 hours. Below is a table outlining the estimated applicable subsea and surface evaporation and dispersion quantities.



### Criteria Barrels
Highest capacity well uncontrolled blowout volume associated with facility 147,099

Highest capacity storage tank volume associated with facility 0

TOTAL WORST CASE DISCHARGE 147,099

Surface Natural Evaporation and Dispersion

- 28 % (ADIOS2) 41,188

TOTAL SPILL VOLUME REMAINING AFTER

NATURAL SURFACE EVAPORATION & DISPERSON 105,911

b) Production Volume

An ADIOS 2 model was run on a similar product based on the oil that would reach the surface.

The res ults indicate 27% of the product would be evaporated / naturally dispersed into the water column within 24 hours. Below is a table outlining the estimated applicable subsea and surface evaporation and dispersion quantities.



### Criteria Barrels
Highest capacity well uncontrolled blowout volume associated with facility 147,099

Total storage tank volume associated with facility 0

Total capacity of pipelines associated with facility 1,445

TOTAL WORST CASE DISCHARGE 148,544

Surface Natural Evaporation and Dispersion

- 27 % (ADIOS2) 40,107

TOTAL SPILL VOLUME REMAINING AFTER

NATURAL SURFACE EVAPORATION & DISPERSON 108,437

### GC 298

May 15 , 2014

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### GC 298

May 15 , 2014 4) Land Segment Identification

Land areas that could be potentially impacted by a n oil spill from GC 298 were determined using the BOEM Oil Spill Risk Analysis Model (OSRAM) available on the BOEM website. The OSRAM estimates the probability that an oil spill occurring in a particular launch area will contact a certain county or parish within 3, 10, and 30 days

. The land segment that has the highest probability of being impacted by the GC 298 well is Cameron , Louisiana , at 5 percent. Land segments identified by the model are listed in the table below

.

OCS Launch Area 44 for the Gulf of Mexico Area was utilized as the point of origin. Land segments identified by the model are listed below (referenced from “ Oil

- Spill Risk Anal ysis: Contingency Planning Statistics for Gulf of Mexico OCS Activities ” – OCS Report MMS 2004

- 026 ):

Area and Spill Site Land Segment Contact Percent Impact Chance (Days)



## Green Canyon

298

Launch Block

# 44 **Land Segment No. & County/ Parish & State**  **3 10**  **30**

Matagorda, TX

-- -- 1 Galveston, TX

-- -- 2 Jefferson, TX

-- -- 1 Cameron, LA

-- -- 5
Vermilion, LA

-- -- 2
Terrebonne, LA

-- 1 2 Lafourche, LA

-- -- 1
Jefferson, LA

-- -- 1 Plaquemines, LA

-- -- 4

Note: “

-- “denotes a value of less than 0.5%.

### GC 298

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### GC 298

May 15 , 2014 5) Resource Identification

A sample Environmental Sensitivity Index map based on the current ACP is located below. Land Segment Contact Areas are identified on a map in Section 11, Resource Identification

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May 15 , 2014 6) Response

Eni has contracted with Clean Gulf Associates (CGA) and National Response Corporation (NRC) as the primary Oil Spill Removal Organization s. Contact information and procedures for requesting OSRO’s resources can be found in Section

7.

Upon notification of the spill, procedures in Section 6 will be followed with the partial or full mobilization of the resources identified in Appendix E, depending on the incident complexity. The status boards, located in this Appendix, outline equipment as well as temporary storage equipment to be considered in order to cope with an initial spill. The status boards outline on

- water containment, on

- water recovery, temporary storage, aerial and vessel dispersant application, in

- situ burning and shoreline protection equipment identified as most relevant in addressing any oil that remains present on the surface of the water. These status boards estimate times needed for procurement, load out, travel to the site and deployment. . In addition, either a fixed wing aircraft or helicopter would be dispatched for aerial surveillance at the spill location. The dispatch of aerial support will be dependent on available daylight hours, weather conditions, and other safety considerations. Aerial support may also be used to coordinate and survey response efforts (such as in

- situ burning, disp ersant application and mechanical recovery). The effectiveness of these response efforts

can be enhanced will the use of air

- based spotters, who can guide these systems to

the different oil concentrations and assist will the coordination of simultaneous

o perations. Air

- based spotters may be equipped with air to marine/ground communication equipment.

The Qualified Individual, Person in Charge, Incident Commander or designee may contact other service companies if the Unified Command deems such services

nec essary to the response effort

Simultaneous operations (SIMOPS) may involve different companies working in close proximity on identical and/or different tactical objectives. SIMOPS can be either subsea operations, surface operations or a combination of both. These operations must be well planned and coordinated. SIMOPS will be evaluated daily and coordinated based on the response efforts needs, as well as, additional criteria’s (e.g. meteorological conditions, sea state, etc.). Regular communications wi ll be established and maintained during all SIMOPS activities



### .

SIMOPS activities may include but are not limited to the following:



## • Dispersant Application (Aerial, Vessel, and Subsea)



## • In

- situ Burning



## • Mechanical Recovery



## • Nearshore / Shoreline Response



## • Source Control

### GC 298

May 15 , 2014 6) Response (Cont’d)

Vessel locations may also be monitored with real

- time vessel tracking technologies, such as Automated Identification Systems (AIS), GPS tracking, cell phone data, etc.

These technologies may be used to direct vessels to the appropriate areas of oil

concentration to enhance encounter rates.

The company will maintain an effective and well

- coordinated response effort for the duration of the response effort to control the source of the spill and to the point when

the Federal On

- Scene Coordinator deems the response effort complete.

Response Technologies Discussion

This section discusses various response technologies (in no prioritized order) that might be employed during a response to a discharge of oil. The particular response technologies applied during a spill event will be coordinated based on the most accurate and up

- to

- date knowledge of the situation, which will determine the types of technology to be used, the locations at which particular technologies are applied, and the implementation of simultaneous operations (SIMOPS).

Eni will work with their OSRO(s) to establish a remote sensing program during an incident. The goal of the remote sensing program is to integrate a common operating picture for the entire response. Remote sensing capabilities will be used on aircraft, vessels, and other platforms as appropriate. The following table outlines some of the goals of a remote sensing program.

• Determine the location of an o il slick

• Determine oil thickness

• Operate day and night, if safe to do so

• Operate under adverse weather conditions, if safe to do so

• Have the ability to work long distance offshore

• Ability to update and provide information in pre

- determined

timeframe

• Acceptance of upgrades in capacities

### GC 298

May 15 , 2014 6) Response (Cont’d)

Extended Response Operations

For an extended response to an uncontrolled well blowout of up to 120 days, additional provisions for sustained operations and source control will be implemented by the Unified Command as necessary. These options may include but are not limited to the following:

Extended Response Options

 Command Post Coordination

 Expanded Community Relations and Public Awareness

 Expanded GIS and Satellite Imagery Coordination

 Expanded Safety and Monitoring Programs

 Expanding Staging Areas and Decontamination Sites

 Extended Logistics and Procurement

 Extended Wildlife Response and Care

 Personnel Staffing and Resource

 Relief Well Drilling

 Subsea Containment

 Vessel of Opportunity Program

 Volunteer Programs

 Well Control Technologies

a) Offshore Response

Offshore response strategies may include skimming with Oil Spill Response Vessels (OSRVs), Oil Spill Response Barges (OSRBs), and Quick Strike OSRVs.

An i nitial response will likely consist of an Oil Spill Response Vessel (OSRV) due to quick mobilization and response time of these dedicated vessels. All estimated

resp onse times are captured in the s tatus b oards above. Additional response equipment and resources will begin cascading to the site or staging area(s). An offshore response will consist of simultaneous operations of containment booming and skimming operations. Dispersant application and in

- situ burn operations will be evaluated by the Unified Command, and if approved, these techniques will be used in the simultaneous operations. The following equipment categories maybe used in the

followi ng offshore response strategies:

### GC 298

May 15 , 2014 Offshore Response Strategies



## • Mechanical recovery efforts using vessels, barges, ocean boom, skimming equipment, and spotter aircraft. These resources will be deployed close to the source in order to contain and collect the maximum amount of oil and enhancing encounter rates. This may include mechanical recovery vessels and barges equipped with ocean boom systems and/or mechanical recovery ves sels and barges that will deploy skimming systems on vessels of opportunity to contain and recover oil that strays from the source area.



## • Spotter aircraft may be utilized to assist and direct skimming vessels and barges to areas of concentrated oil to ensure maximum encounter rates. Aerial and vessel communications will be established using the appropriately chosen communications system coordinated through the OSRO(s) and the FOSC.



## • Deployment of offshore resources with night sensing capabilities to enhance slick tracking during night time operations. The use of night sensing capabilities (e.g. x

- band radar systems, infrared cameras, etc.) will assist deployment of assets to areas consisting of the thickest oil to enhance the encounter and recovery r ates. These night operations will only commence if it is deemed safe to do so.



## • Upon approval, In

- situ burn assets will be deployed outside of the source area in a U configuration to collect and burn oil in heavy

concentrated areas.



## • Upon approval, dispersant application to disperse oil. Approved dispersant operations may consist of subsea and/or surface dispersant applications. Dispersant application requires the appropriate Regional Response Team (RRT) approval and will be in compliance with the R RT IV & VI guidelines.

For additional information regarding offshore response strategies, refer to the MSRC/CGA dual edition Gulf of Mexico Deep Blue Response Tactics Guidebook and the National Response Corporation’s Spill Response Guidebook.

