[BSEE) RECEIVED MA R 13 2018RP0176-83 is 8.4 to 7.4; use 7.9. 1= 127 ft L= 38,200 x 92 14.000 x 127 ft x 7.9 252.2 years LIFE EXPECTANCY 17460-PLEN-TP-0003, Rl - 14in Oil Pipeline

March 8,2018

Baroau of Saffilf flnd EavirsiESdifli Umm\ [BSEE)

R E C E I V E D MAR 13 2018

Office of Field Operations Pipeline Section

U. S. Department of the Interior Bureau of Safety and Environmental Enforcement 1201 Elmwood Park Boulevard New Orleans, Louisiana 70123-2394

Arena Offshore, LP

4200 Research Forest Dr.

Suite 230

The Woodlands, TX 77381

281-681-9501

281-681-9502 Fax

Attention: Phillip Smith Pipeline Section

RE: Supplement and Amendment to Application Dated December 12, 2017 for Modification to Existing Right-of-Way Easement Associated with Abandoned-In-Place 14-Inch Right-of-Way Pipeline (ROW OCS-G 29378/Segment No. 19785) Originating at Plugged End in Eugene Island Block 297 and Terminating at a Plugged End in Ship Shoal Block 28, OCS Federal Waters, Gulf of Mexico, Offshore Louisiana

Ms. Smith:

The following information is provided as further support of the referenced application, and our subsequent telephone discussion and email correspondence:

• Arena's plan to remediate line restriction: The flow test conducted by Arena in 2017 did show a significant pressure drop over the length of the 14" pipeline. This flow test was conducted by pumping through 300' of 2.5" hose on one end connected to a 14" flange that was subsea. The flow was received at the other end through another 250' of 2" hose connected to a 14" flange subsea. When this configuration is modeled in PIPESIM assuming no restriction in the flow line, the results are almost identical to what was recorded on the flow test chart in the field. Our conclusion is that this pressure drop was later erroneously attributed to a restricted/obstructed pipeline using a very rudimentary orifice calculation. This analysis did not take into account the two hoses on either end which caused this significant pressure drop. The chart below clearly shows that the hoses are where the majority of the pressure differential is occurring. In conclusion. Arena does not believe there is a pig stuck in this line or that it is restricted in any way.

U.S. Department of the Interior Bureau of Safety and Environmental Enforcement March 8, 2018 Page 2

• Proposed testing of new line and riser piping to be installed: The piping will be pre-tested onshore for 4 hours at 1500#.

• Assignment of segment number(s) for entire length of existing line pipe: As reflected in the application. Arena is requesting reactivation of a portion of the line pipe and requesting a 5-year inactive status to the remaining portion ofthe existing pipeline for future utility. As we discussed in our earlier conference call, we have since elected to re-route production from our existing Eugene Island Block 341 A Platform which will include installing new departing line pipe to the south end of the existing 14-inch pipeline's capped end in Eugene Island Block 297. We have completed running the Pipeline Pre-Lay Survey and will be submitting a separate application within the next few weeks will provide for a new 14-inch pipeline originating at Eugene Island Block 341 A Platform and terminating at the existing capped end of the 14-inch pipeline (Segment No. 19785) in Eugene Island Block 297. As such, we would like to maintain the existing Segment No. 19785 as one segment number.

Arena has elected to not install the subsea pig launcher; as such we are requesting removal of the Key Plan at Subsea Tie In Drawing No. 0912 included in our original application.

Correction to wall thickness of existing line pipeline: Attached are the amended documents in support of this correction:

Document Name

Drawing or Page

No. Rev. No.

Document Date

New Pipeline Design Data 1-8 1 3//2018

Maximum Spill Volume Calculations (Worst-Case Discharge) 1-2 1 3/6/2018

Pipeline Safety Flow Diagram 4301 2 3/6/2018

Please continue to direct any questions or requests for additional information to Connie Goers at 281.210.3123 or [email protected].

