C i

U.S. Departm ent of the InteriorBureau of Safety and Environmental

Enforcement (BSEE)

S u tm it original plus T H R E E copies, with O N E copy m arked "Public Inform atiof)."

0 M B Control No. 1014-0018

0 M B Appro\/al Expires 10/31/2014

Application for Perm it to Modify (ARM)1. W ELL N A M E (C U R R E N T )

S-275. API W E LL N O . (12 digits)

04-311-20557-00

2. S ID E TR A C K NO. (C y ^ R E N T )

6. S TA R T D A TE (Proposed)

09/15/2014

3. BYP A S S N O . (C U R R E N T )

007. E S T IM A TE D D U R A T IO N (D A Y S )

12 Days

4. O P E R A TO R N A M E and A D D R E S S (S o ijm ittin g office )

DCOR, LLC290 Maple Ct, Ste. 290Ventura, CA 93003

□ Revision9. If revision, please

list changes;

W E LL AT TO TA L DEPTH WELL^ T SURFA RECEIVED10. LEASE NO .O CS P-0216

13. LEASE NO .O C S p-0216

11. AREA NAM E

6 B14. A R E A NA M E

6 B MAR 2 & 2 0 1 412. BLO CK NO .

486115. B LO CK NO .

4861

Proposed or C om pleted W orkOlr FlCfc 01* U tL U lows J16. P R O P O S E D O R C O M P L E T E D W O R K (Describe In Section 17)

P L E A S E S E L E C T O N L Y O N E P R IM A R Y T Y P E IN B O LD A N D A S M A N Y S E C O N D A R Y TY PE S A S N E C E S 9 A R ¥ 7 -1^ E nhan ce P ro d u ctio n

Acidize

□ Artrfical Lift

S W ash/D esand W ell

□ Jet W eil

n u tility

n InitlaMnjection W ell

n Additional Fluids for Injection

Q O th e r O p era tio n s

D Describe O peration(s)

□ W o rk o v er:

O Change Tubing

n Casing Pressure R epair

Q A b a n d o n m e n t o f W ell Bore:

Q Perm anent Abandonm ent

Q Tem porary Abandonm ent

Q Plugback to Sidetrack/Bypass

Site C learance

P C o m p le tio n :

Initial Completion

n Reperforation

n Change Zone

Modify Perforations

□ In fo rm ation :

n Surface Location Plat

D Change W ell N am e

17. B R IE FLY D E S C R IB E P R O P O S E D O P E R A T IO N S (Attach prognosis):

Pull tubing; C leanout santd; Run inner liner gravel pack; Acid ize ; Run ESP; RW TP18. L IS T ALL A T T A C H M E N T S {Attach com plete well progrrosis arid attachm ents reQuired by 3 0 C F R 2 5 0 .51 3 (a ) through (d): 2 50 .613(a) through (d): 2 50 .17 12 (a ) through (g): 2 50 .17 21 (a ) through (h); 250 .1722 (a ) through (d): o r 250 .1743 (a )

See attached W BDs, w orkover procedure, and acid procedureIS . Rig N am e or Prim ary Unit (e.g.. W ireline Unit. Coil Tubing. Snubbing Unit, etc.)

DCOR Rig #10

20. The greater of S IT P or M A S P (ps i): 700 21- Type of Safety Vaive (SV ): _ X . S C S S V S S C S V N/A 22. S V Depth BM L (ftl: 5 3 V

23. Rig BO P (R am s ) Rig B O P (A n n u lar)

S lle :(Inches)

2 - 7 / 8 "

Working Pressure(psi)

5,000

Test Pressure(psi)

„ . 250/2,500Low /H igh;__________

Working Pressure (psi)

5,000

Test Pressure

(psi)

Low/HtQh:

| 26, S nubb ing U n it BOP:'25 Coiled Tubing BO P: l27. W ire line Lubricato r:Working Pressure B O P Test Pressure

(psi) (psi)

N/A Low/High: N/A

Working Pressure

(psi)

N/A

Test Pressure

(psi)

Low/High

Working Pressure (psi)

Low/High:

Test Pressure

(psi)

N/A

28. C O N TA C T NAME:

Dale Bradley29. C O N T A C T TE L E P H O N E NO.:

(805) 535-2085________30. C O N TA C T E -M A IL A D D R E SS :