### GC 298

May 15 , 2014 Surveillance

Upon notification of a release and mobilization of the response, either a fixed

- wing aircraft or helicopter would be dispatched as promptly as possible (considering available daylight hours, weather conditions and ot her safety factors) to conduct visual surveillance at the spill source. If necessary and safe, this surveillance could be supplemented through use of vessels as well. The effectiveness of many response technologies (such as in

- situ burning, dispersant appl ication and mechanical recovery) can be enhanced through collaboration with air

- based spotters, who can guide these systems to the greatest oil concentrations and coordinate simultaneous operations (SIMOPS). Air

- based spotters shall be equipped with air to marine/ground communication equipment to facilitate communications with marine - and land based response assets. Vessel locations may also be monitored in real

- time using vessel

tracking technologies (such as Automated Identificatio n Systems (AIS) data, GPS

based tracking, cell phone data, etc.), which can facilitate vessels being deployed for optimal recovery. Additional information regarding methods of identifying and tracking a spill on water are discussed in Section 10.

### GC 298

May 15 , 2014 Mechanical Cleanup Methods

Mechanical oil spill response uses physical barriers (boom) and mechanical devices (skimmers) to redirect and remove oil from the surface of the water.

Mechanical Cleanup Methods



## • Skimming systems will deploy boom in several different configurations. Generally, boom will be deployed in a J

configuration for a high EDRC rated single skimming unit. This usually requires only one support vessel to attend the boom. Single skimming units will be locat ed in the heavy concentrated oil and can be assisted by a spotter plane and remote sensing technologies to enhance encounter rate s and effective recovery. The system transfers recovered oil to onboard tanks for primary storage. The system boom may also be deployed in a U

configuration with an open apex to funnel oil to a single skimming unit. This requires the skimming vessels(s) to be positioned closely behind the open apex for collection and recovery.



## • For identified areas of heavy oil that cannot be addressed immediately by skimming vessels, containment boom will be deployed to contain the oil until skimming operations can

commence in these areas. Once skimmers are on

- site the oil will be directed to the skimming units. The oil may be dumped into

th e path of the skimming unit or boom may be configured into a U

configuration with an open apex to funnel oil to the awaiting skimming vessels.



## • Deployment of offshore resources with night sensing capabilities to enhance mechanical skimming activities and slick tracking during night time operations. The use of night sensing capabilities (e.g. x

- band radar systems, infrared cameras, etc.) will assist skimming vessels to deploy assets to areas consisting of the thickest oil to enhance the encounter and recovery rates.



## • Vessels of opportunity (VOO) equipped with skimming systems will be deployed to identified locations with recoverable oil. If any locations are identified to contain light oil, vessels will be equipped with sorbent materials to pick up the lighter oil.

### GC 298

May 15 , 2014 Mechanical Cleanup Methods (Cont’d)

Current proven and available sensing technology for tracking oil at night includes hand held, boat mounted and aircraft mounted infrared sensing. Multiple new oil sensing technologies (radar, satellite imagery, fluorometry, etc.) which can aid in a

response are being reviewed and developed by industry. These and any other new oil sensing technologies that become available will be deployed with the purpose of improving the ability of keeping deployed oil skimming platforms in the most highly concentrated areas of spilled oil and may be used to potentially improve the capabilities to skim beyond traditional daylight hours. However the latter capabi lity can only be implemented taking all aspects of safe operations in account and ensuring that there is no additional risk to human life.

Mechanical oil spill response uses physical barriers (boom) and mechanical devices (skimmers) to redirect and remove oil from the surface of the water.

Dispersant Application

Applying dispersant from aerial, vessel, and subsea applications may be a viable response option and will require the appropriate approvals as outlined in Section 18, Dispersant Use Plan. All dispersant application methods must be approved by the appropriate RRT and will be in compliance with RRT IV and VI guidelines.

A listing of the Aerial Dispersant Equipment is located on the status boards within this

Section.

Aerial Dispersant Application

Dispersants from aerial applications may be viable response options and will require the appropriate approvals as outlined in Section 18, Dispersant Use Plan.

If deemed appropriate and with approval, aerial dispersant application can be uti lized

with dispersant equipment listed above. Assuming a 1:20 application rate, 90% effectiveness, and 4

- 5 sorties per day.

Vessel Based Dispersant Application

Vessel

- based dispersant application is another available response option. In previous

respons es, boat

- spray systems were used for both dispersing oil and suppressing vapors near the spill source on the water surface

. Vessel

- based dispersants are also applied under the direction and approval of a designated Federal On

- Scene Coordinator (FOSC), and in a manner consistent with the National Contingency Plan and the applicable Regional Response Plan(s) and/or Area Contingency Plans (ACPs).

If appropriate, vessel spray systems can be installed on offshore vessels of opportunity to apply dispersants at the source or at other areas where there are significant concentrations of oil. Using inductor nozzles installed on fire

- water monitors, skid mounted systems, or purpose

- built boom

- arm spray systems, vessels can initially apply dispersant within the first 12 to 24 hours of the response, and

thereafter as needed.

### GC 298

May 15 , 2014 Vessel Based Dispersant Application (Cont’d)

Priorities for dispersant use and rationing of existing supplies will be determined on an incident specific basis to allow for maximum effectiveness of dispersants. Dispersant use will be dictated by approval, safety, weather, and sea states before application and coordinated with Unified Command. In addition, after assessing the situation and notifications will be made within 48 hours of the initial spill to begin ramping up dispersant production through Nalco, as discussed in Section 18, Dispersant Use

Plan.

All dispersant application will be in compliance with RRT IV and VI guidelines.

For additional information regarding dispersant response strategies, refer to the MSRC/CGA dual edition Gulf of Mexico Deep Blue Response Tactics Guidebook and the National Response Corporation’s Spill Response Guidebook.

In

- situ Burning

Open

- water in

- situ burning (ISB) also may be used as a response strategy, depending on the circumstances of the release. ISB services may be provided by the primary OSRO contractors. If appropriate conditions exist and approvals are granted, one or multiple ISB task forces could be deployed offshore.

Task forces typically consist of two to four fire teams, each with two vessels capable of towing fire boom, guide boom or tow line with either a handheld or aerially

deployed oil ignition system. At least one support/safety boat would be present during active burning operations to provide logistics, safety and monitoring support. Depending upon a number of factors, up to 4 burns per 12

- hour day could be completed per ISB fire team. Most fire boom systems can be used for approximately

8- 12 burns before being replaced. Fire intensity and weather will be the main determining factors for actual burns per system. Although the actual amount of oil that will be removed per burn is dependent on many factors, recent data suggests that a typical burn might eliminate approximately 750 barrels. For planning purposes and based on the above assumptions, a single task force of four fire teams with the appropriate weather and safety conditions could complete four burns per day and remove up to ~12,000 bbls/day.

After assessing the situation and notification should be made within the 48 hours of the initial spill to begin ramping up fire boom production through contracted OSRO(s) as discussed in Section 19, In

- situ Burn Plan.

Considerations and limitations to ISB include atmospheric and sea conditions, oil weathering, air quality impacts, safety of response workers, and risk of secondary fires. All safety considerations will be evaluated. Additional information on ISB is presented in Section 19, In

- situ Burn Plan.

For additional information regarding in

- situ burning response strategies, refer to the MSRC/CGA dual edition Gulf of Mexico Deep Blue Response Tactics Guidebook.

### GC 298

May 15 , 2014 Well Containment

The initial response to a well blowout would be an attempt to activate the blowout preventers and close the well. The Source Control team will be stood up immediately with notifications to the primary well control provider, Helix Well Containment Group (H WC G ) in the event of a blowout. The first step will be determining the method for source control (ie. capped and killed or captured and flow). These options will be determined prior to drilling using the Well Containment Screening Tool.

Subsea containment resources would be mobilized in the event of an uncontrolled well blowout. Subsea containment incorporates simultaneous operations to cap or contain the flow of oil within the well, contain the oil outside of the well and collect at surface facilities or vessels and chemically disperse the oil at the well head. HWCG has been contracted to supply the subsea dispersant applications.

Subsea containment activities, including Source Control are addressed in Appendix I.

Source Control Activities

 Notifications to regulatory authorities, HWCG , and support contractors regarding well control incident

 Site assessment, initial response, and well monitoring

 Notification and activation of any equipment and

contract services outside of HWCG will be initiated by

Eni (e.g. shuttle tankers, helicopters, etc.)

 Notification, as needed, to members of HWCG to assist

Eni ’s Source Control Group during source control operations

 Debris Removal and Lower Marine Riser Package (LMRP) Recovery Considerations, if applicable

 Coordination of ROVs, support vessels, intervention vessels, subsea dispersant equipment, subsea dispersant application, debris removal tools, umbilical, chemical delivery, pumping services, and other equipment for WCD scenarios

 Run Intervention Riser System

 Well Capping and Shut

- in Operation Activities

For additional detailed information on these systems, their components, and deployment times, refer to the current Marine Well Containment Company Interim Containment Response System Functional Specifications USWC

- ED

- BPFEP

- 000001 provided to BSEE by HWCG

. Information on how these systems will be deployed to respond to a specific well, can be found in the NTL 2010

- N10 information submitted as a supplement to the individual “Application for Permit to Drill.”

### GC 298

May 15 , 2014 b) Nearshore and Shoreline Protection

If a nearshore spill were to occur, shoreline impact would depend upon existing environmental conditions. Nearshore response may include the deployment of shoreline boom on beach areas, or protection and sorbent boom on vegetated area s, as well as shallow water response strategies. Sorbent boom is a readily available resource and can be acquired as needed. OSRO’s have resources which can be deployed for a shoreline cleanup effort (equipment locations are depicted on the Equipment Location map), as well as the contractor Shoreline Protection & Wildlife Support Status Board in this section. CGA maintains the PRO’s program. This is a list of subcontractors that may be called upon for assistance for the nearshore/shoreline response.