U.S. Department of the Interior Bureau of Safety and Environmental Enforcement March 8, 2018 Page 3

Sincerely,

Arena Offshore, LP By: Arena Offshore GP, LLC its Sole General Partner

Michael E. McCauley Operations General Manager

MEM:CJG Enclosures

^*£TRATEGY

PIPELINE PERMIT & CALCULATIONS - KAQ-1030,14" OIL PIPELINE JUMPER

Client: Arena Offshore, LP

REV DATE ISSUED FOR By Chk'd App'd Client Project: Rosefield Pipeline

0 12/5/17 MOC: SS28A-2017-11-28 MDS CJM CJM VN Job No: 17460

1 3/6/18 MOC:SS28A-2017-11-28 MDS CJM CJM RC By/Date: MDS /11-28-17

Doc No: 17460-PLEN-TP-0003

Spec No: —

Page: 1 of 8

RIGHT-OF-WAY PIPELINE MODIFICATION PERMIT APPLICATION

PROPOSED 14" OIL PIPELINE JUMPER

FROM

ARENA OFFSHORE, LP SHIP SHOAL BLOCK 28, EXISTING FOURTEEN-INCH PIPELINE (SEGMENT NO. 19785)

TO

ARENA OFFSHORE, LP SHIP SHOAL BLOCK 28, PLATFORM "A"

OCS-G 01504

GULF of MEXICO FEDERAL WATERS, OFFSHORE LOUISIANA

Submitted By: ARENA OFFSHORE, LP

MARCH 2018

17460-PLEN-TP-0003, R1 - 14in Oil Pipeline Modification Permit Strategy Engineering and Consulting, LLC.

iTECY PIPELINE PERMIT & CALCULATIONS - KAQ-1030,14" OIL PIPELINE

JUMPER Client:

Arena Offshore. LP

Project:

Rosefield Pipeline

Job No: Rev: Date: Issued For: Spec No: Doc No: Page:

17460 1 3-6 18 MOC SS28A-2017-11-28 — 17460-PLEN-TP-0003 2 of 8

GENERAL INFORMATION

Pipeline Tag No.

Pipeline Name

Pipeline Size

Pipeline Length, ft

Water Depth, ft

KAQ-1030

i r OIL PIPELINE JUMPER

Fourteen-inch

126.00

12

Design Pressure, Psig

Design Temperature, °F

Operating Pressure, Psig

Operating Temperature, °F

1,480

100

400

100

Flowrates:

Gas, mmscfd

Oil/Condensate, bpd

Water, bpd

0

3,200

0

Specific Gravities:

Specific Gravity-Gas

Specific Gravity-OII/Condensate

Specific Gravity-Water

0 65

0 83

1 05

(I) DESCRIPTION OF THE CATHODIC PROTECTION SYSTEM

Pipeline Anodes with the following characteristics will be used for cathodic protection of the pipeline.

Anode Type:

Size:

Weight (net):

Number:

Spacing (Max):

Life Expectancy:

Calculations

Number of Anodes Required (N)

N _ Length of Route (ft)

Anode Spacing (Max)

126 N=

500 N= 1

Anode Intervai (i)

!_ Length of Route (ft)

Number of Anodes

126 1=

1

Tapered, Semi-Cylindrical Aluminum Bracelet, Galvalum

Fourteen-inch

92

1

500

252.2 years

Life Expectancy (L)

£ _ 3 . 8 2 x i a ' x W 0

DxIxR Where:

L = Life of Cathodic Protection System (years)

W° = Weight of unit anodes (Ibs)

D = Outside Diameter of pipe (inches)

i = Interval length of pipe (ft)/total no. of anodes

R = Rate of consumption (lbs/amp«year) - The value

of R for Galvalum ill (aluminum-zinc-indium) as

obtained from Table l.B of NACE Standard

RP0176-83 is 8.4 to 7.4; use 7.9. 1= 127 ft L= 38,200 x 92

14.000 x 127 ft x 7.9

252.2 years LIFE EXPECTANCY

17460-PLEN-TP-0003, Rl - 14in Oil Pipeline Modification Pemit Strategy Engineering and Consulting, LLC,

iTECT PIPELINE PERMIT & CALCULATIONS - KAQ-1030,14" OIL PIPELINE

JUMPER e Client:

Arena Offshore. LP

Project:

Rosefield Pipeline

Job No: Rev: Date:

17460 1 3/6/18

Issued For:

MOC: SS2BA-2017-11-28

Spec No: Doc No:

1746a-PLEN-TP-0003

Page:

3 of 8

(II) DESCRIPTION OF EXTERNAL PIPE COATING SYSTEM

Line Pipe:

Coating Type: Fusion bonded epoxy coating, 14-16 mils thick

Risers:

Above Splash Zone:

Splash Zone:

Below Splash Zone:

Three Coat Offshore Paint System

Neoprene rubber base coating (Splashtron), V4" thick, 20 feet long, vulcanized to pipe

Fusion bonded epoxy coating, 14-16 mils thick

(ill) DESCRIPTION OF INTERNAL PROTECTIVE MEASURES

No internal coating is provided. The analysis of the transported products will be monitored and preventive

measures such as inhibiting will be employed as necessary.

(iv) SPECIFIC GRAVITY OF EMPTY PIPELINE PIPE

Specific gravity of 14.000" x 0.438" wt, empty pipe = 0.93

Weight of Bare Pipe In air (W p )

W p = Volume of steel x Density of steel

12 ft3

1728 in 3 W0

n(Do2-Di2)

n (14.000A2-13.124A2) Wp= x

4 Wp= 63.47 lb/ft3

Weight of Pipe Coating (Wc)

12

1728 x 489.6

Weight of Coated Pipe In air (W)

w= wp + wc

W= 63.47 + 0.00 W= 63.47 lb/ft3

Weight of Displaced Seawater (W.) w s = Volume of sea water x Density of sea water

Ws = n(Dof 12 ft3

_ n((Do+2Tc)2-Do2) W c " x

12 ft3

1728 in J

Wc = •n ((0.00+2(0.00))'12 - O.Oi 12 ft3

1728 in'' x 0.0

_ K (14.000)^2 f r 5 — X

4 W s = 68.42 lb/ft3

1728 in 12

1728

— x Pwalor

X64

W c = 0.00 lb/ft3

Specific Gravity (SG)

S G _ Weight of Pipe in Air

SG=

Weight of Displaced Sea Water

63.47 lb/ft3

68.42 lb/ft3

SG= 0.93

PIPE SPECIFIC GRAVITY

(v) MAXIMUM SOURCE PRESSURE (MSP)

MSP (psig): = < 905

Based on: Input from pipeline pumps on departing platform (EI-2521)

Protection: Pipeline will be protected by PSHL's and PSVs installed on input sources.

17460-PLEN-TP-0003, Rl - 14in Oil Pipeline Modification Permit Strategy Engineering and Consulting, LLC.


Client:

Arena Offshore, LP

Project:

Rosefield Pipeline

Job No: Rev: Date:

17460 1 3/6/18

Issued For:

MOC:SS28A-2ai7-11-28

Spec No: Doc No:

17460-PLEN-TP-0003

Page:

4 of f

(vi) MAXIMUM ALLOWABLE OPERATING PRESSURE (MAOP) AND CALCULATIONS

Pipeline MAOP:

Limiting Component:

1,000 psig @ 100 0F Existing tie in pipeline (Segment No. 19785) MAOP.

Design Pressure & Component Summary

Components Material or Ratina Nominal Size

Line Pipe API 5L x52 14.000" x 0.438" wt 2,343 psig Line Pipe Bends API 5L x52 14.000" x 0.438" wt 2,155 psig

Riser Pipe API 5L x52 14.000" x 0.438" wt 1,952 psig

Riser Pipe Bends API 5L x52 14.000" x 0.438" wt 1,796 psig

Flanges ANSI 900 14" Nominal 2,220 psig

Existing Line Pipe API 5L x52 14.000" x 0.375" wt 2,006 psig

Subsea Valves ANSI 900 14" Nominal 2,220 psig

Formulas

Internal Design Pressure

From: Title 30 CFR, Chapter II, Subchapter B, Part 250, Subpart J, §250.1002

p _2(S)(t) (FETS) Do

Where: P = Internal design pressure in pounds per square inch (psig).

S = Specified minimum yield strength, in psi, will be stipulated in the specification under which the pipe will be

purchased from the manufacturer. S=35,000 psi for API 5L Gr. B

D = Nominal outside diameter of the pipe in inches,

t = Nominal wall thickness of the pipe in inches.

F = Construction design factor of 0.72 for submerged components and 0.60 for riser pipe.