DBradley@dcorllc.com31. A U T H O R IZ IN G O FFIC IA L (T y p e o r p r in t n am e)

Robert L. Garcia33. A U T H O R ia N G S IG F K T B R

APPROVED

32. T ITLEV.P. California Offshore Operations

34. DATE

THIS SPACE FOR BSEE USE ONLY(DATE

B s E e F o rm B S E E -0 1 2 4 (March 2012 ■ Supersedes all previous versions of this form which may not be used.) P a g e 1 o f 2

DOI0001560

Application for Permit to Modify (ARM) Information Sheet

35) Q uestion In form ation

Questions Response Remarks

a) is H2 S present in the well? If yes, then comment on the Inclusion of a Contingency Plan fo r this operation.

[X] YES

□ NO

□ N/A

SCBA and H2S sensors per BSEE regulations.

b) Is this proposed operation the only lease holding activity for the subject lease? If yes, then comment.

□ YES

[3 NO

□ N/A

c) Will all wells in the well bay and related production equipment be shut-in when moving on to or off of an offshore platform, or from well to well on the platform? If not, please explain.

□ YES

H NO

□ N/A

Solid steel deck between drill deck and wellbay.

d) If sands are to be commingled for this completion, has aproval been obtained?

□ YES

□ NO

[X] N/A

e) Will the completed interval be within 500 feet o f a block line? If yes, then comment.

□ YES

□ NO

[X] N/A

f) For permanent abandonment, will casings be cut 15 feet below the mudline? If no, then comment.

□ YES

□ NO

[ X ] N/A

PAPERWORK REDUCTION ACT OF 1995 (PRA) STATEMENT The PRA (44 U.S.C. 3501 et. seq.) requires us to inform you that we coliect this information to obtain knowledge of equipment and procedures to be used in drilling operations. BSEE uses the information to evaluate and approve or disapprove the adequacy of the equipment and/or procedures to safely perform the proposed drilling operation. Responses are mandatory (43 U.S.C. 1334). Proprietary data are covered under 30 CFR 250.197. An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a currently valid OMB Control Number. Public reporting burden for Form BSEE-0124 is estimated to average 17 hours per response. This includes the time for reviewing Instructions, gathering and maintaining data, and completing and reviewing the form. Direct comments regarding the burden estimate or any other aspect of this form to the Information Collection Clearance Officer, Bureau of Safety and Environmental Enforcement, 381 Elden Street, Herndon, VA 20170.

BSEE Form BSEE-0124 (M arch 2 0 1 2 - S upersedes all previous versions of this form w hich m ay not be used.) Page 2 O f 2

DOI0001561

7 RUN 7" SCRAPER (OPTIONAL)7.1. PU & RIH with 7" positive scraper on existing 2-7/W .7.2. RIH to cleanout depth.7.3. POOH standing back tubing. Lay down 7" scraper.

8 RUN AND GRAVEL PACK INNER LINER8.1. PU 3 - /2" L-80 SSWWS inner liner.8.2. PU Inner gravel packing tubing and gravel tools.8.3. RIH with liner and tools on 2 -7 /8 " tubing. Set down on cleanout bottom and space SC-1 packer to be at

+ /- 7,710.8.4. Proceed to gravel pack Inner liner with >100% of theoretical sand volume.8.5. POOH laying down old tubing. Laydown Inner string and gravel pack tools.

9 RUN STIM PACKER AND PUMP ACID• Make sure all JSAs required for transport and handling of acid equipment, are being followed. Refer to

DCOR acid JSA procedure for details.• RU acid equipment.9.1. PU 2 -3 /8" FJ/IJ tubing for acid tailpipe. PU enough tailpipe to space tubing 50' off liner bottom.9.2. PU 9 -5 /8" full bore stimulation packer and RIH while picking up new /yellow band 2 -7 /8" L-80 tubing.

Set packer at ~7,650' tubing tail below. Test backside to 500 psi for 5 minutes.9.3. Acid operations - pump acid job per separate acid procedures9.4. Bleed off remaining pressure and release packer.9.5. Allow well to equalize, open bypass and check well for stability. If stable, release packer. If well Is u-

tubing, circulate one tubing volume of kill fluid.9.6. Pump an additional 100 bbl of filtered seawater down well to further dilute the acid while POOH w /

stimulation string.9.7. LD treating packer. Hold post job acid JSA.9.8. RD acid equipment

10 RUN ESP10.1. RU to run Baker completion equipment, 1 x 3 /8" chemical line to motor Intake and 2 x >4" control lines

to SCSSSV and vent valve. Test control lines to 5000 psi10.2. MU new ESP and RIH. Plan to set bottom of m otor at + /- 7 ,680' (above 3-34" liner). Install cannon

clamps at each tubing collar and one band at each mid joint. Test cable every 20 stands, phase-to- phase and phase-to-ground. Install chemical Injection line with check valve at pump intake.