St rategies would be based upon surveillance and real time trajectories provided by The Response Group that depict areas of potential impact given actual sea and weather conditions. Strategies from the Area Contingency Plan, The Response Group and Unified Command would be consulted to ensure that environmental and special economic resources would be correctly identified and prioritized to ensure optimal protection. The deployment of nearshore resources with night sensing capabilities to enhance slick tracking may be used during night time operations. The use of night sensing capabilities (e.g. x

- band radar systems, infrared cameras, etc.) will assist deployment of assets to areas consisting of the thickest oil to enhance the encounter and recovery rates.

For additional information regarding Nearshore and Shoreline response strategies, refer to the MSRC/CGA dual edition Gulf of Mexico Deep Blue Response Tactics Guidebook, the National Response Corporation’s Spill Response Guidebook, the Area Contingency Plans, and the appropriate Shoreline Response Strategy Guidebook developed by The Response Group.

Surveillance

Either a fixed

- wing aircraft or helicopter will conduct visual surveillance to assess the situation and assist in coordinating Nearshore and Shoreline response activities. If necessary and safe, this surveillance could be supplemented through use of vessels as well. The effectiveness of many response technologies (such as in

- situ burning, dispersant application and mechanical recovery) can be enhanced through

collaboration with air

- based spotters, who can guide these systems to the oil concentrations and coordinate simultaneous operations (SIMOPS). Air

- based spotters may be equipped with air to marine/ground communication equipment to facilitate

communications with marine - and land

- based response assets. Vessel locations may

also be monitored in real

- time using vessel

- tracking technologies (such as Automated Identification Systems (AIS) data, GPS

- based tracking, cell phone data, etc.), which

can facilitate vessels being deployed for optimal recovery. Additional information regarding methods of identifying and tracking a spill on water are discussed in Section

10.

### GC 298

May 15 , 2014 Mechanical Cleanup Methods

In order to minimize shoreline impact, mechanical recovery resources will be deployed to contain and collect oil. In shallow water areas, it may be possible to collect and corral oil with ocean boom and move it to deeper water or low

- current areas that allow for better skimmer

access and higher encounter and recovery rates. Skimmers will also be deployed in natural collection points along the shoreline.

This table outlines some of the water

- borne tactics that may be used in

a shallow water environment



## • Shallow Water Barge Skimming (SBS)



## • Combination FRV/SBS



## • Shallow Water Skimmers



## • Shallow Water Recovery Barge (Skimming System/Shuttle Barge)

This table outlines an example of land

- based tactics that may be used

in shallow water environments



## • Vacuum Trucks



## • Shore

- side Skimmers



## • Sorbent Materials

For additional information regarding mechanical response strategies, refer to the MSRC/CGA dual edition Gulf of Mexico Deep Blue Response Tactics Guidebook and the National Response Corporation’s Spill Response Guidebook.

### GC 298

May 15 , 2014 Dispersant Applications

Dispersant use within 10 miles of shore will be considered on a case

- by

- case basis. Consideration will be given according to the location of the spill material, distance from shore, water depth, trajectory modeling, and environmental impacts of a non

- disp ersed spill. The Near Shore Environmental Dispersant Expedited Approval Process (NSE EAP) Initial Call and Minimum Criteria Checklists are located in Figure 18

- 11 and Figure 18

- 12. If deemed appropriate and with approval, aerial dispersant application can be utilized aerial dispersants denoted in the Status Boards above. It is assumed there will be a 1:20 application rate, 90% effectiveness with the ability to conduct 4

- 5 sorties per day.

Vessel dispersant application may be another available response option. If appropriate, vessel spray systems can be installed on offshore vessels of opportunity using inductor nozzles (installed on fire

- water monitors), skid mounted systems, or purpose

- built boom arm spray systems. Vessels can apply dispersant within the first 12

- 24 hours of the response and continually as directed.

All dispersant applications will be in compliance with the RRT IV and VI guidelines.

For additional information regarding dispersant response strategies, refer to the MSRC/CGA dual edition Gulf of Mexico Deep Blue Response Tactics Guidebook and the National Response Corporation’s Spill Response Guidebook.

In

- situ Burning

In

- situ burning nearshore and along shorelines may be a possible option based on several conditions and with appropriate approvals from the RRT, as outlined in Section 19, In

- situ Burn

Plan. In

- situ burning along certain types of shorelines may be used to minimize physical damage where access is limited or if it is determined that mechanical/manual removal may cause a substantial negative impact on the environment. All safety considerations will be

evaluated.

Additional information on ISB is presented in Section 19, the In

- Situ Burn Plan. In addition, after assessing the situation and notifications will be made within 48 hours of the initial spill to begin ramping up fire boom production through contracted OSRO(s) as discussed in Section
19, the In

- sit u Burn Plan.

For additional information regarding in

- situ burning response strategies, refer to the MSRC/CGA dual edition Gulf of Mexico Deep Blue Response Tactics Guidebook and the National Response Corporation’s Spill Response Guidebook.

### GC 298

May 15 , 2014 Shoreline Protection

The Response Group’s Shoreline Response Guides depict the protection response modes applicable for oil spill clean

- up operations. Each response mode is schematically represented to show optimum deployment and operation of the equipment in areas of environmental concern. Supervisory personnel have the option to modify the deployment and operation of equipment, allowing a more effective response to site

- specific circumstances. The following are various types of boom that may be deploye d to protect the shoreline.

Shoreline Boom Options

Near Shore Booming When oil impact threatens shoreline or marshes. Medium size boom (~18”) to deflect or contain oil or use to prevent impact to sensitive areas.

Bottom

- Seal Boom Typically used in shallow water with higher

currents. The shallow skirt minimizes the drag in

the current and allows it to conform to the

substrate so that it can continue to act as a barrier to oil during changing tides or lower water levels.

Bottom seal boom uses ballast tubes that are filled

with water and lies on the bottom to provide a seal against oil passage.

Inland Boom Inland boom is the smallest conventional boom and is designed for deployment in very shallow water; as the draft is only 6

- 12 in ches. It is normally deployed in more protected waters where

there is little or no wave action.

Sorbent Boom Deployed to absorb oil and act as a protective measure against thin oil sheens under very quiet water conditions. Snare boom may be used for

mor e viscous oils under higher wave and current

conditions. Sorbent booms effectiveness is limited to only the thinnest sheens.

For more information on resource identification and protection methods, see Section 11,

Resource Identification. A time frame f or the mobilization of equipment is outlined in Section 14, Mobilization & Deployment Methods, based on equipment locations. See Section 15, Oil & Debris Removal for additional shoreline cleanup and protection methods.

For additional information regarding shoreline response strategies, refer to the MSRC/CGA dual edition Gulf of Mexico Deep Blue Response Tactics Guidebook, the National Response Corporation’s Spill Response Guidebook, the Area Contingency Plans, and the appropriate Shoreline Response Strategy Guidebook developed by The Response Group.

Wildlife Support

If wildlife is threatened due to a spill, the OSRO’s have resources available that can be utilized to protect and rehabilitate wildlife. See Appendix E, Response Equipment, for details on the available resources, and Section 17, Wildlife Rehabilitation Procedures, for further details on the protection and rehabilitation of affected wildlife and contacts for available wildlife protection and rehabilitation providers.

### Eni US Operating Co. Inc. Page 16

Supplemental DOCD May 19, 2014 

### Green Canyon Block 298 (OCS-G 08010) Public Information 

### SECTION J

ENVIRONMENTAL MONITORING INFORMATION

(a) Monitoring Systems There are no environmental monitoring systems currently in place or planned for the proposed activities.

(b) Incidental Takes No incidental takes are anticipated. Eni implements the mitigation measures and monitors for incidental takes of protected species according to the following notices to lessees and operators from BOEM/BSEE:

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

• NTL 2012-Joint-G01 “Vessel Strike Avoidance and Injured/Dead Protected Species Reporting”

• NTL 2012-Joint G02 “Implementation of Seismic Survey Mitigation Measure & Protect Species Observer Program”



### SECTION K

LEASE STIPULATIONS INFORMATION

Marine Protected Species Eni will operate in accordance with NTL 2012-Joint-G01 “Vessel Strike Avoidance and Injured/Dead Protected Species Reporting” and NTL 2012-Joint G02 “Implementation of Seismic Survey Mitigation Measure & Protect Species Observer Program”, 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.



### SECTION L

ENVIRONMENTAL MITIGATION MEASURES INFORMATION

(a) Measures Taken to Avoid, Minimize, and Mitigate Impacts The proposed action will implement mitigation measures required by laws and regulations, including all applicable Federal & State requirements concerning air emissions, discharges to water, and solid waste disposal, as well as any additional permit requirements and Eni policies. Project activities will be conducted in accordance with the Regional OSRP.

(b) Incidental Takes Eni US Operating Co. Inc. does not anticipate any incidental takes related to the proposed operations. Eni implements the mitigation measures and monitors for incidental takes of protected species according to the following notices to lessees and operators from BOEM/BSEE:

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

• NTL 2012-Joint-G01 “Vessel Strike Avoidance and Injured/Dead Protected Species Reporting”

• NTL 2012-Joint G02 “Implementation of Seismic Survey Mitigation Measure & Protect Species Observer Program”Eni US Operating Co. Inc. Page 

### 17

Supplemental DOCD May 19, 2014 Green Canyon Block 298 (OCS-G 08010) Public Information 

### SECTION M

RELATED FACILITIES AND OPERATIONS INFORMATION

(a) Related OCS Facilities and Operations The subject well will have a 10K horizontal tree mounted on the top of the wellhead in approximately 3200’(feet) water depth. Subsea wells on the continent shelf in the GoM in such deep water usually do not have any protective structures since they are far away from the coastal and shallow water areas (state water) where fishing and navigation activities are frequent.