E = Longitudinal joint factor, 1.00 for API 5L seamless (SMLS) and electric resistance welded (ERW) pipe as

obtained from Table 841.115A of ANSI B31.8.

T = Temperature derating factor, 1.00 for temperatures 250°F or less as obtained from Table 841.116A of ANSI

B31.8.

Pipe Thinning on the Outside Bend Radius of Hot Bends:

From: Intemational Pipe Association's Voluntary Standard for Induction Bending of Pipe (IPA-VIBS-86)

R (D) of Bend=

Dn

Where: R = Center Line Radius of Bend, in inches.

Dn = Nominal pipe Diameter, in inches.

Anticipated wall thinning, in percent, is obtained from Table 1-1 of IPA-VIBS.

17460-PLEN-TP-0003, Rl - 14in Oil Pipeline Modification Pemit Strategy Engineering and Consulting, LLC.


Client:

Arena Offshore, LP

Project:

Rosefield Pipeline

Job No:

17460

Rev;

1

Date:

3/6/18

Issued For:

MOC:SS28A-2D17-11-2a

Spec No: Doc No:

17460-PLEN-TP-0003

Page:

5 of 8

(vi) MAXIMUM ALLOWABLE OPERATING PRESSURE (MAOP) AND CALCULATIONS - Cont'd

Calculations

Line Pipe internai Design Pressure

Nominal Pipe Size (in): 14

Pipe Outside Diameter (Do) (in) 14

Pipe Schedule Sch. 40

Pipe Inside Diameter (Di) (in) 13.124

Wall Thickness (t) (in) 0.438

Material: API 5L x52

Minimum Yield Strength (S) (psi) 52,000

Construction Type - Line Pipe: A

Construction Factor (F): 0.72

Temperature Selection: 1

Temperature Derating Factor (T): 1.00

Longitudinal Joint Factor (E): 1.00

Line Pipe Bend internai Design Pressure



Pipe Schedule Sch. 40





Construction Type - Line Pipe: A




(D) of Bend (R/D): 5

Wall Thinning (%): 8

P=-

P=-

2(S)(t)(FET)

Do

2(52,000)(0.438)(0.72)(1.00)(1.00)

14.000

P= 2,343 psig

LINE PIPE

W t bendf W. i ) - (thinning % x t^,.,),

W . b , ^ 0.438-(8/100)(0.438)

W t bendf 0 - 4 0 3 i n -

p . 2(S)(t)(FET)

Do

r _ 2(52,000)(0.403)(0.72)(1.00)(1.00)

14.000

P 2,155 psig

LINE PIPE BENDS

Riser Pipe internai Design Pressure



Pipe Schedule • Sch. 40





Construction Type - Line Pipe: E


Temperature Selection: 1



Q There is no Riser

P=- 2(S)(t)(FET)

Do

2(52,000)(0.438)(0.60)(1.00)(1.00)

14.000

P= 1,952 psig

RISER PIPE


P I P E L I N E P E R M I T & C A L C U L A T I O N S - KAQ-1030 ,14" O IL P I P E L I N E

J U M P E R

Client:

Arena Offshore, LP

Project:

Rosefield Pipeline

Job No: Rev: Date:

17460 1 3/6/18

Issued For:

MOC: SS28A-2017-11-28

Spec No: Doc No:

17460-PLEN-TP-00a3

Page:

6 of (

(vi) MAXIMUM ALLOWABLE OPERATING PRESSURE (MAOP) AND CALCULATIONS - Cont'd

Riser Pipe Bend Internal Design Pressure

Nominal Pipe Size (in):

Pipe Outside Diameter (Do) (in)

Pipe Schedule

Pipe Inside Diameter (Di) (in)

Wall Thickness (t) (in)

Material:

Minimum Yield Strength (S) (psi)

Construction Type - Line Pipe:

Construction Factor (F):

Temperature Derating Factor (T):

Longitudinal Joint Factor (E):

(D) of Bend (R/D):

Wall Thinning (%):

Exist ing Line Pipe

Nominal Pipe Size (in):

Pipe Outside Diameter (Do) (in)

Pipe Schedule

Pipe Inside Diameter (Di) (in)

Wall Thickness (t) (in)

Material:

Minimum Yield Strength (S) (psi)

Construction Type - Line Pipe;

Construction Factor (F):

Temperature Selection:

Temperature Derating Factor (T):

Longitudinal Joint Factor (E):

Flanges

ANSI Class

From: ANSI B16.5, Table 2

Temperature =

Flange Sizes

Flange Sizes, Additional

Subsea Valves

ANSI Class

From: API 6D, Table 2.1

Valve Size

14

14

Sch. 40

13.124

0.438

API 5L x52

52,000

E

0 60

1.00

1.00

5

s

W t bend)- in i t ia l ] " ( t h i n n i n g % X t^mtia,,,

W . bendf 0.438-(8/100)(0.438)

W t bendf 0.403 in.