10.3. RU tubing testers. Continue running In hole with 2 -7 /8" production tubing, hydro testing tubing to 5000 psig.

10.4. MU SCSSSV, surface packer and vent valve. Splice electric line. Pressure test SCSSSV and vent valve to5000 psig for 15 minutes. RIH w / remaining tubing and hydro test to 5000 psi. Place surface packer at-r/- 500'.

10.5. Install plug onto ESP cable. Install feed through mandrel and test connections. Ensure electrical feed through Is protected and kept dry. Obtain BSEE variance for cable soldering 24 hours In advance from ChrlstI McMlllen at 805-535-2070. Complete Hot W ork Permit. Use explosion proof fan and continuously monitor well head area with hand monitors. Strap all completion equipm ent and prepare tubing detail.

10.6. Drain stack. Land hanger using caution to avoid torn seal elements. Install BPV. Run In lock down screws. Fill stack. Test lower seals on tubing hanger against pipe rams to 3000 psig for 10 charted minutes.

10.7. Check well for pressure and back out landing joints.

Gllda S-27 Procedures March 2014

DOI0001562

11 ND BOPE AND NU TREE11.1. ND diverter, BOP and riser.11.2. NU and test production tree to 3000 psig.11.3. Install pig tail and hub clamp on production tree.11.4. Puii BPV.11.5. Pressure annular vent valve and SCSSSV open for 15 minutes.11.6. If Production Operations is ready, run ESP to confirm correct rotation and operation for 2 hours.

Record tubing pressure. Shut down ESP. In the event that Production Operations is not ready to run the ESP, RD and move to next well.

12 SET PACKER12.1. MU landing joints into tree. RU wireline and pressure test lubricator and lines to 3000 psig.12.2. Set tubing plug above SCSSSV.12.3. As per Baker Hughes representative's direction; Pressure up in 500 psig increments to set packer at

1500 psig. Continue pressuring up to 3000 psig and hold for 15 minutes.12.4. Bleed pressure and pull tubing plug.12.5. RD wireline and have production test vent vaive and SCSSSV.12.6. Turn well over to production.

13 RDMO13.1. Prepare rig for skid to next well.

Gilda S-27 Procedures March 2014

DOI0001563

spud; 9M 5 /1983

AP I # 0 4 -3 1 1 -2 0 5 5 7 -0 0

Lease #: O C S -P 0216

Platform Gilda S-27

3 /1 4 /2 0 1 4

R T to S e a Level = 107’

SL X - 1,041.685 00 Y= 748,013 00 KB = 5 2 ’

BHL X= 1,036,374.00 Y= 743,305 00 W a te r Depth = 205 '

B a ke r S C S S S V 5 31 '

2-7/8" EUE, N-80, 8rd Tubing Model HS Packer 7,686‘; ball stiear & entry guide below

T o p o f L P -B 7 ,8 0 7 ’

Caslne Strine 20'' 16" 13-3/B'’ 9-5/8"Open Hole finches) 26 22 IS 12.25Casing OD (inches) 20 16 13.375 9.625CP (feet) 717 1646 3458 7803Volume o f Cement (ft*) 1200 1513 2565 2045Annular Caoacitv 0,6643 0.8042 1.2635 3.1930TTOC ffeetl s -80 119 -374 1273

.20" 94#K -55C 717'No notes on cem ent returns to seafloor

TTOC (9-5/8") 1,273'; Noted cmt returrts to srf; No CBL

_16" 75# K-55 Cond Extension 405’ -=1,646'No notes on returns during cm t job. lap tested ok

.13-3/8" 68# & 54.5# K-55 C 3,458'Full fluid returns during job. noted cem ent to surface

Tagged fill @ 7,636' (1/22/2013), Circulated out gravel pack & formation sand to 7,864'

Was not running In at cleanout depth

Too ofLP-C 8.061'

Top of LP-P 8.298'

ID 8,329'