A 6-inch insulated lease-term oil pipeline approximately 2.3 miles in length will be installed to transport produced hydrocarbons from Green Canyon Block 298, Well No. 007 to the South Riser Manifold (REM) at Green Canyon Block 298, associated with a 4-inch jumper to the Allegheny A Platform TLP in Green Canyon Block 254 (Complex ID 251) through one of the existing 4.5-inch steel catenary risers (SCRs). The maximum flow rate is estimated to be 9,000 barrels of crude oil per day. The pipeline boarding shutdown valve (BSDV) at the Allegheny TLP meets the 45 second shut-in requirement as set forth in

the NTL No. 2009-G36.

E ni anticipates installing minimal processing equipment on this structure. All hydrocarbon handling equipment installed for testing and production operations will be designed, installed and operated to prevent pollution.

(b) Transportation System As stated in (a) above, a pipeline will be installed to transport produced hydrocarbons from the proposed well site to the existing structure in Green Canyon Block 254-A. No new nearshore or onshore pipelines

or facilities will be constructed.

(c) Produced Liquid Hydrocarbons Transportation Vessels There will not be any transfers of liquid hydrocarbons other than via pipeline.Eni US Operating Co. Inc. Page 

### 18

Supplemental DOCD May 19, 2014 Green Canyon Block 298 (OCS-G 08010) Public Information 

### SECTION N

SUPPORT VESSELS AND AIRCRAFT INFORMATION

(a) General

Type Maximum Fuel Tank Capacity Maximum

Number in Area at Any Time Trip Frequency or

Duration

Crew Boat 1500 bbls 1 1 per week

Supply Boat 2500 bbls 2 2 per vessel per week

Helicopter 286 gallons 1 1 per day

ROV Installation Vessel 10,000 bbls 1 9 days

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

utilized.

(b) Diesel Oil Supply Vessels A ROV vessel will be used to install jumpers. Eni will not use a diesel oil supply vessel for this operation.

Size of Fuel Supply

Vessel Capacity of Fuel Supply Vessel Frequency of Fuel Transfers Route Fuel Supply

Vessel Will Take

240 Foot 2500 Barrels 3 per month Port Fourchon to

GREEN CANYON

BLOCK 298

(c) Drilling Fluid Transportation This table is required for operations in the State of Florida and is not required in this plan.

(d) Solid and Liquid Waste Transportation

TABLE 2: WASTES YOU WILL TRANSPORT AND /OR DISPOSE OF ONSHORE

(e) Vicinity Map Enclosed 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.Eni US Operating Co. Inc.Page19Supplemental DOCDMay 19, 2014Green Canyon Block 298 (OCS-G 08010)Public InformationEni US Operating Co. Inc. Page 

### 20

Supplemental DOCD May 19, 2014 Green Canyon Block 298 (OCS-G 08010) Public InformationEni US Operating Co. Inc. Page 21

Supplemental DOCD May 19, 2014 Green Canyon Block 298 (OCS-G 08010) Public Information 

### SECTION O

ONSHORE SUPPORT FACILITIES INFORMATION

(a) General The table below is the onshore facilities that will be used to provide supply and service support for the proposed activities under this plan:

Name of Shorebase Location Existing/New/Modified

Fourchon, LA – Gulf Offshore

Logistics 300 AT Gisclair Road
Fourchon, LA 70357 Existing

PHI Heliport Houma, LA 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 plan.

(c) Support Base Construction or Expansion Timetable Eni will not expand the existing shorebase as a result of the operations proposed in this DOCD.

(d) Waste Disposal

TABLE 2:

WASTES YOU WILL TRANSPORT AND /OR DISPOSE OF ONSHOREEni US Operating Co. Inc.Page22Supplemental DOCDMay 19, 2014Green Canyon Block 298 (OCS-G 08010)Public InformationEni US Operating Co. Inc. Page 23

Supplemental DOCD May 19, 2014 Green Canyon Block 298 (OCS-G 08010) Public Information 

### SECTION P COASTAL ZONE MANAGEMENT (CZMA) INFORMATION

A certificate of Coastal Zone Management Consistency for the state(s) is not required 

### under NTL 2008-G04
for Supplemental Development Operations Coordination Document.Eni US Operating Co. Inc. Page 24

Supplemental DOCD May 19, 2014 Green Canyon Block 298 (OCS-G 08010) Public Information 

### SECTION Q ENVIRONMENTAL IMPACT ANALYSIS (EIA)

In accordance with the requirements of 30 CFR 550.261 an Environmental Impact Analysis (EIA) is attached.

Attachments: Environmental ReportEIA – GC298

MAY 2014 

## APPENDIX 19

Environmental Impact Analysis

(A) Impact Producing Factors Environmental Impact Analysis Worksheet

Environmental

Resources Impact Producing Factors (IPFs) Categories and Examples

Refer to a recent Gulf of Mexico Outer Continental Shelf Lease Sale EIS for a more complete list of IPFs

Emissions (air, noise, light, etc.) Effluents (muds, cuttings,

other discharges

to the water

column or seafloor) Physical

disturbances

to the seafloor (drilling rig or

anchor emplacements, etc.) Wastes

sent to

shore for

treatment or disposal Accidents (e.g., oil spills,

chemical spills, H 2 S releases) Discarded

Trash and

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)

Chemosynthetic

communities (4)

Water quality X X X X

Fisheries X X X

Marine mammals X(8) X X(8) X

Sea turtles X(8) X X(8) X

Air quality X(9) X

Shipwreck sites (known or potential (7)

Prehistoric archaeological sites X(7)

Vicinity of Offshore

Location

Essential fish habitat X X X(6)

Marine and pelagic

birds X X X

Public health and safety (5)

Coastal and Onshore

Beaches X(6) X

Wetlands X(6)

Shore birds and coastal nesting birds X(6) X

Coastal wildlife refuges X

Wilderness areas X

Other Resources you identifyEIA – GC298

MAY 2014 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 installed on the seafloor within the:

(a) The 4-mile zone of the Flower Garden Banks or the 3-mile zone of Stetson
Bank;

(b) The 1000-m, 1-mile, or 3 mile zone of any topographic feature (submarine bank) protected by the Topographic Features Stipulation attached to an Outer Continental Shelf (OCS) lease;

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

(d) 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 with in 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 Bureau of Ocean Energy Management (BOEM) as being in water depths 300 meters or greater.

5. Exploration or production activities where Hydrogen Sulfide (H 2 S) concentrations greater than 500 part per million (ppm) may occur.

6. All activities potentially resulting in an accidental spill of produced liquid polycyclic aromatic hydrocarbons or diesel fuel that may potentially impact these environmental resources. The EIA may denote if the proposed action is located a sufficient distance from a resource, thus resulting in no impact.

7. All activities involving seafloor disturbances (e.g. anchor placements) in any OCS block with a high-probability of shipwrecks or prehistoric sites occurrence (as designated by the BOEM), including such blocks that will be affected that are adjacent to the lease block in which the planned activity will occur. The EIA may denote if the proposed activities are located a sufficient distance from a shipwreck or prehistoric site, thus resulting in no impact.

8. All activities that might have an adverse effect on endangered or threatened marine

mammals or sea turtles or their critical habitats.

9. Production activities that involve transporta tion of produced fluids to shore using shuttle tankers or barges.EIA – GC298

MAY 2014 (B) ANALYSIS

Site-Specific at Green Canyon Area, Block 298, Well No. 7

1. Designated Topographic Features Potential Impact Producing Factors (IPFs) on topographic features include physical disturbances to the seafloor, effluents, and accidents.

Physical disturbances to the seafloor: Green Canyon Area, Block 298, Well No. 7 is located approximately 39 miles southeast of Diaphus Bank (South Timbalier Area, South Addition, Block 317), the nearest known topographic feature, no adverse impacts are expected.

Effluents: Green Canyon Area, Block 298, Well No. 7 is located approximately 39 miles southeast of Diaphus Bank (South Timbalier Area, South Addition, Block 317), the nearest known topographic feature, no adverse impacts are expected.

Accidents: The following discussion of topographic features is summarized from the Final Environmental Impact Statement (EIS; US DOI, MMS, 2002). The Topographic Features Stipulation (TFS) has been used on offshore energy leases located in close proximity to biotic communities since 1973. The TFS provides protection of biota in these areas from damage occurring as a result of routine oil and gas activities (Schmahl et al. 2012). In the unlikely event of an accidental surface or subs urface oil spill, concentrated oil is not expected to impact sessile biota on designated topographic features within regional proximity. In the northern Gulf of Mexico, a majority of topographic features occur within 150 to 200 feet of the water’s surface (http:oceanexplorer.noaa.gov, last accessed April 2013); therefore, concentrated oil from a surface spill is not likely to reach sessile biota. While unlikely, subsurface spills may result in formation and settling of oil-saturated material with particles potentially reaching organisms and resulting in adverse impacts; however a subsurface spill is expected to disperse and stay suspended or slowly rise to the surface (NOAA 2010). The Eni US Operating Co. Inc. Oil Spill Response Plan will cover activities proposed in this DOCD.

There are no other IPFs (including emissions, wastes sent to shore for disposal, and discarded trash and debris) from the proposed activities potentially impacting topographic

features.

2. Pinnacle Trend Area Live Bottoms Potential IPFs on pinnacle trend area live bottoms include physical disturbances to the seafloor, effluents, and accidents.