2(S)(t)(FET)

Do

2(52,000K0.403)(0.60)(1 .OOKI .00)

14.000

1,796 psig

RISER PIPE BENDS

• Tliere is no Subsea Assembly

14

14

Sch. 30

13,250

0.375

API 5L x52

52.000

A

0.72

1

1.00

1.00

ANSI 900

-2010 1 0 0 ^

14

ANSI 900

P=-

P=-

2(S)(t)(FET)

Do

2(52,000)(0.375H0.72)(1 00)(1 00)

14.000

P= 2,006 psig

EXISTING LINE PIPE

2,220 psig

FLANGES

2,220 psig

SUBSEA VALVES

1' ;

17460-PLEN-TP-0003, R l - 14in Oil Pipeline Modification Permit Strategy Engineering and Consulting, LLC.

PIPELINE PERMIT & CALCULATIONS - KAQ-1030,14" OIL PIPELINE JUMPER 0

Client:

Arena Offshore, LP

Project:

Rosefield Pipeline

J o b No:

17460

Rev:

1

Date:

3/6/18

Issued For:

MOC:SS28A-2017-11-28

Spec No: Doc No:

17460-PLEN-TP-0003

Page:

7 of 8

(vii) HYDROSTATIC TEST PRESSURE (HTP), TEST MEDIUM, AND PERIOD OF TIME

Hydrostatic test pressure for the pipeline: 1,250 psig

Test Medium:

Test Period:

Calculation

Sea Water

8 Hours

Minimum Hydrostatic Test Pressure (HTP) for the pipeline:

HTP= 1.25 x MAOP

HTP= 1.25x1,000 psig HTP= 1,250 psig

HYDRO TEST PRESSURE

Stress at Hydrotest Pressure

Where:

Limiting pipeline SMYS Component:

SMYS of Limiting Component:

Outside Diameter (Do):

Wall Thickness (t):

Riser Pipe Bends 52,000

14

0.403

S= (HTP)(Do)E

S=-

2(t) 1,250(14.000)(1.00) S= 21,712 psi

2(0.403)

Stress Ratio (SR)

f.R_ Stress at Hydrotest Pressure

SMYS Limit

SR=-21,712

52,000

SR= 42%

Conclusion

The hydrotest will be performed at a pressure that is 42% of the SMYS of the pipeline (based on the wail thickness of the 14.000-inch Riser Pipe Bends).

(viii) MAOP OF TIE-IN PIPING

The MAOP ofthe 14" Oil Pipeline (Segment No. 19785) is 1,000 PSIG.

(Ix) PROPOSED DATE FOR COMMENCING INSTALLATION AND ESTIMATED TIME FOR CONSTRUCTION

Commence Construction Date: May 2018

Estimated Construction Time: 12 days

17460-PLEN-TP-0003, Rl - 14in Oil Pipeline Modification Pemit Strategy Engineering and Consulting, LLC.

0*7 PIPELINE PERMIT & CALCULATIONS - KAQ-1030,14" OIL PIPELINE JUMPER

Client:

Arena Offshore, LP

Project:

Rosefield Pipeline

Job No: Rev: Date:

17460 1 3/6/18

Issued For:

MOC: SS28A-2017-11-28

Spec No: Doc No:

1746D-PLEN-TP-00a3

Page:

8 of 8

(x) TYPE OF PROTECTION TO THE AFFORDED CROSSING PIPELINES, SUBSEA VALVES, TAPS AND MANIFOLD ASSEMBLIES

Pipeline Burial

The proposed pipeline will be buried to a minimum depth of three feet below natural bottom.

Pipeline Crossings

The proposed pipeline does not cross any existing pipelines.