WSO Perf Detail 10/2/1983:7 ,7 3 3 ' - 4 -1 /2" Holes, sqz w /*-208cf cmt. test ok

_ 9-5/8" 43.5# N-80 C 7,803'Full fluid returns during job. noted cem ent to surface Extem al casing packer 7,739* - 7 ,7 5 9 ', did not inflate External packer ports leaked, had to sqz multiple tim es

Liner Detail:.20" S S W W S 7,809' - 8 ,3 2 4 ‘SC-1 P acker 7 ,7 3 0 ’; Port Collar 7 ,739 '16" open hole gravel pack w /690sx 16/30 O ttaw a (1 2 0 % )

.7" 26# K-55 L 7,730'-8,325'

DOI0001564

WELL INFORMATION

KEC Job Number:

Anticipated Kill Fluid Weight:

Well Total Depth:

Plug Back Depth:

Effective ID :

Kelly Bushing:

Wellhead:

Vent Valve:

Packer:

SS5V:

Control Lines:

Chem Line:

Conductor Casing:

Conductor Casing Extension;

Intermediate Casing:

Production Casing:

Gravel Pack Liner:

Tubing:

1015

10.6 ppg

8329'MD (-5,795'7VD)

8325' MD

7864' MD (Nov 2013 cleanout)

52' above tubing hanger LDS

Seaboard 13-5/8" 3M 8X160

None

HS Packer @ 7,686’ w/30K shear

Baker TRSCSSVTE-5

1 X )4" SS

None

20" 94# K-55 @ 717'

16" 75# K-55 @ 405' -1646 '

13-3/8" 68# & 54.5# K-55 @ 3,458'

9-5/8" 43.5# N-80 @ 7,803'ID: 8.755"Drift: 8.599"bbl/ft: 0.07446

7" 26# K-55 @ 7,730' - 8,325'SSWWS from 7,809' - 8,324'ID: 6.276"Drift: 6.151"bbi/ft: 0.03826

2-7/8" 6.5#, P-llO/N-80, 8rd @ 7,700' tailpipe depth ID: 2.441"Drift: 2.347"bbi/ft: 0.00579

Gilda S-27

DOI0001565

PRE-RIG OPERATIONS:• Maximum anticipated surface pressure is 700psi. Expected kill fluid is 10.6 ppg. Reservoir pressure is ~2785psi

at 7600' MD (5155' TVD). 0.54 psi/ft at packer depth = 10.4 ppg• Punch holes in tubing as close to the packer as comfortable.• Note 10.6 ppg kill fluid is on backside over packer• Notify BSEE 48 hours in advance of workover. A BSEE permit is required for this workover.

1 MIRU1.1. MIRU. Test H2S equipment and cascade systems on rig floor.1.2. Verify well is locked and tagged out.1.3. Pressure test tree bonnet and/or between seals on tubing hanger to 3000 psi.1.4. Check tubing and casing pressure. Bleed off pressure. Monitor wellhead pressures for 30 minutes to

ensure static conditions. If well dead, proceed with step 3.

2 KILL WELL2.1. Mix weighted fluid in mud pits using filtered seawater. Treat all fluids with scale inhibitor and biocide.2.2. Displace kill fluid down casing using PZ-9. Restrict kill rates to avoid pumping fluids into formation

while circulating. Notify Lead Operator 4 hours in advance of kill procedure. Take returns through choke manifold to 500 bbl tank using Wait-and-Weight Method. Have 500 bbl tank plumbed to production drain system to drain well fluid from tank while killing well.

3 ND PRODUCTION TREE, NU AND TEST BOP3.1. With well dead, install BPV. Be sure to have the correct XO for riser.3.2. ND production tree. Inspect tubing hanger lock down screws.3.3. Check tubing hanger joint threads with short 2-7/8 EUE pup joint. Visually examine the wellhead

components. Install cap on feed through mandrel.3.4. NU and test Class III 5M BOPE to 250 psi low / 2500 psi high (annular and double gate) for 5 minutes

each against 2-7/8" tubing per BSEE requirements.