Physical disturbances to the seafloor: Green Canyon Area, Block 298, Well No. 7 is located approximately 154 miles southwest of Main Pass, Block 290, the nearest block protected by the pinnacle trend live bottom stipulation; therefore, no adverse impacts are expected. The following discussion of pinnacle trend areas of live bottoms is summarized from the Final EIS (USDOI, MMS 2002). Upon identification of pinnacles present at the activity site, the lessee will be advised to avoi d placement of the drilling rig and anchors onEIA – GC298

MAY 2014 the identified area. Therefore, mechanical damage to the pinnacles is avoided by following restrictions listed in the Final EIS for pinnacle trend area live bottoms.

Effluents: Green Canyon Area, Block 298, Well No. 7 is located approximately 154 miles southwest of Main Pass, Block 290, the nearest block protected by the pinnacle trend live bottom stipulation; therefore, no adverse impacts are expected. The stipulation does not address the discharge of effluents near the pinnacles because the pinnacle trend is subject to heavy natural sedimentation and is at c onsiderable depths. The quick dilution of drill cuttings and muds will minimize the potential of significant concentration of effluents on the pinnacles (perf.org, last accessed April 2013).

Accidents: In the unlikely event of an accidental surface or subsurface oil spill, concentrated oil is not expected to impact biota of the pinnacle trend. Any surface oil spill resulting from a proposed action would likely have no impact on the biota of the pinnacle trend because the crests of these features occur at a depth greater than 20 meters. All evidence to date indicates that accidental oil discharge occurring at the seafloor from pipelines or blowouts will rise in the water column—surfacing almost directly over the source location—without impacting pinnacles. In the unl ikely event of an accident, adverse impacts to pinnacle trend area live bottoms are possible. The Eni US Operating Co. Inc. Oil Spill Response Plan will cover activities proposed in this DOCD.

There are no other IPFs (including emissions, wastes sent to shore for disposal, and discarded trash and debris) from the proposed activities, which could impact pinnacle trend

area live bottoms.

3. Eastern Gulf Live Bottoms Low Relief Area Potential IPFs on Eastern Gulf live bottoms low relief area include physical disturbances to the seafloor, effluents, and accidents.

Physical disturbances to the seafloor : Green Canyon Area, Block 298, Well No. 7 is located approximately 194 miles southwest of the nearest block (Destin Dome 573) protected by the gulf live bottom stipulation, therefore, no adverse impacts are expected. The following discussion of eastern gulf live bottom is summarized from the Final EIS (USDOI, MMS 2002). Through detection and avoidance, the Eastern Gulf live bottom lease stipulation minimizes the likelihood of mechanical damage to the sessile and pelagic

communities associated with the crest and flanks of such features as a result of OCS activities associated with drilling rig and anchor placement.

Effluents: Green Canyon Area, Block 298, Well No. 7 is located approximately 194 miles southwest of the nearest block (Destin Dome 573) protected by the gulf live bottom stipulation, therefore, no adverse impacts are expected. Since this area is subject to heavy natural sedimentation, this stipulation does not include any specific measures to protect the pinnacles from the discharge of effluents.EIA – GC298

MAY 2014 Accidents: In the unlikely event of an accidental surface or subsurface oil spill, concentrated oil is not expected to impact Eastern Gulf live bottoms because of the features and dilution of spills by currents and/or quickly rising oil. However, in the unlikely event of an accident, adverse impacts to Eastern Gulf live bottoms are possible. Eni US Operating Co. Inc.’s Spill Response Plan will cover activities proposed in this DOCD.

There are no other IPFs (including emissions, wa stes delivered to shore for disposal, and discarded trash and debris) from the proposed activities, which could impact eastern Gulf

live bottoms.

4. High-Density Deepwater Benthic Communities After careful review of the impact-producing factors (including effluents, physical disturbances to the seafloor, and accidents) that could result from the activities proposed under this DOCD; Green Canyon Area, Block 298, Well No. 7 is located approximately 6 miles south of the nearest block (Green Canyon 210) with known chemosynthetic communities, it has been determined that there will be no adverse impacts to chemosynthetic communities. Bottom-disturbi ng activities proposed in this DOCD will not impact any deepwater benthic chemosynthet ic communities, as evidenced by Fugro GeoConsulting, Inc., “Shallow Hazard Assessment, Allegheny Prospect, Block 298, Green Canyon Area, Gulf of Mexico”, Report No. 27.2014-2706 and Fugro GeoConsulting, Inc., “Wellsite Clearance Letter, Proposed Wellsite GC 298, Well No. 007, Block 298, Green Canyon Area”, Report No. 27.2014-2706-GC298-7. The water depth at the surface location of the proposed Green Canyon Area, Block 298, Well No. 7 is 3,206 feet. The proposed activities are not located within the vicinity of any known chemosynthetic communities which typically occur in water depths from 300 meters down to the abyssal oceanic zone (NTL 2009-G40; www.bsee.gov).

The water depth at the surface location of the proposed Green Canyon Area, Block 298, Well No. 7 is 3,206 feet. Discharge of water-based drilling fluids and cuttings at the surface in such water depths will be spread across broad areas of the seafloor in thin accumulations with very low impact expected.

A Shallow Hazards Assessment, Report No. 27.2014-2706 dated March 24, 2014, of the seafloor covering the wellsite was prepared by Fugro GeoConsulting, Inc. The results of the seafloor assessment concluded that there were no high density deepwater benthic communities located within the proposed location.

An accidental oil spill or chemical spill could have a detrimental impact on chemosynthetic communities; however, it is highly unlikely that this would occur. If it does occur, Eni US Operating Co. Inc. has an approved Oil Spill Response Plan in place which would be immediately put into action. There are no other IPFs (including emissions and discarded trash and debris) from the proposed activities which could cause impacts to chemosynthetic

communities.EIA – GC298

MAY 2014 5. Water Quality Potential IPFs resulting in water quality degradation from the proposed activities of this DOCD include physical disturbances to the seaf loor, effluents, wastes sent to shore for treatment or disposal, and accidents.

Physical disturbances to the seafloor: Bottom area disturbances resulting from the placement of drill rigs, the drilling of wells and the installation of platforms and pipelines will temporarily increase water-column turbid ity and re-suspension of any accumulatedpollutants (e.g. trace metals and excess nutrients). Increased turbidity and potential resuspension of pollutants will cause ephemeral impacts on water quality conditions in the immediate vicinity of the emplacement operations.

Effluents: The discharge generated as a result of drilling and completion activities associated with this DOCD will be discharged upon successful bioassay tests, per NPDES discharge guidelines. All applicable Federal, State and Local guidelines regarding water quality and discharge for the proposed activities, as well as any other permit conditions, will

be followed.

Wastes sent to shore for treatment or disposal: Solid wastes—typically paper, plastic, cloth, and metal—will be collected and transported to shore for disposal at an approved facility. Solid wastes generated from the transportation vessels will be collected and returned to shore for disposal concurrent with the drilling rig refuse. Scrap metal and other metal wastes will be recycled or sold. Sanitary waste will be treated in approved marine sanitation devices as required by the Clean Water Act. All biodegradable wastes, such as kitchen food scraps, will be comminuted or ground and discharged in accordance with Annex V of MARPOL 73/78 (International Convention for the Prevention of Pollution from Ships, 1973 as modified by the Protocol of 1978). Hazardous waste from the drilling rig, such as paint and/or paint thinner, will be collected in sealed metal containers and transported to an approved disposal site in accordance with Resource Conservation and Recovery Act guidelines.

Accidents: The following discussion of potential impacts to water quality is summarized from the Final Environmental Impact Statement (USDOI, MMS 2002). In the unlikely event of a surface or subsurface oil spill, a variety of physical, chemical, and biological processes are enacted to disperse the oil such as the evaporation of the more volatile constituents, dissolution into the water column, emulsification of small droplets, agglomeration sinking, microbial modification, photochemical modifica tion, biological ingestion and excretion, and more. The dissolved components and small oil droplets that do not rise to the surface or are mixed down by surface turbulence might temporarily affect the water quality. Dispersion by currents and microbial degradation may remove the oil from the water column or dilute the constituents to background levels. Therefore, adverse impacts to water quality are possible, but are unlikely. Eni US Operating Co. Inc.’s Spill Response Plan will cover activities proposed in this DOCD.

There are no other IPFs (including emissions and discarded trash and debris) from the proposed activities which could cause impacts to water quality.EIA – GC298

MAY 2014 6. Fisheries Potential IPFs resulting in impacts to fisheries from the DOCD proposed activities include physical disturbances to the seafloor, effluents, and accidents.

Physical disturbances to the seafloor: Since the activities proposed in this DOCD are located in water depths of approximately 3,206 feet, the emplacement and removal of facilities are not expected to cause significant adverse impacts to fisheries.

Effluents: Effluents such as drilling fluids and cuttings discharges contain some components and properties that 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 3000 m of the discharge point, and are expected to have negligible effect on fisheries.

Accidents: The following discussion of potential impacts to water quality is summarized from the Final Environmental Impact Statement (USDOI, MMS 2002) and the National Oceanic and Atmospheric Administration (NOAA). The Gulf Sturgeon ( Ancipenser Oxyrincus

desotoi ) and Smalltooth Sawfish ( Pristis pectinata ) are the only listed threatened or endangered fish species in the Gulf of Mexico (www.noaa.gov, last accessed November 2012). The current distribution of the Smalltooth Sawfish is limited to peninsular Florida. The activities proposed in this plan are not expected to cause adverse effects to the Smalltooth Sawfish. The Gulf Sturgeon may potentially be impacted by a spill, if one were to occur. While unlikely, contact with spilled oil may cause sublethal to lethal effects in fishes, depending on the amount of exposure. The likelihood of spill occurrence and contact to the Gulf Sturgeon and other Gulf of Mexico fish is very low.