Subsea Valves, Taps, and Manifold Assemblies

The proposed subsea components (valves, taps or assemblies) will be covered to a minimum of three feet using sand bags.

Riser Protection

A riser guard will be installed on the platform to protect the proposed pipeline.

(xi) ADDITIONAL DESIGN PRECAUTIONS

Additional design precautions will not be required to enable the pipeline to withstand the effects of water currents, storm or ice scouring, soft bottoms, mudslides, earthquakes, perfafrost or other environmental factors.

17460-PLEN-TP-0003, R1 - 14in Oii Pipeline Modification Permit Strategy Engineering and Consulting, LLC.

MAXIMUM SPILL VOLUME CALCULATIONS - KAQ-1030,14" OIL PIPELINE JUMPER

Client: Arena Offshore, LP

REV DATE ISSUED FOR By Chk'd App'd Client Project: Rosefield Pipeline

0 12/6/17 MOC: SS28A-2017-11-28 MDS CJM CJM VN Job No: 17460

1 3/6/18 MOC: SS28A-2017-11-28 MDS CJM CJM RC By/Date: MDS/11-28-17

Doc No: 17460-PLEN-TC-0004

Spec No: —

Page: 1 of 2

GENERAL INFORMATION & CALCULATIONS

The following calculation applies to the total length of the proposed pipeline 14" OIL PIPELINE

(This length includes 14-inch P/L Seg. No. 19785 being placed back into service and proposed 14-inch Jumper to SS-28A) Given

= 0 mmscfd

3200 bpd

0

14. in

0.375 in (304,283 ft of 0.375" wall, 126 ft of 0.438" wall)

13.25 in

304,409 ft (304,283 ft of 0.5" wall, 126 ft of 0.438" wall)

100 ft

400 psig

Gas Flowrate

Oil Flowrate

Gas to Oil Ratio

Pipeline Outside Diameter

Pipeline Wall Thickness

Pipeline Inside Diameter

Pipeline Length

Average Water Depth

Pipeline Operating Pressure

Assumptions

Pipeline Leak Detection Time

Shutdown Response Time

15.00 minutes

0.75 minutes

Find

Worst-Case Spill Volume

Calculations

Use the MMS Pipeline Oil Spill Volume Estimator, OCS Study MMS 2002-033, Sections 1.3.1 through 1.3.5.

Volume of OII Released Prior to Pipeline Shut-In (Vp,)

v = - 2 i i P S 1440

Where:

Q= Pipeline flowrate, bpd

t= Time before shut-in, min

v _ (3,200 x (15.00+ 0.75))

1440 35.00 barrels

Pipeline Volume (Vplp,)

V = r Pipe

'inr . 2 4 , n

Where:

ID= Intemal diameter of pipe, in Lp= Length of Pipeline, ft

Vpipe= 13.250/24)A2 x 304,409 x TI V n l „ = 291602.61 ft3


0,* TECY PIPELINE PERMIT & CALCULATIONS - KAQ-1030,14" OIL PIPELINE

JUMPER

Client:

Arena Offshore. LP

Project:

Rosefield Pipeline

Job No: Rev: Date:

17460 1 3/6/1B

Issued For:

MOC: SS28A-2017-11-28

Spec No: Doc No:

17460-PLEN-TP-0003

Page:

2 of 2

Release Volume Factors based on Relative Pressure Ratio (Pmi)

P „ . „

rel amb

Where:

Ppipe= Pipeline pressure, psi

Pamb= Pressure at water depth, psi

= 0.446533 x water depth

= 44.65 psi

400 P,si=

44.65 P,B,= 8.96

Use Pr8i and Table 1.3 in the MMS Pipeline Oil Spill Estimator to Find:

f r e l= 0.55

Gm a x= 505

Use Table 1.4 in the MMS Pipeline Oil Spill Estimator to Find:

GOR= 0 f g o r= 0.26 GOR<Gmax

Volume Released ( V n l )

Vr0|= 0.1781 x Vpipe x frel x fgor + Vps

V r o l= 0.1781 x 291,602.61 x 0.55 x 0.26 + 35.00

7461.62 barrels

17460-PLEN-TP-0003, R1 - 14in Oil Pipeline Modification Permit Strategy Engineering and Consulting, LLC.