4 PU LL OLD COMPLETION4.1. MU landing joints w / FOSV into tubing hanger. Circulate well down tubing. Shut down pump and

check pressures to be static.4.2. Close annular and back out lock down screws.4.3. Shear HS packer by striping through annular. Monitor well for pressure. Packer is set to release with

+/- 30,000 lbs above string weight.4.4. LD tubing hanger. Remove BPV. Send tubing hanger to Cameron for redress.4.5. Install FOSV and circulation head. Circulate well back to pits. SD pump and monitor well.4.6. POOH w / tubing and control line to SCSSV. LD SCSSV, send to BoT in Ventura.4.7. POOH w / 2-7/8" tubing. Stand back the old production tubing. Keep hole full at all times.

5 RUN 9-5/8" SCRAPER5.1. PU & RIH with 9-5/8" 43.5# positive scraper on existing 2-7/8".5.2. RIH to top of 3-K" liner (~7,710').5.3. Circulate well clean.5.4. POOH standing back tubing. Lay down 9-5/8" scraper.

6 CLEANOUT WELL TO TD6.1. PU 6-1/8" bit.6.2. RIH with 2-7/8" tubing while circulating down to TD (8,325'). PU power swivel if needed.6.3. Circulate liner over to poiymer fluid when needed or when reaching TD.6.4. POOH w/tubing, laydown bit.

Gilda S-27 Procedures March 2014

DOI0001566

s-27 ACID PUMPING SCHEDULE 3 /1 9 /2 0 1 4

1. Install workable 3,000 psi gauges on the wellhead annulus and tubing. RU acid pumping equipment on the platform and test surface lines to at least 3,000 psi.

2. Run stimulation packer above new 3-/j" liner top in the 9-5/8" production casing. Run a 2-3/8" or smaller tubing tail to 50' off liner bottom.

3. Spot 70 gal ('“1.7 bbl) of 15% MCI out bottom of tailpipe across liner from tailpipe to top of SSWWS ('“7,809' - "8,265') and displace tubing with kill weight fluid.

4. Set packer and test backside to 500psi. Allow acid to soak for 2 hours.

5. Open the bypass valve. Start acid job at 1.0 bpm and gradually increase/decrease to highest rateachievable at 1,800 psig surface pressure. Close bypass when acid reaches packer. Apply 500 psig on annulus and monitor throughout job.

*D 0 NOT EXCEED 2,000 PSIG SURFACE PRESSURE or 3 BPM *

2-7/8" capacity is .00578 bbl/ft. .00578 * 7,700' = 44.5 bbis = 1 tubing volume

Pumping Schedule:15% HCI 143 bbIs 6000 gals5% NH4 CI (Clayfix) 71 bbis 3000 gals (Sent out as lOOOga! cone)FSW/Kill fluid "“94 bbis 3950 gals (2.0 tbg vol + liner vol)

6. After pumping final stage clean tanks with kill fluid/FSW as needed and pump down tubing, this volume can be part of the final 94 bbl displacement.

7. Shut in at surface after final displacement and allow well to bleed off to formation for up to 2 hours.Bleed off any remaining pressure, do not bleed off more than one tubing volume.

8. Open bypass on full-bore packer and check well for stability. If stable, release packer. If U-tubing is seen, circulate kill fluid or filtered sea water as needed.

9. Lay down stimulation tools, stand back tubing, and prep to run artificial lift equipment.

Displacement volumes can be modified to match with current tubing tallv.

Some o f the chemicals specified in this program have toxic properties. Personnel should be fam iliar withthe inherent dangers and appropriate safeguards to prevent accidental injury. Please refer to the MSDSsheets fo r proper safety precautions and required personnel protective equipment.

Note: The equipment must be cleaned prior to leaving platform. Client representative must inspectequipment prior to acid crew being released.

DOI0001567

spud: 9/15/19B3

Platform Gilda S-27

P R O P O S E D

R T to S ea Level = 107'

API # 0 4 -3 1 1 -2 0 5 5 7 -0 0 SL X= 1,041.6a5 00 Y= 748,013.00 KB = 52'

L e a s e # : O C S -P 0216 BHL 1,036,374 00 Y= 748,305.00 W a te r Depth = 205'

B a k e r V e n t V a lv e + /- 540 ' B a k e r T w in S ea l p a c k e r + /- 550*

B a k e r S C S S S V + /- 565 '

2 '7 /8 " E U E , N ’ 80 , 3rd T ub ing B o tto m o f R eda S e n s o r a t W - 7 ,6 8 0 '

T o p o f L P -B 7,80r

T o p o f L P -C 8 ,061'

T o p o f L P -D 8 ,298 '