Should a spill occur in the area of adult finfish or shellfish, the effects will likely be sublethal and the extent of the damage would be dependent on the ability of the adult fishes and shellfishes to avoid a spill, to metabolize poly cyclic aromatic hydrocarbons, and to excrete both metabolites and parent compounds. In the unlikely event of an accident, adverse impacts to fisheries are possible. Eni US Operating Co. Inc.’s Spill Response Plan will cover activities proposed in this DOCD.

There are no other IPFs (including emissions, wastes sent to shore for disposal, and discarded trash and debris) from the proposed activities that could cause impacts to

fisheries.

7. Marine Mammals Potential IPFs potentially impacting marine ma mmals from the DOCD proposed activities include emissions, effluents, discarded trash and debris, and accidents.

Endangered or threatened marine mammal species occurring in the Gulf of Mexico are West Indian Manatee ( Trichechus manatus ), Fin Whale ( Balaenoptera physalus ), Humpback Whale ( Megaptera novaeangliae ), Sei Whale ( Balaenoptera borealis ), Sperm Whale ( Physeter macrocephalus ), and Blue Whale ( Balaenoptera musculus ) (www.noaa.gov, last accessed September 2012). Several species of non-endangered and non-threatened mammal species of whales and dolphins also occur in the Gulf of Mexico.EIA – GC298

MAY 2014 Emissions: Disturbances (e.g. noise) may stress marine mammals and weaken their immune systems making them more vulnerable to parasites, diseases, environmental contaminants, and predation; however, the effect of these stressors on marine mammals is dependent upon the intensity and amount of exposure (Wright and Weilgart 2011). There are multiple studies debating whether anthropogenic noise and other disturbances cause long-term displacement of or population reductions in marine mammal populations.

Effluents: Contaminants in waste discharge and drilli ng muds might indirectly affect marine mammals through food-chain bioaccumulations. Although the scope of effects and their magnitude are not known, direct or indirect effects are not expected to be lethal.

Discarded Trash and Debris: Both entanglement in and ingestion of debris have caused death or serious injury in marine mammals (Williams et al. 2011). The marine debris, if any, resulting from the proposed activities is not expected to significantly affect marine mammals. Eni US Operating Co. Inc. will adhere to the information and guidelines set forth by the

Marine Trash and Debris Awareness and Elimination Notice to Lessees and Operators (BSEE; NTL 2012-BSEE-G01).

Accidents: Small numbers of marine mammals may experience mortality or injury by chance collision with service vessels. Sperm whales are one of the 11 whale species that are hit commonly by ships (Wilson et al. 2007). Collisions between OCS vessels and cetaceans within the project area are unlikely. In the case of a vessel-marine mammal collision, chronic and or acute sublethal effects may occur and stress or weaken individuals making them more susceptible to infection. Few lethal effects are expected from collisions with service vessels. Eni US Operating Co. Inc. will adhere to the information and guidelines set forth by Vessel Strike Avoidance and Injured/Dead Protected Species Reporting Notices to Lessees and Operat ors (BSEE; NTL 2012-JOINT-G01).

Oil spills may affect cetaceans. Oil spills may potentially cause sublethal effects and death to marine mammals. Additionally, oil spill resp onse activities may increase vessel traffic in the area, adding to changes in marine mammal behavior and distribution. The effect of oil dispersants on marine mammals is highly debated, causing results to be inconclusive. While an oil spill is improbable, adverse impacts to marine mammals are possible. Oil spill response planning and the habitat protection requirements of the Oil Pollution Act of 1990 (Environmental Protection Agency [EPA]) should mitigate these threats. Eni US Operating Co. Inc.’s Spill Response Plan will cover activities proposed in this DOCD.

The net result of any disturbance depends on the numbers of cetaceans affected, the ecological importance of the disturbed area(s), environmental and biological parameters influencing an animal’s sensitivity to disturbance and stress, and various other factors (Geraci and St. Aubin 1980).

There are no other IPFs (including physical disturbances to the seafloor and wastes sent to shore for treatment or disposal) from the proposed activities that could impact marine

mammals.EIA – GC298

MAY 2014 8. Sea Turtles Potential IPFs that could cause impacts to sea turtles from the proposed activities of this DOCD include emissions, effluents, discarded trash and debris, and accidents.

Endangered or threatened sea turtle species that occur in the Gulf of Mexico are Kemp’s Ridley Turtle ( Lepidochelys kempii ), Green Turtle ( Chelonia mydas ), Hawksbill Turtle ( Eretmochelys imbricate ), Leatherback Turtle ( Demochelys coriacea ), and Loggerhead Turtle ( Caretta caretta ) (www.fws.gov, last accessed April 2013).

Emissions: Brightly lit platforms and noise from drilling activities may affect sea turtle behavior temporarily and without lethal effects.

Effluents: Contaminants in waste discharge and drilling muds might indirectly affect sea turtles via food-chain bioaccumulation, but there is uncertainty concerning the possible direct and indirect effects. Chronic sublethal stressors (e.g. stress) resulting in persistent physiological or behavioral changes and/or avoidance of impacted areas may cause declines in fecundity and survival of progeny re sulting in population declines; however, such effects on sea turtles are not expected.

Discarded Trash and Debris: Both entanglement in and digestion of debris have caused the death or serious injury of sea turtles (Schuyler et al. 2012). The limited amount of marine debris, if any, resulting from the proposed activities is not expected to substantially harm sea turtles. Eni US Operating Co. Inc. will adhere to the information and guidelines set forth by the Marine Trash and Debris Awareness and Elimination Notice to Lessees and Operators (NTL 2012-BSEE-G01).

Accidents: Collisions between OCS vessels and sea turtles within the project area are unlikely. In the case of a vessel-sea turtle collision, chronic and or acute sublethal effects may occur and stress or weaken individuals making them more susceptible to infection. Few lethal effects are expected from collisions with service vessels. Eni US Operating Co. Inc. will adhere to the information and guidelines set forth by Vessel Strike Avoidance and Injured/Dead Protected Species Reporting Notices to Lessees and Operators (BSEE; NTL 2012-JOINT-G01).

In the unlikely event of an accidental surface or subsurface oil spill, sea turtles could be adversely impacted. Oil spills and oil spill response activities are potential threats that couldhave lethal effects on turtles. Contact with oil, consumption of oil particles, and oilcontaminated prey could seriously affect indivi dual sea turtles. Oil spill response planning and the habitat protection requirements of the Oil Pollution Act of 1990 (EPA) should mitigate these threats. However, in the unlikely event of an accident, adverse impacts to sea turtles are possible. Eni US Operating Co. Inc.’s Spill Response Plan will cover activities proposed in this DOCD.

There are no other IPFs (including physical disturbances to the seafloor and wastes delivered to shore for treatment or disposal) from the proposed activities that could impact

sea turtles.EIA – GC298

MAY 2014 9. Air Quality Air emissions—particulates, sulfur oxides, nitrogen oxides, volatile organic compounds and carbon monoxide, and other compounds have been estimated for the proposed activities

and were determined to be below the BOEM exemption levels (www.boem.gov, last accessed April 2013). Accidents and blowouts may release polycyclic aromatic hydrocarbons and other chemicals, potentially causing the discharge of air pollutants. There would be a limited degree of air quality degradation in the immediate vicinity of the proposed activities; however, the emissions associated with the proposed activities are not projected to have significant effects on onshore air quality. Atmospheric conditions, emission height, emission rates, and the distance to shore are expected to contribute to dilution and dispersion of pollutants near the emission source, if pollutants are released.

There are no other IPFs (including effluents, physical disturbance of the seafloor, wastes carried to shore for treatment or disposal, and discarded trash and debris) from the proposed activities that may impact air quality.

10. Shipwreck Sites After review of IPFs (including physical disturban ces to the seafloor) resulting from activities proposed in this DOCD, there will be no adverse impacts to known or potential shipwreck

sites.

There are no shipwrecks within the Area of Potential Effect (APE). The “Deep Tow Survey, Allegheny Prospect, Blocks 297 & 298, Green Canyon Area”, Job No. 14-021-11,(Tesla Offshore, LLC), reported a total of 24 sonar targets throughout the surveyed area. Most of the targets are interpreted as isolated instances of modern debris. The single shipwreck, located in the adjacent Block 297 has been recommended for avoidance by a distance of 500 feet. Provided that the avoidance zones surrounding these targets are adhered to, construction activities should not impact this site.

There are no other IPFs (including emissions, effluents, wastes sent to shore for treatment or disposal, accidents, and discarded trash and debris) from the proposed activities that may impact shipwreck sites.

11. Pre-historic Archaeological Sites Green Canyon Area, Block 298, Well No. 7 is located in an area of high-probability for prehistoric and archaeological sites as identified in the BSEE NTL Archaeological Survey and Report Requirements (BSEE; NTL 2011-Joint-G01; Coastal Environments Inc. [CEI], 1977). After review of impact-producing factors (including physical disturbances to the seafloor) resulting from activities proposed in this DOCD, there will be no adverse impacts to known or potential shipwreck sites.EIA – GC298

MAY 2014 Please refer to the “Deep Tow Survey



### , Blocks 297 & 298, Green Canyon Area, Gulf of
Mexico. Job No. 14-021-11, April 2014 

### ( Tesla Offshore, LLC 

### ) . Water depths in the survey area exceed depths in which preserved prehistoric landforms are likely to occur; therefore, the assessment only addresses historic shipwrecks. If Eni US Operating Co. Inc. observes man-made debris indicating a shipwreck or archaeological site during lease development activities, Eni US Operating Co. Inc. will cease operations and immediately contact the BOEM Regional Supervisor of Leasing and Environment.