KAQ-IQ3Q OL PIPELINE

9 ! t . I*" OO

id top iooo pac

ZZZ-9060 PIG RCTVER

3ZE 20 _ i i r

EVERYTHING ON THIS DRAWING IS EXISTING

CLOUDED ITEMS REPRESENT PROPOSED MODIFICATIONS

\ * ' ANS 900

or wm 2 TAP

WT TAP-v MS 900 \

1000 PSC PCH HTOROItST

- E N O or UNE IH

gHERAL NOTTS:

1 THE DESKH CHARACTCRISTKS OF THE PROPOSED RPEUNE EQUALS OR EXCEEDS THE REOU1REUENTS OF DOI TITLE 30 CFR. PART 250 SUBPART J.

2 SEE SECIWN M OF THE RICH I Of WAT PIPEUNE APPUCATION FOfl SPEOFIC DCSKW CHARACTERISTICS OF THE PROPOSED PIPEUNE 1 H 00" PIPEUNE WLL TRANSPORT OL

4 PLATFORU PRESSURE PILOT SENSORS WLL BE SET AS FOLLOWS HI SENSOR. I5» OVER NORMAL OPERATWC PRESSURE RAHCE, NOT TO EXCEED IHE MAOP OF THE SEGMENT THEY ARE PROTECTING

LO SENSOR- 151 UNDER NORMAL OPERATING PRESSURE RAHCE

S. mFQSED UHE PPE. PBOPQgD UNC PUT 5fl flEHOS. fflPfQgD ffigR fVE, PROPQgD BSB 50 Km. 0.0. - l^ f iO'N

KGCHTStHJlLfl/FT API 5L X 5 r - ^ TTPE • SMLS DESGN - 3574 PSK

O.D WT

5) Lfl/FT HDCHT -API SL X TYPE - SMLS OESCN - 2460 PSC

O.D. KT BOOIT •hG^STLD/TT

API SL xsr^ TTPE - SMLS DESW - 2229 PSC

O.D W.T WDGHT Si 63 3)LB/FT API 5L X 5 r - ^ FIPE - SMLS OESim - 2050 PSC

PROPQSffi Fimcs aASS - ANS 900 SZE - 14" SPEC - BG 5 DESGN - 2220 PSG

Ewsmc M' UHC PPE

EXISTING P A SEGMENT PROPOSED 14' 00. PIPEUNE NO 19785 0 SS-2Bj_I0 SS-JflA PLATFORM

APPROX, 126 FT TO 14' SSD « SS-28

WVEUNE SEGMENT NO 19785

EMSPHC M' HTTIWCS a * s s - ANS 900 SZE - H ' SPEC - BG 5 DESGN - 2220 PSIC

I HYDROTESTED EXISTINC 14' P/L SECEMENT NO 1 9 7 t o \ TO 1300 PSG FOR 8 HRS.

PffCLtNE SFOtfWT HO I97H5 PROPOSED MDPFICATIQH I REUSE MAOP PER HYDROTEST TO IOOO PSC. 3 INSTALL PROPOSED 14* 00. PIPELINE JUMPER

FROM PIPEUNE SEGMENT 19785 W 55-28 TO SS-38A.

6 14 00' PIPEUNE MAOP IS IOOO PSC

7 COOES ft SPEPTlCAnONf 60 AHS SI6 5 30 CFR 350 AHS 831 3

VALVES FITTlNCS PIPELINE PLATFORM PWNG

I PROPOSED 8' PA FROM El-2531 CCWRCD UNDER SEPARATE PERMIT APPUCATION

•1 RtMSCD I* MCH m*LL THOOCSI, UOC SS3BA-MI7-11 -W MB CM UflM/lM NC 1 (ssuco ran PCTWI. UOC S S I B A - M I T - M - J B •.m 11/M/17 ^ m

a BSUCD Ttm POtUfl. UOC SS31*-«II7-t1-7B im Mt

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[BSEE) RECEIVED MA R 13 2018RP0176-83 is 8.4 to 7.4; use 7.9. 1= 127 ft L= 38,200 x 92 14.000 x 127 ft x 7.9 252.2 years LIFE EXPECTANCY 17460-PLEN-TP-0003, Rl - 14in Oil Pipeline