Casin£ Strine 20" 16" 13-3/8" 9-5/8"Open Hole finches) 26 22 18 12.25Casing 0 0 (inches) 20 16 13.375 9.625CP (feet) 717 1646 34S8 7803Votume o f Cement fft*} 1200 1513 2565 204SAnnular Capacity ( ft /f t ’ ) 0.6643 0.8042 1.2635 3.1930TTOC ffeet) = -ao 119 ■374 1273

.20" 94# K-55 C 717’No notes on cem ent returns to seafloor

TTO C (9 -5 /8" ) 1 ,2 7 3 '; N o ted c m t re tu rn s to srf; N o C B L

_16“ 75# K^55 Cond Extension 405' -1,646'No notes on returns during cm t job, lap tested ok

. 13-3/8" 68# & 54,5# K-55 C 3,458'Full fluid returns during job, noted cem ent to surface

T D 8 ,329 '

3-1/2" 26# L-80 L +/- 7,710' - 8,315',20" S S W W S 7 .8 0 9 '- 8.315'G ravel pack w / 16 /3 0 O ttaw a (1 0 0% + Theo.)

W S O P e r f D e ta il 10 /2 /19S 3:7 .7 3 3 ’ - 4 -1 /2" Holes, sqz w /-2 0 B c f cmt. test ok

.9-5/8" 43.5# N-80 C 7.803'Full fluid returns during job. noted cem ent to surface External casing packer 7 .7 3 9 ’ - 7 ,7 5 9 '. did not Inflate External packer ports leaked, had to sqz multiple tim es

L in e r Deta il:.20" S S W W S 7 .809' - B.324'SC-1 Packer 7 .730 '; Port Collar 7 ,739'16" open hole gravel pack w /690sx 16/30 O ttaw a (1 2 0% )

.7" 26# K-55 L 7.730'- 8,325'

DOI0001568

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Sue Warren Card Type: VisaCard Number; ************6593

8401 N. Central Region : PacificExpressway Dale Bradley 805#525 Contact: 535-2085

Com pany- DCOR, L.L.C.Dallas Com panyNo : 2531

TX Lease: 0216API Well No : 043112055700

75225 Unnamed orArea-Biock: Other, 4861

USA Enhanceproduction -

APM Work: Acidize

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DOI0001569

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BSEE Application for Permit to Modify - BR25ESMNRA7458805335603/19/2014 11:30 EDT

Holder Name: Sue Warren

Billing 8401 N. Central Address: Expressway

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Card Type: Visa Card Number;

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Contact: 535-2085C om pany-D CO R, L.L.C. /

Com panyNo : 2531 Lease: 0216

API Well No : 043112055700 Unnamed or

Area-Block: Other, 4861 Enhance production -

APM Work: Acidize

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DOI0001570

DCOR-APM P-0216 S-27

Fernandez, Peggy <peggyiemandez@bsee.gov Wed, Mar 26, 2014 at 12:06 PMTo: BSEE RAC California District <bseepaccatifomiadistrict@bsee.gov, BSEE PAG OPD <bseepacopd@bsee.gov, Kenneth Seeley <kenneth.seeley@bsee.gov>

OPD/Seeley: Please see attach.

Entered in P:/ODO....APM {lssued)/DCOR-14-0324-APM{R)-P0216-51011 -S027.pdf

Peggy Fernandez Office of Field Operations California District OfficeBureau of Safety and Environmental EnforcementPacific OCS RegionCamarillo, CA 93010Main No.: (805) 389-7775Fax No.: (805) 389-7784peggyierriande2@bsee.gov

DCOR-14-0324-APM(R)-P0216-51011-S027.pdf^ 2315K

Sinkula, Nathan <nathan.sinkula@bsee.gov Wed, Mar 26, 2014 at 12:13 PMTo; "Fernandez, Peggy" <peggy.fernandez@bsee.govCc: BSEE PAG Califomia District <bseepaccalifomiadistrict@bsee.gov, BSEE PAG OPD <bseepacopd@bsee.gov, Kenneth Seeley <kenneth.seeley@bsee.gov

OPD has no issue with the proposed operation to Install an inner-grave! packed liner and to acidize the completion.

IQuoled text hiiWeiiJ

Nathan SinkulaPetroleui': engineerOffice of Production & DevelopmentBSEE- POCSR805-389-7748 - office805-603-7918 - cell

DOI0001571