Vicinity of Offshore Location

1. Essential Fish Habitat Potential IPFs affecting essential fish habitat from the proposed activities of this DOCD include physical disturbances to the seafloor, effluents, and accidents.

Physical disturbance to the seafloor: The live bottom low relief stipulation, the live bottom pinnacle trend stipulation, and the Eastern Gulf live bottoms stipulation (BOEM, NTL 2009-G39) prevents most of the potential impacts on live-bottom communities and essential fish habitat from bottom disturbing activities (anchoring, structure emplacement, and removal).

Effluents: The live bottom low relief stipulation, the live bottom pinnacle trend stipulation,and the Eastern Gulf live bottoms stipulation prevents most of the potential impacts on livebottom communities and essential fish habitat 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 National Pollutant Discharge Elimination System (NPDES; EPA 1972) permit, minimizing significant biological or ecological effects. Operational discharges are not expected to cause significant adverse impacts to essential fish habitat.

Accidents: In the unlikely event of an accidental surface or subsurface oil spill, the potential exists for detrimental effects to essential fish habitat. The following discussion of potential impacts to marine mammals is summarized from the Final Environmental Impact Statement (USDOI, MMS, 2002). Should a spill occur in the area of adult finfish or shellfish, the effects will likely be sublethal and the extent of the damage would be dependent on the ability of the adult fishes and shellfishes to avoid a spill, to metabolize polycyclic aromatic hydrocarbons, and to excrete both metabolites and parent compounds. In the unlikely event of an accident, adverse impacts to essential fish habitats are possible. Eni US Operating Co. Inc.’s Spill Response Plan will cover activities proposed in this DOCD.

There are no other IPFs (including emissions, wastes sent to shore for treatment or disposal, and discarded trash and debris) from the proposed activities that will impact

essential fish habitat.EIA – GC298

MAY 2014 2. Marine & Pelagic Birds Potential IPFs that may impact marine and pelagic birds from the proposed activities of this DOCD include emissions, accidents, and discarded trash and debris.

Emissions: Emissions of pollutants into the atmosphere from the proposed activities are

below concentrations estimated to cause har m to marine and pelagic birds (www.boem.gov, last accessed April 2013).

Accidents: Oil spills pose the greatest potential impacts to marine birds. Heavy oiling of birds generally results in mortality. If physical oiling of birds occurs, some degree of both acute and chronic physiological stress associated with direct and secondary uptake of oil is expected. Lightly oiled birds can sustain tissues and organ damage from oil ingested or inhaled. Stress and shock enhance the effects of exposure and poisoning. Low levels of oil may stress birds by interfering with food detection, feeding impulses, predator avoidance, territory definition, homing of migratory species, susceptibility to physiological disorders, disease resistance, growth rates, reproduction, and respiration. Reproductive success is potentially affected with oil exposure. Indirect effects occur by disrupting nesting habitat and displacement of individuals, breeding pairs, or populations to less favorable habitats. Dispersant used in spill cleanup activity may have toxic effects similar to oil.

Green Canyon Area, Block 298, Well No. 7 is located approximately 96 miles from the coast of Terrebonne Parish, Louisiana. Because of the distance from shore and the available oil spill response capabilities, no adverse impacts to the marine and pelagic bird population are anticipated as a result of the proposed activities. In the unlikely event of an accident, adverse impacts to marine and pelagic birds are possible. Eni US Operating Co. Inc.’s Spill Response Plan will cover activities proposed in this DOCD.

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. The limited amount of marine debris, if any, resulting from the proposed activities is not expected to subst antially harm marine and pelagic birds. Eni US Operating Co. Inc. will adhere to the information and guidelines set forth by the Marine

Trash and Debris Awareness and Elimination Notice to Lessees and Operators (NTL 2012- BSEE-G01).

The majority of effects on endangered/threatened and non-endangered/non-threatened marine birds are expected to be sublethal: behavioral effects, sublethal exposure to or intake of OCS-related contaminants or discharge debris, temporary disturbance, and displacement of localized groups from im pacted habitats. Chronic sublethal stress, however, is often undetectable in birds. As a result of stress, individuals may become weak, facilitating infection and disease; then migratory species may not have the strength to reach their destination. No significant habitat impacts are expected to occur directly from routine activities resulting from proposed actions under this DOCD.

There are no other IPFs (including physical disturbance to the seafloor, effluents, and wastes sent to shore for treatment or disposal ) from the proposed activities that could impact marine and pelagic birds.EIA – GC298

MAY 2014 3. Public Health & Safety After review of impact-producing factors (including an accidental H 2 S release) resulting from activities proposed in this DOCD, there is no potential for accidental release of a dangerous

substance such as H 2 S gases. As stated in the H 2 S Information Section of the Plan, there is sufficient evidence from the drilling/production of previous wells to deem the proposed activity area as an area that is “H 2 S absent.”

Coastal and Onshore

1. Beaches Potential IPFs that could cause impacts to beaches from the proposed activities of this

DOCD include accidents and discarded trash and debris.

Accidents: Green Canyon Area, Block 298, Well No. 7 is located approximately 96 miles from the coast of Terrebonne Parish, Louisiana. An accidental oil spill from the proposed activities would have a -/1/2 percent chance (based on 3, 10, or 30 days from the date of the spill) of causing impacts to the beaches at the coast line of Terrebonne Parish, Louisiana; a -/ -/ 1 percent (based on 3, 10, or 30 days from the date of the spill) of causing impacts to the beaches at the coast line of Lafourche Parish, Louisiana; and a -/ 1/ 4 chance (based on 3, 10, or 30 days from the date of the spill) of causing impacts to the beaches at the coast line of Plaquemines Parish, Louisiana. Because of the distance from shore of the proposed activities and the available oil spill response capabilities, no adverse impacts to beaches are anticipated. In the unlikely event of an accident, adverse impacts to beaches are possible. Eni US Operating Co. Inc.’s Spill Response Plan will cover activities proposed in this DOCD.

Discarded trash and debris: Trash on the beach is recognized as a major threat to the enjoyment and use of beaches. The limited amount of marine debris, if any, resulting from the proposed activities is not expected to significantly affect beaches. Eni US Operating Co. Inc. will adhere to the information and guidelines set forth by the Marine Trash and Debris

Awareness and EliminationNotice to Lessees and Operators (BSEE; NTL 2012-BSEEG01).

There are no other IPFs (including physical disturbance to the seafloor, effluents, emissions, and wastes sent to shore for treatment or disposal) from the proposed activities that could impact beaches.

2. Wetlands Potential IPFs that could cause deleterious effects to wetlands from the proposed activities

of this DOCD include accidents.

Accidents: : Green Canyon Area, Block 298, Well No. 7 is located approximately 96 miles from the coast of Terrebonne Parish, Louisiana. An accidental oil spill from the proposed activities would have a -/1/2 percent chance (based on 3, 10, or 30 days from the date of the spill) of causing impacts to the wetlands at the coast line of Terrebonne Parish, Louisiana; a -/ -/ 1 percent (based on 3, 10, or 30 days from the date of the spill) of affecting wetlands at the coast line of Lafourche Parish, Louisiana; and a -/ 1/ 4 chance (based on 3, 10, or 30 days from the date of the spill) affecting wetlands at the coast line of Plaquemines Parish,EIA – GC298

MAY 2014 Louisiana. Because of the distance from shore of the proposed activities and the available oil spill response capabilities, no adverse impacts to the wetlands are anticipated. However, in the unlikely event of an accident, adverse effects to wetlands are possible. Eni US Operating Co. Inc.’s Spill Response Plan w ill cover activities proposed in this DOCD.

There are no other IPFs (including physical disturbance to the seafloor, effluents, emissions, wastes sent to shore for treatment or disposal, and discarded trash and debris) from the proposed activities that could impact wetlands.

3. Shore & Coastal Nesting Birds Potential IPFs that could affect shore and coastal nesting bird species from the proposed

activities of this DOCD include accidents and discarded trash and debris.

Accidents: Oil spills pose the greatest potential impacts to shore birds and coastal nesting birds. Heavy oiling of birds generally results in mortality. If physical oiling of birds occurs, some degree of both acute and chronic physiological stress associated with direct and secondary uptake of oil is expected. Lightly oiled birds can sustain tissues and organ damage from oil ingested or inhaled. Stress and shock enhance the effects of exposure and poisoning. Low levels of oil may stress birds by interfering with food detection, feeding impulses, predator avoidance, territory definition, homing of migratory species, susceptibility to physiological disorders, disease resistance, growth rates, reproduction, and respiration. Reproductive success is potentially affected with oil exposure. Indirect effects occur by disrupting nesting habitat and displacement of individuals, breeding pairs, or populations to less favorable habitats. Dispersant used in spill cleanup activity may have toxic effects similar to oil. No significant habitat impacts are expected to occur directly from routine activities resulting from a proposed action. Se condary impacts to coastal habitats will occur over the long-term and may ultimately displace species from traditional sites to alternative sites. In the unlikely event of an accident, adverse impacts to marine and pelagic birds are possible. Eni US Operating Co. Inc.’s Spill Response Plan will cover activities proposed in

DOCD.

Green Canyon Area, Block 298, Well No. 7 is located approximately 96 miles from the coast of Terrebonne Parish, Louisiana. An accidental oil spill from the proposed activities would have a -/1/2 percent chance (based on 3, 10, or 30 days from the date of the spill) of causing impacts to the shore birds and coastal nesting birds that occur onshore in Terrebonne Parish, Louisiana; a -/ -/ 1 percent chance (based on 3, 10, or 30 days from the date of the spill) of causing impacts to the shore birds and coastal nesting birds that occur onshore in Lafourche Parish, Louisiana; and a -/ 1/ 4 chance (based on 3, 10, or 30 days from the date of the spill) of causing impacts to shore birds and coastal nesting birds that occur onshore in Plaquemines Parish, Louisiana. Because of the distance from shore of the proposed activities and the available oil spill response capabilities, no adverse impacts to the shore birds and coastal nesting birds are anticipated. In the unlikely event of an accident, adverse impacts to shore and coastal nesting birds are possible. Eni US Operating Co. Inc.’s Spill Response Plan w ill cover activities proposed in this DOCD.

Discarded trash and debris: If present, shore birds and coastal nesting birds may become entangled and snared in discarded trash and debris or ingest small plastic debris causing permanent injuries and death. The limited amount of marine debris, if any, resulting from theEIA – GC298

MAY 2014 proposed activities is not expected to cause significant harm marine and pelagic birds Eni US Operating Co. Inc. will adhere to the information and guidelines set forth by the Marine

Trash and Debris Awareness and Elimination Notice to Lessees and Operators (NTL 2012- BSEE-G01).

There are no other IPFs (including physical disturbance to the seafloor, effluents, emissions, and wastes sent to shore for treatment or disposal) from the proposed activities that could impact shore and coastal nesting birds.

4. Coastal Wildlife Refuges Potential IPFs that could cause impacts to coastal wildlife refuges from the proposed

activities of this DOCD include accidents.

Accidents: Green Canyon Area, Block 298, Well No. 7 is located 96 miles from the coast of Terrebonne Parish, Louisiana. An accidental oil spill from the proposed activities would have a -/1/2 percent chance (based on 3, 10, or 30 days from the date of the spill) of causing impacts to the coastal wildlife refuges that occur onshore in Terrebonne Parish, Louisiana; a -/-/1 percent chance (based on 3, 10, or 30 days from the date of the spill) of causing impacts to the coastal wildlife refuges that occur onshore in Lafourche Parish, Louisiana; and a -/1/4 percent chance (based on 3, 10, or 30 days from the date of the spill) of causing impacts to the coastal wildlife refuges that occur onshore in Plaquemines Parish, Louisiana. Because of the distance from this refuge of the proposed activities and the available oil spill response capabilities, no adverse impacts to coastal wildlife refuges are anticipated. In the unlikely event of an accident, adverse impacts to coastal wildlife refuges are possible. Eni US Operating Co. Inc.’s Spill Response Plan will cover activities proposed

in this DOCD.

There are no other IPFs (including physical disturbance to the seafloor, effluents, emissions, wastes sent to shore for treatment or disposal, and discarded trash and debris) from the proposed activities that could impact coastal wildlife refuges.

In regards to Louisiana resources, an accidental oil spill from the proposed activities would have the following probabilities (based on 3, 10, or 30 days from the date of the spill) of causing impacts to coastal wildlife refuges:

 State of Louisiana WMA and Game Preserve in Vermilion Parish ( -/ -/ 2)

 Paul J. Rainey Wildlife Sanctuary in Vermilion Parish ( -/ -/ 2)

 Rockefeller State Wildlife Refuge in Vermilion Parish ( -/ -/ 2) Cameron Parish (-/ -/ 5)

 Atchafalaya WMA in Terrebonne Parish ( -/ 1/2)

 Breton National Wildlife Refuge in Terrebonne Parish ( -/1/2)

 Pass a Loutre WMA in Terrebonne Parish ( -/1/2)

 Delta National Wildlife Refuge in Terrebonne Parish (-/1/2)

 Wisner WMA in Lafourche Parish ( -/ -/ 1)

5. Wilderness Areas Potential IPF’s that could cause impacts to w ilderness areas from the proposed activities of

this DOCD include accidents.EIA – GC298

MAY 2014 Accidents : Green Canyon Area, Block 298, Well No. 7 is located approximately 96 miles from the coast of Terrebonne Parish, Louisiana. Due to the distance from shore and the available oil spill response capabilities, no adverse impacts to wilderness areas are anticipated as a result of the proposed activities. However, in the unlikely event of an accident, adverse impacts to wilderness areas are possible. Eni US Operating Co. Inc.’s Spill Response Plan will cover activities proposed in this DOCD.

Texas has five areas designated by Congress as Wilderness Areas, namely the Big Slough Wilderness Area, Indian Mounds Wilderness Area, Little Lake Creek Wilderness Area, Turkey Hill Wilderness Area, and the Upland Island Wilderness Area, none of which are located along the coastal region of Texas; and the only wilderness area located along the coastal region of Louisiana is the Breton Wilderness Area, located on the eastern side of the Mississippi River, approximately 140 miles fr om Green Canyon Area, Block 298. Due to the distance from shore and the available oil spill response capabilities, no adverse impacts to wilderness areas are anticipated as a result of the proposed activities.

There are no other IPF’s (including physical disturbance to the seafloor, effluents, emissions, wastes sent to shore for treatment or disposal, and discarded trash and debris) from the proposed activities that could impact wilderness areas.

(C) IMPACTS ON PROPOSED ACTIVITIES

A Wellsite Clearance Letter was prepared for the proposed surface location. The surface location was evaluated for any seafloor and subsurface geological and manmade features and conditions that may adversely affect operations. Referencing Fugro GeoConsulting, Inc., Wellsite Clearance Letter, Report No. 27.2014-2706-GC298-7, dated April 27, 2014; infrastructure is located within 2,000 ft of the proposed wellsite. Eni pipeline segments #13413, #16150, and #16149 are located 1,275 ft west-northwest, 1,300 ft east, and 1,360 ft west-southwest, respectively, from the proposed wellsite.

While no impacts are expected from the propos ed activities on site-specific environmental conditions it is recommended that an ROV be used to inspect the seafloor at the proposed wellsite immediately before spud-in to confirm that no seafloor obstructions have appeared since the archaeological survey data was acquired.

(D) ENVIRONMENTAL HAZARDS

During the hurricane season—June through November of each year—the Gulf of Mexico is potentially impacted by an average of ten tropical storms (39-73 mph winds), of which six may become hurricanes (>74 mph winds). Because of the proposed location in the Gulf of Mexico, Green Canyon Area, Block 298, Well No. 7 may experience hurricane and tropical 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 material (including polycyclic aromatic hydrocarbons). Additionally, theEIA – GC298

MAY 2014 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:

Drilling and Completion

 Secure well

 Secure drilling rig/platform

 Evacuate personnel

Alternatives

No alternatives to the proposed activities were considered to reduce environmental impacts.

1. Mitigation Measures No mitigation measures other than those required by regulation will be employed to avoid, diminish, or eliminated potential impacts on environmental resources.

2. 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.

3. Preparer Wendy Fiaschetti Regulatory Specialist wfiaschetti@fugro.com

337-268-3152 John Chance Land Surveys, Inc.

200 Dulles Drive Lafayette, Louisiana 70506

4. References NOAA. National Oceanic and Atmospheric Association. 2010. Deep sea subsurface oil assessment. NOAA, National Incident Comma nd, Unity of Effort. www.noaa.gov, last accessed 19 September 2012. Schmahl GP, Hickerson EL, Nuttall MF. 2012. Science-based design of coral protected areas in the Gulf of Mexico. Proceedings of the 12 th Internation Coral Reef Symposium. 9-12 July 2012. Cairns, Australia. Schuyler Q, Hardesty BD, Wilcox C, Townsend K. 2012. To eat or not to eat? Debris selectivity by marine turtles. PLoS ONE 7:1-9. USDOI. U.S. Department of the Interior, Fish and Wildlife Service Endangered and threatened species of the southeastern United States. Region IV, Atlanta, Georgia. USDOI, MMS. U.S. Department of the Interior, Minerals Management Service. 2002. Gulf of Mexico OCS oil and gas lease sales: 2003-2007; Central Planning Area Sales 185, 190, 194, and 201; Western Planning Area Sales 187, 192, 196, and 200—final environmental impact statement; Volumes I and II. U.S. Dept. of the Interior, Mineral Management Service, Gulf of Mexico OCS Region, New Orleans,EIA – GC298

MAY 2014 LA. OCS EIS/EA MMS 2002-052. Williams R, Ashe E, O’Hara PD. 2011. Marine mammals and debris in coastal waters of British Columbia, Canada. Marine Pollution Bulletin 62:1303-1316. Wilson B, Batty RS, Daunt F, Carter C. 2007. Collision risks between marine renewable energy devices and mammals, fish and diving birds. Report to the Scottish

Executive. Scottish Association for Ma rine Science, Oban, Scotland, PA37 1QA. Wright AJ and Weilgart L. 2011. Assessing cumulative impacts of underwater noise with other stressors on marine mammals. Acoustical Society of America 129:2394-2394. Fugro GeoConsulting, Inc. Wellsite Clearance Letter, Proposed Wellsite GC 298, Well No. 007, Green Canyon Area, Block 298, Gulf of Mexico. Report No. 27-2014-2706- GC298-7, Apirl 27, 2014. Fugro GeoConsulting, Inc., Shallow Hazard Assessment, Allegheny Prospect, Block 298 (OCS-G-08010), Green Canyon Area, Gulf of Mexico. Report No. 27.2014-2706,
March 24, 2014. Tesla Offshore, LLC, Deep Tow Survey, All egheny Prospect, Blocks 297 & 298, Green Canyon Area (OCS-G-08876 & 08010), Gulf of Mexico. Job No. 14-021-11, April

2014.Eni US Operating Co. Inc. Page 

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Supplemental DOCD May 19, 2014 Green Canyon Block 298 (OCS-G 08010) Public Information 

### SECTION R

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 DOCD as well as any discussions of the target objectives, geologic or geophysical data, and any interpreted geology.

(b) Bibliography Not applicable.